This paper reviews the results of a comprehensive assessment of the prospectivity of structural uplifts on the western slope of the South Tatar arch. The relevance of this study is due to the depletion of major oilfields and the limitations of untapped resources. The main goal is to develop and apply a universal approach to rating of local targets for exploratory drilling in mature areas using an integral reservoir prospectivity coefficient. Twenty-two structures and 235 wells were selected for analysis based on the data obtained from 3D seismic survey (500 km2), well logging, and core and sludge analyses. A 3D geological model, incorporating an interpretation of seismic surfaces, a stratigraphic breakdown, and an extrapolation of reservoir properties, was build using TNavigator software. A geostatistical analysis was used to account for uncertainties in the interwell intervals. Maps of reservoir structures and properties (porosity, permeability, oil saturation, net thickness) were compiled. The evaluation of geological resources was performed using deterministic and probabilistic approaches, together with development scenario analysis and cash flow discounting. Then, the integral prospectivity coefficient was introduced, including parameters of resources, morphology, infrastructure and economic attractiveness. The drilling priority ranking of the selected structures was compiled based on this coefficient. This technique demonstrated high informative values and enabled the identification of the most promising targets, taking into account both geological and economic risks. The obtained results can be applied to exploration planning under a high degree of uncertainty, a limited budget, and late-stage development. This approach can be scaled for similar regions, and integrating it into digital reserve management platforms shall make exploratory decisions more efficient and accurate.

References

1. Kamaleeva A.I., Issledovanie vozmozhnykh istochnikov nefti mestorozhdeniy Tatarstana (Study of possible sources of oil deposits in Tatarstan): thesis of candidate of geological and mineralogical science, Moscow, 2014.

2. Muslimov R.Kh., Abdulmazitov R.G., Khisamov R.B. et al., Neftegazonosnost’ Respubliki Tatarstan. Geologiya i razrabotka neftyanykh mestorozhdeniy (Oil and gas bearing of the Republic of Tatarstan. Geology and development of oil fields), Part 1, Kazan’: FEN Publ., 2007, 315 p.

3. Deryushev A.B., Experience of three-dimensional geological modelling of prospective structures using the results of seismic and lithofacies analysis, field-analog data (In Russ.), Vestnik PNIPU. Geologiya. Neftegazovoe i gornoe delo = Perm Journal of Petroleum and Mining Engineering, 2013, no. 7, pp. 18-23,

DOI: https://doi.org/10.15593/2224-9923/2013.7.2

4. Levin M.Sh., Combinatorial framework for planning in geological exploration, arXiv, 2018, no. 1801.07229, 14 r., URL: http://arxiv.org/abs/1801.07229v1

5. Deng H. et al., Learning 3D mineral prospectivity from 3D geological models using convolutional neural networks, arXiv, 2021, no. 2109.00756,

URL: http://arxiv.org/abs/2109.00756

6. Bloem H., Curtis A., Tetzlaff D., Introducing conceptual geological information into Bayesian tomographic imaging, arXiv, 2022, no. 2210.07892,

URL: http://arxiv.org/abs/2210.07892

7. Khisamov R.S. et al., Probabilistic-statistical estimation of reserves and resources according to the international classification SPE-PRMS (In Russ.), Georesursy = Georesources, 2018, V. 20, no. 3, Part 1, pp. 158-164, DOI: https://doi.org/10.18599/grs.2018.3.158-164. – EDN: XZLFVZ

8. Zhang Yucheng, Liu Hao, Wang Zemin, Probabilistic reservoir modeling under data scarcity: integration of seismic attributes and geostatistics, Journal of Petroleum Science and Engineering, 2025, V. 224.

9. Altunin A.E., Semukhin M.V., Yadryshnikova O.A., Probabilistic and fuzzy models to evaluate uncertainties and risks related to HC reserves estimation (In Russ.), Vestnik Tyumenskogo gosudarstvennogo universiteta. Fiziko-matematicheskoe modelirovanie. Neft’, gaz, energetika = Tyumen State University Herald. Physical and Mathematical Modeling. Oil, Gas, Energy, 2017, V. 3, no. 2, pp. 85-99, DOI: https://doi.org/10.21684/2411-7978-2017-3-2-85-99

10. Emel’yanova I.M., Poroskun V.I., Summation of probabilistic oil and gas resource estimates of local objects with account of a geological risk (In Russ.), Geologiya, geofizika i razrabotka neftyanykh i gazovykh mestorozhdeniy, 2019, no. 2, pp. 30-38, DOI: https://doi.org/10.30713/2413-5011-2019-2-30-38

11. Semerikova I.I., Using the dynamic characteristics of longitudinal seismic waves to improve the resolution of seismic exploration (In Russ.), Gornoe ekho, 2020, no. 4, pp. 75-80, DOI: https://doi.org/10.7242/echo.2020.4.15

The problem of casing perforation during hydrocarbon production using shaped-charge perforating guns is associated with a number of process and geological challenges. The major disadvantage of typical shaped charges includes compaction of the rock surrounding the perforation channel. The paper describes an improved casing perforation method due to larger flow area. This method entails application of a reactive element (RE) fitted in front of the shaped charge and made up of solid fuel (energy-saturated material) which, upon detonation, releases high-temperature acids (hydrochloric and hydrofluoric) acting on the walls of the perforation channel to increase its permeability. The RE is designed with an axial channel and a conical cavity, which enables the shaped charge jet to form without any contact with the RE. The composition is based on ammonium perchlorate (AP), a strong oxidizer that releases hydrogen chloride (HCl) upon decomposition. To increase the acidity, chlorine- and fluorine-containing components. According to experimental data, the perforation channels formed by shaped charges loaded with RE exhibit larger dimensions and rock decompaction zone to improve the fluid flow. Test results confirmed the efficiency of the proposed solution: channels with RE have larger dimensions and improved flow performance. Thus, the combination of RE with shaped charges ensures increased well productivity due to improved permeability in the bottomhole zone and minimizes the need for post-treatments.

References

1. Adadurov G.A. et al., Shock wave induced polymerization of acrylamide (In Russ.), Fizika goreniya i vzryva, 1972, no. 4, pp. 566-570.

2. Batsanov S.S., Solid-phase chemical reactions in shock waves: kinetic investigations and a mechanism (In Russ.), Fizika goreniya i vzryva = Combustion, Explosion, and Shock Waves, 1996, no. 1, pp. 115-128.

3. Anisichkin V.F., On phase transformations and chemical reactions in shock waves (In Russ.), Fizika goreniya i vzryva = Combustion, Explosion, and Shock Waves, 1980, no. 2, pp. 140-143.

4. Figovsky O. et al., Production of polymer nanomembranes by super deep penetration method, Chemistry and Chemical Technology, 2012, V. 6, no. 4, pp. 393-396, DOI: https://doi.org/10.23939/chcht06.04.393

5. Bazotov V.YA. et al., Study of the operating parameters of a coaxial-layer cumulative charge for industrial purposes (In Russ.), Vzryvnoye delo, 2015, no. 114-71,

pp. 242-251.

6. Gil′mutdinov D.K. et al., Produkty goreniya tverdotoplivnykh zaryadov: otsenka effektivnosti deystviya na karbonatnyye porody (Combustion products of solid propellant charges: assessment of the effectiveness of action on carbonate rocks), Collected papers “Nauchno-tekhnicheskiy progress: aktual′nyye i perspektivnyye napravleniya budushchego” (Scientific and technological progress: current and promising directions of the future), Proceedings of IV International scientific and practical conference, Kemerovo, 30 November 2016, Kemerovo: Publ. of ZapSibNTS, 2016, pp. 10-13.

7. Patent RU 2287667 C2, Method for well completion (variants), Inventors: Marsov A.A., Mokeyev A.A., Sadykov I.F., Mingulov I.G., Khayrutdinov M.R.

8. Mokeyev A.A. et al., Study of physical stability of energy-saturated compositions of chemically active element intended for oil well treatment (In Russ.), Vzryvnoye delo, 2012, no. 107-64, pp. 49-59.

9. Pavlova YA.O. et al., Experimental evaluation of acid-generating solid propellant charges’s efficiency in complex with a charge of gun perforator (In Russ.), Vzryvnoye delo, 2023, no. 138-95, pp. 103-113.

The paper presents key aspects of a drilling sequence planning considering the need to put the most promising wells on stream on a first-priority basis. The authors analyze the ranking parameters for candidate wells considered for well interventions including drilling, and identify several groups of criteria that can be used to evaluate their efficiency. To minimize the risk of improper candidate well selection, it is more efficient to consider complex parameters that were formed using several geological and technological criteria. A weighting factor can be assigned to each criterion which will define its priority. Candidate well ranking can be performed based on the predicted efficiency parameters obtained from machine learning models. The paper presents data on the existing algorithms developed by the authors under the Epsilon project, which optimize the process of selecting candidate wells for drilling. A comparative analysis of two methods of ranking the planned well clusters was carried out: based on integral absolute parameters (residual oil saturation, predicted oil production rate, net present value (NPV)) and based on specific parameters (discounted profitability index, cumulative production per well, NPV per Ruble of investment). It is shown that ranking of single planned wells can be based on absolute parameters, while ranking of well clusters should be based on relative (or specific) parameters. The proposed methods are aimed at improving the accuracy and efficiency of planning well interventions, including drilling operations.

References

1. Tyul’kov A.T., Permyakov A.V., Shakirov R.R., Methodology for ranking candidate wells for conducting geological and technical measures at a gas condensate field with significant reserves for commissioning from long-term conservation (In Russ.), Sfera. Neft’ i gaz, 2021, no. 3, pp. 30-34.

2. Sinitsyna T.I., Galeev A.A., Methodology of automated selection of well candidates for hydraulic fracturing at Kharampurneftegaz fields (In Russ.), Neftyanaya provintsiya, 2022, no. 4, pp. 239–251, DOI: https://doi.org/10.25689/NP.2022.4.239-251

3. Sinitsyna T.I., Gorbunov A.N., Automation of workover candidate ranking processes at Krasnoleninskoye oil and gas condensate field (In Russ.), PROneft’. Professional’no o nefti, 2021, V. 6, no. 4, pp. 116–122, DOI: https://doi.org/10.51890/2587-7399-2021-6-4-116-122

4. Mashkantseva T.I., Knyazev A.V., Olyunina A.G., Kanaykin C.P., Integrated approach to selection of candidate wells for interventions (based on example of Talinskaya license area, Krasnoleninskoye oil-gas-condensate field) (In Russ.), Nauchno-tekhnicheskiy vestnik OAO “NK “Rosneft’”, 2016, no. 1, pp. 34–37.

5. Kochnev A.A., Kozyrev N.D., Kochneva O.E., Galkin S.V., Development of a comprehensive methodology for the forecast of effectiveness of geological and technical measures based on machine learning algorithms (In Russ.), Georesursy, 2020, V. 22, no. 3, pp. 79–86, DOI: https://doi.org/10.18599/grs.2020.3.79-86

6. Azbukhanov A.F., Kostrigin I.V., Bondarenko K.A. et al., Selection of wells for hydraulic fracturing based on mathematical modeling using machine learning methods

(In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2019, no. 11, pp. 38–42, DOI: https://doi.org/10.24887/0028-2448-2019-11-38-42

7. Andronov Yu.V., Metodika operativnoy otsenki perspektivnosti skvazhin dlya metodov intensifikatsii pritoka nefti s primeneniem neyronnykh setey i derev’ev resheniy (Methodology for operational assessment of well prospects for oil flow stimulation methods using neural networks and decision trees): thesis of candidate of technical science, Moscow, 2019.

8. Certificate of state registration of a computer program no. 2020665887 RF. Programmnyy kompleks podderzhki prinyatiya resheniy po formirovaniyu mnozhestva predpochtitel’nykh variantov geologo-tekhnicheskikh meropriyatiy (vvoda skvazhin v ekspluatatsiyu) pri razrabotke neftyanogo mestorozhdeniya (Software package for decision support for the formation of a set of preferred options for geological and technical measures (commissioning of wells) during the development of an oil field), Authors: Katasev A.S., Kataseva D.V., Anikin I.V. et al.

9. Khisamov R.S., GanievB.G., Galimov I.F. et al., Computer-aided generation of development scenarios for mature oil field (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2020, no. 7, pp. 22–25, DOI: https://doi.org/10.24887/0028-2448-2020-7-22-25

10. Certificate of state registration of a computer program no. 2020616438 RF. Programmnyy kompleks avtomaticheskogo kustovaniya skvazhin (Software package for automatic well clustering), Authors: Akhmetov N.A., Boyarov F.G., Vasyutin V.A. et al.

A well is a multifunctional complex of a single life cycle system with set of uncertainties. Planning stage of each well (production, injection) should include evaluation of all possible uncertainties and risks and their possible effects on the efficiency of the well and overall field and reservoir performance in the long run. Thereby, assessment of possible risks and loss factors and analysis of well site (well pad) at the planning stage are of great importance. Such factors as presence of flushed zones, reserves depletion, lithofacies variability, unconfirmed reservoir pressure and structural plan, premature water breakthrough through fractures (for carbonate rocks), coning issues (for terrigenous rocks), drilling parameters (sidetracks, horizontal wells, multilateral wells) have a strong impact on ultimate well performance. Adequate and comprehensive risk assessment performed by experts in different fields (geoscientists, reservoir engineers, production engineers), and activities proposed to mitigate such risks will eliminate unplanned production, drilling and production problems and reduce extra costs for repair. The paper considers a detailed risk description workflow, risks subdivision, categorization depending on well function (production or injection), and possible activities to eliminate or reduce risks at the stage of well planning. A number of criteria are presented for risk assessment, digitalization, and automation for further decision on project well drilling.

References

1. Shevelev V.V., Risk factors assessment in oil and gas well development investment projects (In Russ.), Biznes-obrazovaniye v ekonomike znaniy, 2019, no. 3, pp. 117–124, URL: http://bibs-science.ru/articles/ar979.pdf

2. Granaturov V.M., Ekonomicheskiy risk: sushchnost’, metody izmereniya, puti snizheniya (Economic risk: essence, measurement methods, ways of reduction), Moscow: Delo i Servis Publ., 2010, 208 p.

3. Risk-menedzhment investitsionnogo proyekta (Risk management of investment project): edited by Gracheva M.V., Sekerin A.B., Moscow: YUNITI-DANA Publ., 2017, 544 p.

4. Nurgaleyeva K.R. et al., Risk management of investment projects in petroleum refining industry (In Russ.), Upravleniye ekonomicheskimi sistemami, 2017, no. 2, 18 p.

5. Khabibullin, T.D., Stupak I.A., Otsenka geologicheskikh riskov pri burenii skvazhin s primeneniyem sektornykh geologo-gidrodinamicheskikh modeley (Assessment of geological risks during well drilling using sector geological and hydrodynamic models), Collected papers “Aktual’n·yye problemy neftegazovoy otraslI” (Current issues in the oil and gas industry), Proceedings of three scientific and practical conferences of the Oil Industry journal, Moscow, 14th April – 19th November 2021, Moscow: Neftyanoye khozyaystvo Publ., 2022, pp. 166–180.

6. Fattakhov I.G., Classification of development objects using the principal component method (In Russ.), Neftepromyslovoye delo, 2009, no. 4, pp. 6–9.

7. Fattakhov I.G., Kuleshova L.S., Musin A.I., On the method of express processing of an unlimited array of continuously incoming field data (In Russ.), Avtomatizatsiya, telemekhanizatsiya i svyaz’ v neftyanoy promyshlennosti, 2009, no. 3, pp. 26–28.

The requirements for the properties of cement grades produced and used in the construction of oil wells are defined in state standards. The main parameter is the bending strength at various application temperatures. However, whether cement strength is sufficient to withstand the range of loads experienced during well operation at particular productive formations remains unclear. Samples of one of the cement grades used in production operations were obtained under pressure and temperature conditions of formations under development, strength properties were investigated for a range of loads in the near-wellbore intervals. A pseudo-triaxial loading setup was used for the experiments. Cement sheath failure envelopes were developed with samples breakdown by conditions of formation. Internal friction angles according to research findings were obtained in a narrow range of 29-31 °. Ultimate cement strength ranges from 53,9 to 102,6 MPa, an increase in cement strength with increasing confining pressure is observed. The obtained strength values are sufficient for the cement sheath to maintain its integrity in situ during production operations. Numerical modeling of the stress-strain state in the near-wellbore area also requires elastic cement properties. Some tasks require understanding of elastic properties depending on pressure changes. Young's modulus and Poisson's ratio are determined for stress conditions typical for producing oil fields of the Republic of Tatarstan. There is a slight difference between ultimate strength and elastic property ranges for two conditions of cement sample formation. Hence, the general failure envelope with single states limit is applicable.

References

1. Nutskova M.V., Alkhazzaa M., Review of well casing problems and applied cementing materials (In Russ.), Neftegaz.RU, 2023, no. 11, pp. 90–96.

2. Nikishin V.V. et al., Cement mixtures and additives for lining well sections in permafrost conditions. Analysis of compositions (In Russ.), Neftegaz.RU, 2023, no. 8,

pp. 94–101.

3. Aslzoda M., Azizov R.O., Cement sheets and their value when driving salt-bearing deposits (In Russ.), Doklady Akademii nauk Respubliki Tadzhikistan, 2015, V. 58,

no. 8, pp. 721–725.

4. Iskhakov A.R. et al., Application of light-weight cementing slurries during well construction at Tatneft PJSC assets (In Russ.), Neftyanoye khozyaystvo = Oil Industry, 2021, no. 7, pp. 14–17, DOI: https://doi.org/10.24887/0028-2448-2021-7-14-17

5. Kateyev T.R., Improving the quality of well casing in oil fields of the Republic of Tatarstan (In Russ.), Zapiski Gornogo instituta, 2004, V. 159, no. 2, pp. 11–14.

6. Kozhevnikov E.V., Study of properties of cement slurries for horizontal well and sidetrack cementing (In Russ.), Vestnik Permskogo natsional’nogo issledovatel’skogo politekhnicheskogo universiteta. Geologiya. Neftegazovoe i gornoe delo = Perm Journal of Petroleum and Mining Engineering, 2015, no. 17, pp. 24–31. –

DOI: https://doi.org/10.15593/2224-9923/2015.17.3

7. GOST 1581-2019. Well portlandcements. Specifications.

8. GOST 21153.2-84. Rocks. Methods for determination of axial compression strength.

9. Fjaer E., Holt R.M., Horsund P. et al., Petroleum related rock mechanics, Elsevier, 2008, 514 p.

The choice of methods to enhance the productivity of production wells in terrigenous reservoirs is small compared to carbonate reservoirs. In most cases, oil companies use hydraulic fracturing. However, this is an expensive method associated with the risk of production from waterflooded reservoir intervals in fields at late stages of development. Wave stimulation of bottomhole formation zone is a possible option for this type of reservoirs. To evaluate the efficiency of this method, pressure transient analysis was conducted in 8 production and 2 injection wells in terrigenous reservoirs of TATNEFT PJSC. For this purpose, folds-of-increase in oil and fluid productivity of the wells were determined depending on changes in skin factor and water cut after stimulation. Incremental cumulative production and average production rates were determined based on production forecast performed in the Topaze software and from actual field data. The results imply substantial variations in incremental production rates and productivity (injectivity) increase resulting from discrepancy of input well data. On the average, fluid and oil productivity of production wells increased respectively by 83 and 62 %. Profitability indices for simulated and actual incremental production rates exceed 1,3 suggesting successful technology testing. It was confirmed that maximum effect of wave stimulation is achieved at the highest skin factors before stimulation, low water cut and reservoir pressure near its initial pressure. The technology ensures better performance given high-quality input data on the reservoir and individual intervals beeing available.

References

1. “PETROBUST” obeshchayet vtoruyu zhizn′ skvazhinam («PETROBUST» promises a second life for wells), URL: https://sk.ru/news/petrobust-obeschaet-vtoruyu-zhizn-skvazhinam/

2. Korzhenevskiy A.A., Korzhenevskiy A.G., Korzhenevskaya T.A., Pulse-wave technologies of net formations fracturing - the tangible ground to put the wells on a potential productivity (In Russ.), Neftepromyslovoye delo, 2021, no. 3, pp. 13–18, DOI: https://doi.org/10.33285/0207-2351-2021-3(627)-13-18

3. Tsi Chenchzhi et al., Predicting the permeability of the near-bottomhole zone during wave impact (In Russ.), Zapiski Gornogo instituta, 2022, V. 258, pp. 998–1007, DOI: https://doi.org/10.31897/PMI.2022.59

4. Mardegalyamov M.M., Marfin E.A., Vetoshko R.A., Change in permeability of a porous medium at ultrasonic action, Innovations in Geosciences-Time for Breakthrough, Proceedings of EAGE 8th International conference and exhibition, 9-12 April 2018, Saint Petersburg, Russian Federation / European Association of Geoscientists & Engineers, 2018, pp. 1–5, DOI: https://doi.org/10.3997/2214-4609.20180025834

5. Elkhoury J.E. el at., Laboratory observations of permeability enhancement by fluid pres-sure oscillation of in situ fractured, Journal of Geophysical Research, 2011,

V. 116, pp. 2–16, DOI: https://doi.org/10.1029/2010JB007759

6. Barabanov V.L., Nikolaev A.V., Problema spektra dominantnykh chastot pri seysmicheskom vozdeystvii na neftyanye zalezhi (The problem of the spectrum of dominant frequencies during seismic impact on oil deposits), Collected papers “Elastic wave effect on fluid in porous media, Proceedings of III International conference, Moscow, 2012, pp. 30–33.

7. Svalov A.M., Conditions of effective application of technologies of shock-wave impact on productive formations (In Russ.), Tekhnologii nefti i gaza, 2019, no. 5,

pp. 53–57, DOI: https://doi.org/10.32935/1815-2600-2019-124-5-53-57

8. Ganiyev R.F., Ukrainskiy L.E., Nelineynaya volnovaya mekhanika i tekhnologii. Volnovyye i kolebatel′nyye yavleniya v osnove vysokikh tekhnologiy (Nonlinear wave mechanics and technologies. Wave and oscillatory phenomena at the basis of high technologies), Moscow: Publ. of Institute of Computer Research, 2011, 780 p.

9. Ganiyev O.R., Ganiyev R.F., Ukrainskiy L.E., Rezonansnaya makro- i mikromekhanika neftyanogo plasta. Intensifikatsiya neftedobychi i povysheniye nefteotdachi: nauka i praktika (Resonance macro- and micromechanics of oil reservoir. Intensification of oil production and enhanced oil recovery: science and practice), Moscow - Izhevsk: Publ. of Institute of Computer Research, 2014, 255 p.

10. Iktisanov V.A., Sakhabutdinov R.Z., Evaluation of effectiveness of EOR and bottomhole treatment technologies using rate transient analysis (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2019, no. 5, pp. 72-76, DOI: https://doi.org/10.24887/0028-2448-2019-5-72-76

11. Allain O. et al., Dynamic data analysis: v. 5.20, KAPPA, 2018, 757 p.

12. Iktisanov V.A., On negative values of skin factor (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2020, no. 12, pp. 101–105, DOI: https://doi.org/10.24887/0028-2448-2020-12-101-105

The interwell tracer test method is a direct tool for studying the filtration flows from the injectors and for determining reservoir properties of the interwell space. It reliably identifies zones of low flow coefficient and determines the presence of the injected water breakthrough. Meanwhile, the early water flooding will be registered within a relatively short observation period, which does not require long-term monitoring of the tracer output to capture its main part. The presence of highly active zones of early water flooding has a negative impact on oil field development and is an essential criterion for allocating of additional drilling points. The applicability of the tracer method during infill drilling is a vital option as drilling of new wells is resource-intensive and the risks of discrepancies between predicted and actual measurements will decrease economic efficiency and may cause all incurred expenses to become irretrievable losses. Thus, searching for and utilizing tools to preemptively explore the area for additional drilling in order to mitigate risks and uncertainties is a key issue which will help to increase the success of bringing new wells into production. This paper presents a new approach to application of tracer tests for filtration zone investigation aimed to address aforementioned issue. It provides practical examples and conditions of the method’s usage, its output results and the criteria for interpretation. The results of the studies could be used to solve problems of infill drilling and reduce the risk of new producers being flooded with injected water.

References

1. Modiu S. et al., A field case study of an interwell gas tracer test for GAS-EOR monitoring, SPE-188363-MS, 2017, DOI: https://doi.org/10.2118/188363-MS

2. RD 39-0147428-235-89, Metodicheskoe rukovodstvo po tekhnologii provedeniya indikatornykh issledovaniy i interpretatsii ikh rezul’tatov dlya regulirovaniya i kontrolya protsessa zavodneniya neftyanykh zalezhey (Guidance on the technology for conducting indicator studies and interpreting their results to regulate and control the process of waterflooding of oil deposits), Groznyy: Publ. of SevKavNIPIneft’, 1989, 87 p. 

In oil field geology, the oil-water contact is the boundary separating oil from water in a reservoir, which is a zone of varying thickness containing oil and free water. An important task is to localize an oil-water contact, or position of the initial fluid contact in newly discovered deposits and fields under exploration, along with identification of oil-bearing layers. Oil fields in the Volga-Ural oil and gas province are characterized by complex geology and variety of oil reservoirs, including both conventional and unconventional reservoirs. Accurate determination of oil-water contact is of a great importance in volumetric estimation of reserves and serves as a significant parameter affecting the initial-oil-in-place distribution in the fields. In some cases, determination of fluid contact is complicated by a transition zone, particularly, in carbonate reservoirs. Based on the studies, the range of a transition zone variation can be from several meters to over 10 m. This fact adds complexity to oil-water contact determination. This paper presents approaches to identifying oil-water contact and analyzes the main problems affecting fluid contact substantiation. The results of the research will enable the use of the presented approach to fluid contact determination during reserves estimation, planning of prospecting and exploratory drilling, as well as geological exploration activities.

References

1. Bazhenova O.K. et al., Geologiya i geokhimiya nefti i gaza (Geology and geochemistry of oil and gas), Moscow: Nedra Publ., 2012, 460 p.

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3. Brod I.O., Eremenko N.A., Osnovy geologii nefti i gaza (Fundamentals of oil and gas geology), Moscow: Gostoptekhizdat Publ., 1957, 480 p.

4. Gridin V.A., Tumanova E.Yu., Geologiya nefti i gaza (Geology of oil and gas), Stavropol’: Publ. of NCFU, 2018, 202 p.

5. Zhdanov M.A., Neftegazopromyslovaya geologiya (Oil and gas field geology), Moscow: Gostoptekhizdat Publ., 1962, 536 p.

6. Ivanova M.M., Cholovskiy I.P., Bragin Yu.I., Neftegazopromyslovaya geologiya (Oil and gas geology), Moscow: Nedra Publ., 2000, 414 p.

7. Koveshnikov A.E., Geologiya nefti i gaza (Geology of oil and gas), Tomsk: Publ. of TPU, 2011, 168 p.

8. Kozhevnikova E.E., Geologiya i geokhimiya nefti i gaza (Geology and geochemistry of oil and gas), Perm: Publ. of PSNRU, 2020, 90 p.,

URL: http://www.psu.ru/files/docs/science/books/uchebnie-posobiya/kozhevnikova-geologiya-i-geoximiya-neft...

9. Cavel’ev V.A., Tokarev M.A., Chinarov A.S., Geologo-promyslovye metody prognoza nefteotdachi (Geological and industrial methods of oil recovery forecasting), Izhevsk: Publ. of Udmurt Universirty, Udmurtskiy universitet, 2008, 147 p.

10. Smelkov V.M., Ganiev R.R., Geologiya i geokhimiya goryuchikh iskopaemykh (Geology and geochemistry of fossil fuels), Kazan: Publ. of Kazan University, 2018, 288 p.

11. Solov’ev V.O. et al., Geologiya nefti i gaza (Geology of oil and gas), Khar’kov, 2012, 148 p.

12. Tekhnicheskaya instruktsiya po provedeniyu geofizicheskikh issledovaniy v skvazhinakh (Technical instructions for conducting geophysical surveys in wells), Moscow: Gosgeoltekhizdat Publ., 1963, 298 p.

13. Metodicheskie rekomendatsii po podschetu zapasov nefti i gaza ob’emnym metodom. Otsenka kharaktera nasyshchennosti po dannym GIS (Guidelines for the calculation of reserves of oil and gas by volumetric method. Assessment of the nature of saturation according to well logging): edited by Petersil’e V.I., Poroskun V.I., Yatsenko G.G., Moscow – Tver: Publ. of VNIGNI, 2003, 258 p.

14. Metodicheskie rekomendatsii po primeneniyu klassifikatsii zapasov i resursov nefti i goryuchikh gazov (Guidelines on the application of oil and combustible gas resources and reserves classification), Moscow: Publ. of Russian Ministry of Natural Resources, 2016, 33 p.

15. Dakhnov V.N., Interpretatsiya rezul’tatov geofizicheskikh issledovaniy razrezov skvazhin (Interpretation of the results of geophysical investigations of well sections), Moscow: Nedra Publ., 1980.

16. Koskov V.N., Koskov B.V., Geofizicheskie issledovaniya skvazhin i interpretatsiya dannykh GIS (Well logging and well logging data interpretation), Perm: PSTU, 2007, 317 p.

17. Maraev I.A., Kompleksnaya interpretatsiya rezul’tatov geofizicheskikh issledovaniy skvazhin (Comprehensive interpretation of well logging results), Moscow, 2013, 95 p.

18. Shaymardanova R.R., Geophysical methods control and definition of the oil-water contact (In Russ.), Mezhdunarodnyy zhurnal gumanitarnykh i estestvennykh nauk, 2017, no. 12, pp. 56–58.

19. Bachkov A.P., Bazarevskaya V.G., Anoshin D.V., Features of geological structure heavy oil field complicated palaeovalley (P-N) (In Russ.), Georesursy = Georesources, 2022, V. 24, no. 3, pp. 77–83, DOI: https://doi.org/10.18599/grs.2022.3.6

20. Khisamov R.S. et al., Geologicheskie osnovy poiskov i razvedki mestorozhdeniy sverkhvyazkoy nefti v tsentral’noy chasti Volgo-Ural’skoy neftegazonosnoy provintsii (Geological foundations of prospecting and exploration of deposits of super-viscous oil in the central part of the Volga-Ural oil and gas province), Kazan: Nasledie nashego naroda Publ., 2022, 183 p.

21. Khisamov R.S., Gatiyatullin N.S., Sharogorodskiy I.E. et al., Geologiya i osvoenie zalezhey prirodnykh bitumov Respubliki Tatarstan (Geology and development of natural bitumen deposits of the Republic of Tatarstan), Kazan’: FEN Publ., 2007, 295 p.

22. Khisamov R.S. et al., Water zones distribution in heavy oil reservoirs (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2017, no. 6, pp. 22–26,

DOI: https://doi.org/10.24887/0028-2448-2017-6-22-26

23. Vassoevich N.B., The theory of sedimentary-migration origin of oil (historical overview and current state) (In Russ.), Izvestiya AN SSSR. Ser. Geologiya, 1967, no. 11, pp. 135-156.

24. Gimatudinov Sh.K., Shirkovskiy A.M., Fizika neftyanogo i gazovogo plasta (Physics oil and gas reservoir), Moscow: Al’yans Publ., 2005, 311 p.

25. D’yakonova T.F. et al., Problems of the petrophysical validation of the original oil saturation of oil-wetting reservoirs from core and logs (In Russ.), Karotazhnik, 2019, no. 1, pp. 85–97.

The paper discusses the ways of improving well intervention solutions for oil reservoirs by implementing advanced energy-saturated materials. The paper reviews issues encountered in a conventional tubing-based technique including long execution periods, shortage of well servicing crews, complexity of equipment transportation and maintenance, inadequate reliability and quality control of the operations performed. The authors offer an innovative technique involving application of a logging cable and the next-generation energy-saturated materials. The paper details the design and operating concept of the new technology, including application of thermal gas-generators based on energy-saturated materials which produce the required pressure for setting packers in the wellbores. Laboratory and field test data are presented indicating feasibility and efficiency of the proposed technique. Particular attention is given to the benefits of the proposed technique compared to a conventional tubing-based method, including a shorter execution period, reduced financial expenses, improved reliability and safety of operations. The authors present technical characteristics of the equipment in use and the materials for experimental studies, which confirm viability and practicability of the proposed technology. Moreover, the authors recognize the importance of further development of this technology and expansion of its applicability, emphasizing the necessity for further research studies and engineering-and-process solutions to exploit the full potential of the innovative technology. Thus, this paper contributes substantially to the development of efficient and cost-effective oil production technologies aimed at improvement of performance and environmental sustainability of oil and gas prospecting and development processes.

References

1. Instructions ERB 2270-2023: Ekspluatatsiya pakera-gil’zy PGD-GRI-122(140)-35 (Operation of the packer-sleeve PGD-GRI-122(140)-35), Publ. of Bugul’ma Tatneft / TaTNIPIneft’, 2023, 46 p.

2. Mokeyev A.A. et al., Study of physical stability of energy-saturated compositions of chemically active element intended for oil well treatment (In Russ.), Vzryvnoye delo, 2012, no. 107-64, pp. 49-59.

3. Kosarev A.A. et al., Combustion products of solid propellant charges: assessment of the effectiveness of action on carbonate rocks (In Russ.), Vestnik Tekhnologicheskogo universiteta, 2015, V. 18, no. 17, pp. 77-79.

Consumption of corrosion inhibitors and demulsifiers in different oil fields can range from 60 to 100 % of total amount of oilfield chemicals used during oil production and treatment processes. Thereby, it is very important to study the effects of corrosion inhibitors on demulsification process and to select efficient combinations of demulsifiers and corrosion inhibitors to achieve a synergetic effect. The paper presents the results of studies aimed at determination of the effects of corrosion inhibitors TN-IK-8 and SNPKh-6201A on the performance of demulsifiers Khimtekhno-118A2, TN-DE-10A, Khimtekhno-118M3, TN-DEIK-5, TN-DE-16 and TN-DE-2A during breaking of oil emulsions of Devonian and Carboniferous deposits. Research findings enabled determination of various combinations of corrosion inhibitors and demulsifiers at appropriate dosages and settling temperatures. It was found that the sequence in which chemicals are added in many cases influences the efficiency of demulsification process, and should be selected for each particular demulsifier and inhibitor brand product. To reduce the consumption and, consequently, demulsifier costs, the most beneficial combinations of demulsifiers and corrosion inhibitors were selected for application in oil gathering systems. Application of certain combinations of corrosion inhibitors and demulsifiers in the oil gathering system can ensure 2 to 31 % reduction in demulsifier consumption while maintaining appropriate demulsifier performance. Final recommendations for possible percent reduction of demulsifier dosages when combined with corrosion inhibitors can be provided after pilot tests.

References

1. Tronov V.P., Promyslovaya podgotovka nefti (Field oil treatment), Kazan’: Fen Publ., 2000, 416 p.

2. Akhmetshina E.I. et al., Study of compatibility of demulsifiers and corrosion inhibitors (In Russ.), Interval, 2005, no. 6, pp. 46–48.

3. Ibragimov G.Z., Khisamutdinov N.I., Spravochnoye posobiye po primeneniyu khimicheskikh reagentov v dobyche nefti (Handbook on the use of chemical reagents in oil production), Moscow: Nedra Publ., 1983, 312 p.

4. Volkov A.A. et al., Some aspects relating to breaking of stable water-in-oil emulsions (In Russ.), Neftepromyslovoye delo, 2013, no. 5, pp. 40–42.

This paper explores the issues of processing automation of rock mechanical properties core testing used to ensure the safety of drilling, well operations, fracturing design, etc. Due to the expanded scope of studies and the increased volume of data for analysis, there is a growing need to optimise routine procedures during the pre-processing of experiment results for further analysis. The paper presents the experience of TatNIPIneft in the development of used approaches to automating the study of rock stress-related properties divided into three stages starting from fully manual data processing to the unified digital platform concept. The transition from discrete software units to an integrated solution is essential. It enables automation of routine operations, provides complex data analysis and fosters the improvement of laboratory efficiency. Development of such a solution required consideration of equipment specificities, data formats, calculation techniques and user requirements for reporting and analysis. The need to evaluate the results of core testing together with well log data requires the availability of certain digital tools. Their further improvement will help to increase efficiency of geomechanical modelling and optimise the oil and gas field development process. It is planned to extend the range of analysis tools to enable more in-depth investigation of rock mechanical behaviour patterns. Moreover, the authors consider the possibility of replicating the accumulated experience and developed algorithms applicable to other areas of core testing.

References

1. Ponomareva E.A., Digitizing core testing laboratory equipment (In Russ.), Vesti gazovoy nauki: nauchno-tekhnicheskiy sbornik, 2021, no. 1, pp. 125–128.

2. Kashirskikh D.V., Vakhrusheva I.A., Paromov S.V., Safin M.F., Digitalization concept of laboratory centers of Rosneft Oil Company. Case study of information system RN-LAB development (In Russ.), Neftyanoye khozyaystvo = Oil Industry, 2020, no. 2, pp. 79–83, DOI: https://doi.org/10.24887/0028-2448-2020-2-79-83

3. Certificate of state registration of a computer program no. 2021660419 RF GMS-CORE (GMS-CORE), Authors: Girfanov I.I., Usmanov I.T., Sotnikov O.S., Lutfullin A.A.

4. Lutfullin A.A., Girfanov I.I., Usmanov I.T., Sotnikov O.S., Software for geomechanical simulation (In Russ.), Neftyanoye khozyaystvo = Oil Industry, 2021, no. 7,

pp. 49–52, DOI: https://doi.org/10.24887/0028-2448-2021-7-49-52

The paper considers the development and application of machine learning methods for prediction of potential oil production rate of wells in extra-viscous oil (EVO) fields. This study is essential due to uncertainty associated with traditional prediction methods. The authors propose an innovative approach based on machine learning for automation and improved accuracy of the prediction process through analysis of historical and simulated data. The study is based on 567 wells data, including reservoir properties, production performance and parameters of geological and reservoir simulation models. Data preprocessing stage involved outlier removal, imputation of missing values and wells clustering using k-means algorithm. CatBoostRegressor algorithm for oil production rates prediction, with coefficient of determination R² = 0,785, resulted in the best output. Further analysis of feature importance and SHAP analysis confirmed physical validity of the model with identification of key factors (net pay thickness, oil saturated rock volume). The practical value of the research includes creation of a web interface enabling a convenient application of the model by reservoir engineers and geologists. This approach ensures real-time prediction of potential oil production rates to optimize EVO fields development strategies. Future researches entail integration of the model with reservoir simulations and extension of the training dataset to account for field production performance. Research findings are indicative of substantial increase in prediction accuracy (up to 33 %) compared to traditional methods, which confirms the efficiency of machine learning methods for prediction of potential oil production rate of wells in EVO fields of the Republic of Tatarstan.

References

1. Zakharov YA.V. et al., Opredeleniye optimal′nogo rezhima osvoyeniya parnykh gorizontal′nykh skvazhin kak odnogo iz vazhnykh etapov realizatsii tekhnologii parogravitatsionnogo drenirovaniya (Determination of the optimal mode of development of paired horizontal wells as one of the important stages of implementation of steam-assisted gravity drainage technology), Collected papers “Osobennosti razvedki i razrabotki mestorozhdeniy netraditsionnykh uglevodorodov” (Features of exploration and development of non-traditional hydrocarbon deposits), Proceedings of International scientific and practical conference, Kazan, 2–3 September 2015, Kazan: Ikhlas Publ., 2015, pp. 157–160.

2. Butler R.M., Steam-assisted gravity drainage: Concept, development, performance and future, Journal of Canadian Petroleum Technology, 1994, V. 33, no. 2,

pp. 44–50, DOI: https://doi.org/10.2118/94-02-05

3. Biglov R.R., Zaripov A.T., Shaykhutdinov D.K., Novyy podkhod k postroyeniyu geologicheskikh modeley zalezhey sverkhvyazkoy nefti (SVN) dlya usloviy sheshminskogo gorizonta Respubliki Tatarstan (A new approach to constructing geological models of extra-viscous oil (EVO) deposits for the conditions of the Sheshminsky horizon of the Republic of Tatarstan), Collected papers “Innovatsii v razvedke i razrabotke neftyanykh i gazovykh mestorozhdeniy” (Innovations in oil and gas exploration and development), Proceedings of International scientific and practical conference dedicated to the 100th anniversary of V.D. Shashin’s birth, 7–8 September 2016, Kazan, Part 1, Kazan′: Ikhlas Publ., 2016, pp. 258–260.

4. Butler R.M., Gravity drainage to horizontal wells, Journal of Canadian Petroleum Technology, 1992, V. 31, no. 4, pp. 31–37, DOI: https://doi.org/10.2118/92-04-02

5. Shaykhutdinov D.K., Sovershenstvovanie sistemy razrabotki zalezhey sverkhvyazkoy nefti Respubliki Tatarstan v usloviyakh vysokoy neodnorodnosti neftenasyshchennogo plasta (Improving the system for the development of super-viscous oil deposits in the Republic of Tatarstan in conditions of high heterogeneity of the oil-saturated formation): thesis of candidate of technical science, Bugul’ma, 2018.

6. Amerkhanov R.M., Gilyazov A.Kh., D’yakonov A.A. et al., Optimization of production well operation through combination of engineering approach, computer programming and machine learning methods (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2024, no. 8, pp. 94–99, DOI: http://doi.org/10.24887/0028-2448-2024-8-94-99

7. Prokhorenkova L. et al., CatBoost: unbiased boosting with categorical features, NeurIPS 2018: 32nd Conference on Neural Information Processing Systems, Dec 2-8, 2018, Montréal, Canada 2018, DOI: https://doi.org/10.48550/arXiv.1706.09516

2025 marks the 60th anniversary of the discovery of Russia's largest Samotlor oil and gas field, one of the flagships of the Russian oil and gas industry. This article briefly examines the history of the development of the Samotlor field, its current state and development prospects. The Samotlor field was discovered in 1965. As a result of further exploration 376 deposits were identified in 51 productive formations. At the present stage, geological exploration is aimed at the search and exploration of new fields in the JV1 formation and in the achimov formation. The field was put into development in 1969. By the beginning of 1978 half a billion tons of oil was produced. But since 1984 the field has been undergoing an intensive decline in oil production. Horizontal drilling, hydraulic fracturing, modern enhanced oil recovery (EOR) technologies, and involvement in the development of hard-to-recover reserves are actively used to maintain production. The prospects of the Samotlor field are related to the involvement of the PK group of formations into the development, drilling of undeveloped areas, optimization of development systems based on three dimensional digital modeling, carrying out geological and technological measures to launch an idle well stock, using modern technologies to intensify inflow, increase oil recovery, including polymer flooding, etc.

References

1. Bagautdinov A.K., Barkov S.L., Belevich G.K. et al., Geologiya i razrabotka krupneyshikh i unikal’nykh neftyanykh i neftegazovykh mestorozhdeniy Rossii (Geology and development of large and unique oil and gas fields in Russia): edited by Gavura N.N., Part 2, Moscow: Publ. of VNIIOENG, 1996, 352 p.

2. Istoriya Bol′shoy nefti. Samotlor. 1965-2015: Fotoal′bom (History of Big Oil. Samotlor. 1965-2015: Photo Album), Krasnoyarsk: IPK Publ., 2015, 176 p.

3. Nesterov, I.I., Salmanov F.K., Shpil′man K.A., Neftyanyye i gazovyye mestorozhdeniya Zapadnoy Sibiri (Oil and gas fields of Western Siberia), Moscow: Nedra Publ., 1971, 463 p.

4. Dopolneniye k tekhnologicheskomu proyektu razrabotki Samotlorskogo neftegazokondensatnogo mestorozhdeniya (l.u. Samotlorskiy, l.u. Samotlorskiy (severnaya chast′) i l.u. Yuzhno-Mykhpayskiy) (Supplement to the technological project for the development of the Samotlor oil and gas condensate field (Samotlorsky license area, Samotlorsky license area (northern part) and Yuzhno-Mykhpaysky license area)), Tyumen: Publ. of Tyumen Petroleum Research Centre LLC, 2023.

5. Yanin A.N., Retrospective review of development indices of West-Siberian greatest fields (In Russ.), Bureniye i Neft′, 2010, no. 7, pp. 58–61.

6. Tagirov K.D., Lytkin A.E., Pospelova T.A., Nasyrov I.I., Field experience of introducing low-volume physical and chemical EOR in JSC «Samotlorneftegaz» (In Russ.), Neft’ Gaz Novatsii, 2020, no. 10, pp. 22–27.

7. Morozovskiy N.A., Tagirov K.D., Obzor primenyaemykh tretichnykh MUN v Kompanii. Tekushchie vyzovy i perspektivy razvitiya (Review of tertiary EOR methods used in the Company. Current challenges and development prospects), Proceedings of Annual All-Russian scientific and practical conference “Nauka v proektirovanii i razrabotke neftyanykh mestorozhdeniy – Novye vozmozhnosti” (Science in Oil Reservoir Engineering and Development – New Opportunities), 22–23 June 2023, Tyumen: Publ. of Tyumen Petroleum Research Centre LLC, 2023.

8. Tagirov K.D., Gukaylo V.S., Zemtsov Yu.V. et al., Results of SPA-Well EOR field tests at the Samotlor field (In Russ.), Neftyanoye khozyaystvo = Oil Industry, 2025, no. 2, pp. 40–44, DOI: https://doi.org/10.24887/0028-2448-2025-2-40-44

The article considers issues related to the study of wettability of oil and gas reservoirs from various regions of Western Siberia using the example of the Tyumen formation deposits. The traditional wettability study technology is based on the OST 39-180-85 «Oil. Method for Determining the Wettability of Hydrocarbon-Containing Rocks» and reflects the quality of extraction, rather than the actual nature of wettability. The implementation of the USBM method into laboratory practice increases the information content of wettability laboratory study programs. The use of isolated core sampling technology and compliance with the requirements of the «Methodological Recommendations for the Collection and Analysis of Isolated Core» of SibBurMash Research and Development Enterprise (2022) ensures the implementation of comprehensive core study programs with increased information content. The results of special studies of the core of the Tyumen Formation reservoir rocks confirmed the presence of non-hydrophilic wettability for partial samples under study. The carbonatization of the void space, as well as the increased content of koalinite in clay cement, contribute to an increase in the hydrophobicity of reservoir rocks. The introduction of the technology of wetting restoration into the practice of laboratory work of petrophysical and filtration studies enables to obtain electrical and filtration properties of reservoir rocks that are close to the original properties of the oil and gas reservoir.

References

1. Sokolov A.V., Shubina A.V., Analysis of the reserves-to-production ratio for various stratigraphic complexes of Western Siberia (In Russ.), Georesursy = Georesources, 2023, V. 25, no. 1, pp. 45–50, DOI: https://doi.org/10.18599/grs.2023.1.5

2. Mikhaylov N.N., Motorova K.A., Sechina L.S., Geological factors of wettability of oil and gas reservoir rocks (In Russ.), Neftegaz.RU, 2016, no. 3(51), pp. 80–90.

3. Mamyashev V.G., Zadorina L.M., Shal’nykh G.S., Borkun F.Ya., Wettability and diffusion-adsorption activity of sedimentary rocks (In Russ.), Geologiya i geofizika, 1990, no. 7, pp. 95–103.

4. Mamyashev V.G., Zadorina L.M., Osobennosti vydeleniya i izucheniya gidrofobnykh porod-kollektorov (Features of the identification and study of hydrophobic reservoir rocks), Collected papers “Interpretatsiya dannykh geofizicheskikh issledovaniy skvazhin v Zapadnoy Sibiri” (Interpretation of geophysical well logging data in Western Siberia), Proceedings of ZapSibNIGNI, 1992, pp. 163–170.

5. Mamyashev V.G., Zadorina L.M., Effect of wettability on electrical and reservoir properties of terrigenous rocks, Proceedings of International Symposium of the Society of Core Analysts, 14-16 September 1998 (SCA –9843).

6. Mikhaylov N.N., Motorova K.A., Sechina L.S., Smachivaemost’ neftegazovykh plastovykh sitem (Wettability of oil and gas reservoir systems), Moscow: Publ. of Gubkin University, 2019, 360 p.

7. Anashkin A.R., Doroginitskaya L.M., Dergacheva T.N. et al., Petrophysical principles of classification of hydrophilic oil and gas reservoirs of Western Siberia by production parameters (In Russ.), Geofizika, 2001, no. S, pp. 77–82.

8. OST 39 180-85, Neft’. Metod opredeleniya smachivaemosti uglevodorodo-soderzhashchikh porod (Oil. Method for determining the wettability of hydrocarbon-containing rocks).

9. Author’s certificate SU 1022005 A1, Pore surface water-reppelancy treatment determination method, Authors: Tankaeva L.K., Dmitrievskiy A.N., Sechina L.S., Privalenko N.V., 1983.

10. Gudok N.S., Bogdanovich N.N., Martynov V.G., Opredelenie fizicheskikh svoystv neftevodosoderzhashchikh porod (Determination of the physical properties of oil-and-water-containing rocks), Moscow: Nedra Publ., 2007, 592 p.

11. Amott E., Observations relating to the wettability of porous rock, Trans. AIME, 1959, V. 216, pp. 156–162, DOI: https://doi.org/10.2118/1167-G

12. Donaldson E.C., Thomas R.D., Lorenz P.B., Wettability determination and its effect on recovery efficiency, SPE-2338-PA, 1969, DOI: https://doi.org/10.2118/2338-PA

13. Gil’manov Ya.I., Povyshenie dostovernosti opredeleniya podschetnykh parametrov slozhnopostroennykh kollektorov na osnove litologo-fatsial’nogo analiza po dannym GIS (Increasing the reliability of determining the calculation parameters of complex reservoirs based on lithological-facies analysis using well logging data): thesis of candidate of geological and mineralogical science, Tyumen, 2003.

14. Kovalev A.G., Kuznetsov A.M., Dzyubenko A.M., Pchelintsev P.G., Features of laboratory studies of low-permeability productive deposits (In Russ.), Geologiya nefti i gaza, 2001, no. 4, pp. 123-126.

15. Tekhniko-ekonomicheskoe obosnovanie koeffitsienta izvlecheniya po Ombinskomu mestorozhdeniyu (plast YuS2) (Feasibility study of the recovery factor for the Ombinskoye field (YuS2 formation)), Krasnodar: Publ. of ’’ROSNIPITERMNEFT’’, 1998.

16. Gil’manov Ya.I., Salomatin E.N., Vakhrusheva I.A., OOO TNNTs LLC experience in unconsolidated and poorly consolidated core analysis (In Russ.), Karotazhnik, 2019, no. 6(300), pp. 14–22.

17. Ashirov K.B., Tsivinskaya L.V., Fedosova O.I. et al., On the predominant hydrophobic nature of oil reservoirs (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 1982, no. 7.

18. Sakhibgareev R.S., Gidrofobizatsiya peschanikov na rannikh etapakh litogeneza, priznaki ee proyavleniya i znachenie dlya prognoza kollektorov (Hydrophobization of sandstones at early stages of lithogenesis, signs of its manifestation and significance for reservoir forecasting), Collected papers “Problemy regional’nogo i lokal’nogo prognoza kollektorov” (Problems of regional and local forecasting of collectors), Minsk: Publ. of BelNITRI, 1983, pp. 31–35.

19. Bantignies J.-L., dit Moulin Ch.C., Dexpert H., Wettability contrasts in kaolinite and illite clays: Characterization by infrared and X-ray absorption spectroscopies, Clays and Clay Minerals, 1997, V. 45, pp. 184–193, DOI: https://doi.org/10.1346/CCMN.1997.0450206

20. URL: http://www.irocktech.com.cn/en/services/

21. Gil’manov Ya.I., Shul’ga R.S., Shimanovskiy V.A., TNNTs experience in isolated core analysis (In Russ.), Karotazhnik, 2023, no. 5(325), pp. 37–46.

22. Metodicheskoe rukovodstvo po otboru i analizu izolirovannogo kerna (Guidelines for the selection and analysis of an isolated core), Tyumen’, 2022, 82 p.

Traditional drilling methods rely on controlling the bottomhole pressure by using drilling fluids in an open circulation system, which may lead to complication in conditions of a narrow pressure gradient range and unstable equivalent circulating density (ECD). Managed Pressure Drilling (MPD) is the innovative approach which includes the enclosed circulation system with the possibility to accurately manage the annular back pressure. This method ensures ECD control in various intervals of an open hole, preventing reservoir fluids from entering the borehole and eliminating the possibility of reservoir hydraulic fracturing. Managed Pressure Cementing (MPC) is applied in cases when it is impossible to reach an optimal downhole pressure during casing process. The technology creates safe conditions for casing runs, prevents cement losses and improves the overall quality of well casing. Implementation of MPD and MPC technologies on Vietsovpetro JV fields is driven by the specifics of geotechnical conditions, including abnormally pressured zones and loose rocks. The article covers the principles of managed pressure operations, its advantages and practical significance for improving the efficiency of drilling and cementing the wells in difficult conditions; provides examples of equipment application, including rotating control device and Coriolis flowmeter, as well as ECD control and adjustment methods; analyses MPD impact on rate of penetration, mud flow rate optimization and improvement of work safety; describes the principles of creating and selecting the optimal hydraulic model; includes data on reducing well construction time and specifics of performing the technological operations.

References

1. Basargin Yu.M., Bulatov A.I., Proselkov Yu.M., Oslozhneniya i avarii pri burenii neftyanykh i gazovykh skvazhin (Current issues and innovative solutions in the oil and gas industry), Moscow: Nedra Publ., 2002, 680 p.

2. Ryabchuk V.A., Serdobintsev Yu.P., Shmelev V.A., Krivosheeva N.N., Analysis of the application of managed downhole pressure drilling technology in drilling a wellbore in carbonate deposits (In Russ.), Molodoy uchenyy, 2019, no. 22(260), pp. 138–139.

3. Voytenko V.S., Upravlenie gornym davleniem pri burenii skvazhin (Rock pressure control when drilling wells), Moscow: Nedra Publ., 1985, 185 p.

4. Nauduri Sagar, Managed pressure drilling candidate selection: Dissertation, submitted to the Office of Texas A&M University, 2009, 134 p.,

DOI: https://doi.org/10.1016/B978-1-933762-24-1.50016-4

5. Povalikhin A.S., Kalinin A.G., Bastrikov S.N., Solodskiy K.M., Burenie naklonnykh, gorizontal’nykh i mnogozaboynykh skvazhin (Drilling of inclined, horizontal and multilateral wells), Moscow: TsentrLitNefteGaz Publ., 2011, 647 p.

6. Hossain M.E., Islam M.R., Drilling engineering, problems and solutions, Scrivener Publishing, 2018, 627 p., DOI: https://doi.org/10.1002/9781118998632

7. D’yachenko K.V., Managed pressure cementing: MPC method (In Russ.), Molodoy uchenyy, 2022, no. 20(415), pp. 18–19.

The ability of clay rocks to spontaneously disperse and swell complicates the entire drilling process. Inhibited solutions are used where the use of conventional clay solutions causes complications when drilling wells. The following complications may occur: scree and landslides, narrowing of boreholes, cavern formation caused by the swelling of clay rocks and their transition into solution. Clay sludge undergoes peptization and dispersion, which leads to thickening of the solution and deterioration of its parameters. The purpose of this study was to evaluate the effectiveness of the inhibited drilling mud (oil-based, thermally stabilized potassium chloride (OBTSPC)) when drilling unstable rocks in sediments of the red-colored stratum in a certain range of occurrence at a specific well. Conducting controlled experiments enabled to evaluate its ability to prevent complications during the drilling process, as well as the success of launching and cementing the production column. The effectiveness of the inhibited drilling mud OBTSPC was confirmed in the conditions of drilling unstable rocks in red-colored sediments in the range of 2000-2600 m at well Y1 of the Nebitdag licence area. The ability of the inhibited drilling mud OBTSPC was revealed which enables to maintain its structural and mechanical properties under conditions of high mineralization, penetrate into the interplane space of clays, preventing their hydration and swelling, and bind all the water in the solution into stable hydrates, which contributes to the stability and safety of the drilling process.

References

1. Pereira L.B., Sad C.M.S., Castro E.V.R. et al., Environmental impacts related to drilling fluid waste and treatment methods: A critical review, Fuel, 2020, V. 310, no. 1,

pp. 249–256, DOI: http://doi.org/10.1016/j.fuel.2021.122301

2. Gautam S., Guria C., Rajak V.K., A state of the art review on the performance of high-pressure and high-temperature drilling fluids: Towards understanding the structure-property relationship of drilling fluid additives, Journal of Petroleum Science and Engineering, 2022, V. 213, pp. 110–126, DOI: https://doi.org/10.1016/j.petrol.2022.110318

3. Abdelmjeed M., Saeed S., Ramadan A., Significance and complications of drilling fluid rheology in geothermal drilling: A review, Geothermics, 2021, V. 93, pp. 102–115, DOI: http://doi.org/10.1016/j.geothermics.2021.102066

4. Karakosta K., Mitropoulos A.C., Kyzas G.Z., A review in nanopolymers for drilling fluids applications, Journal of Molecular Structure, 2021, no. 5, pp. 128–141,

DOI: https://doi.org/10.1016/j.molstruc.2020.129702

5. Deryaev A.R., Regulation of rheological properties of weighted grouting solutions during cementing of deep wells under conditions of abnormally high reservoir pressure (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2024, no. 5, pp. 86–90, DOI: https://doi.org/10.24887/0028-2448-2024-5-86-90

6. Xiangyang Zhao, Daqi Li, Heming Zhu et al., Advanced developments in environmentally friendly lubricants for water-based drilling fluid: a review, RSC Advances, 2022, no. 12, pp. 22853–22868, DOI: https://doi.org/10.1039/d2ra03888a

7. Saleh T.A., Advanced trends of shale inhibitors for enhanced properties of water-based drilling fluid, Upstream Oil and Gas Technology, 2022, no. 8, pp. 456–478,

DOI: https://doi.org/10.1016/j.upstre.2022.100069

8. Ali M., Jarni H.H., Aftab A. et al., Nanomaterial-based drilling fluids for exploitation of unconventional reservoirs: A review, Energies, 2020, no. 13, pp. 398–417,

DOI: https://doi.org/10.3390/en13133417

9. Kapitonov V.A., Salikhov A.R., Evdokimov D.V. et al., Designing a procedure to assess the effect of process fluids on mudstone stability (In Russ.), Neft’, gaz, novatsii, 2023, no. 10, pp. 51–55.

10. Oseh J.O., Mohd N.M.N.A., Polymer nanocomposites application in drilling fluids: A review, Geoenergy Science and Engineering, 2023, V. 222, no. 3, pp. 211–416,

DOI: http://doi.org/10.1016/j.geoen.2023.211416

11. Qiang Li, Fuling Wang, Yanling Wang et al., Effect of reservoir characteristics and chemicals on filtration property of water-based drilling fluid in unconventional reservoir and mechanism disclosure, Environmental Science and Pollution Research, 2023, V. 30, pp. 55034–55043, DOI: https://doi.org/10.1007/s11356-023-26279-9

12. Mahmoud H., Hamza A., Nasser M.S., Hole cleaning and drilling fluid sweeps in horizontal and deviated wells: Comprehensive review, Journal of Petroleum Science and Engineering, 2020, V. 186, pp. 106–121, DOI: https://doi.org/10.1016/j.petrol.2019.106748

13. Wiśniowski R, Skrzypaszek K, Małachowski T., Selection of a suitable rheological model for drilling fluid using applied numerical methods, Energies, 2020, V. 13,

pp. 31–42, DOI: http://doi.org/10.3390/en13123192

14. Nasiru S.M., Teslim O., Insights into the application of surfactants and nanomaterials as shale inhibitors for water-based drilling fluid: A review, Journal of Natural Gas Science and Engineering, 2022, V. 92, pp. 44–49, DOI: http://doi.org/10.1016/j.jngse.2021.103987

15. Xiangru Jia, Xionghu Zhao, Bin Chen et al., Polyanionic cellulose/hydrophilic monomer copolymer grafted silica nanocomposites as HTHP drilling fluid-loss control agent for water-based drilling fluids, Applied Surface Science, 2022, V. 578, pp. 152–159, DOI: https://doi.org/10.1016/j.apsusc.2021.152089

16. Ikram R., Mohamed J.B., Sidek A. et al., Utilization of eco-friendly waste generated nanomaterials in water-based drilling fluids; State of the art review, Materials, 2021, V. 14, pp. 41–71, DOI: https://doi.org/10.3390/ma14154171

17. Deryaev A.R., Features of the construction of directed deep wells in Turkmenistan, Italian Journal of Engineering geology and environment, 2024, no. 1, pp. 35–47, DOI: https://10.4808/IJEGE.2024-01.O-03

18. Deryaev A.R., Drilling of directional wells in the fields of Western Turkmenistan, Grassroots Journal of Natural Resources, 2024, V. 7(2), pp. 347–369,

DOI: https://doi.org/10.33002/nr2581.6853/070218

19. Deryaev A.R., Borehole fastening during the plastic flow of salts using the active resistant method (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2024, no. 7,

pp. 89–93, DOI: https://doi.org/10.24887/0028-2448-2024-7-89-93

The paper presents a model of dependence of effective permeability of proppant pack on Reynolds number during fluid flow in pore space. In the process of model development, the results of measurements of β-factor and permeability coefficient for different proppants were analyzed, as well as the results of measuring the dependence of effective permeability of proppants at high values of Reynolds number of flow (almost before the occurrence of turbulent regime) with the use of the unique Stim-Lab equipment (USA). These data were published in the period from 2004 to 2012. An expression for the dependence of the effective permeability on the Reynolds number and the value of the β-factor was proposed, which satisfactorily describes the experimental results for a wide range of ceramic proppants. Recommendations are given for the use of the obtained results in various cases encountered in practice. For the calculation, it is possible to use parameters measured by standard means, which can be considered an advantage over the Barree and Conway model, which requires using proppant parameters determined exclusively on unique equipment (for example, effective permeability at an infinitely high filtration rate). The obtained universal dependence can be useful for specialists calculating the inflow of formation fluids into a well through a hydraulic fracturing crack in the initial periods of operation, as well as the inflow of gas and degassed oil over the entire period of operation.

References

1. Forchheimer P.H., Wasserbewegung durch Boden, Zeitschrift des Vereins deutscher Ingenieure, 1901, V. 45, No. 1, pp. 1782–1788.

2. Ceramic Proppant / CARBO Ceramics Inc., URL: https://www.carboceramics.com/products/ceramic-proppant

3. Products – ceramic proppants / Sintex International, URL: https://sintexminerals.com/en/products/proppants

4. Barree R.D., Conway M.W., Beyond beta factors: A complete model for Darcy, Forchheimer, and Trans-Forchheimer flow in porous media, Journal of Petroleum Technology, 2004, V. 57, URL: http://doi.org/10.2118/89325-MS

5. Lai B., Miskimins J.L., Wu Yu-Shu, Non-Darcy porous media flow according to the Barree and Conway model: Laboratory and numerical modeling studies,

SPE-122611-MS, 2012, DOI: http://doi.org/10.2118/122611-MS

6. Lopez-Hernandez H.D., Experimental analysis and microscopic and pore-level flow simulations to compare non-Darcy flow models in porous media, Colorado:

Colorado School of mines, 324 p.

7. Huang H., Ayoub J., Applicability of the Forchheimer equation for non-Darcy flow in porous media, SPE-102715-MS, 2006, http://doi.org/10.2118/102715-MS

8. Reynolds O., An experimental investigation of the circumstances which determine whether the motion of water shall be direct or sinuous, and of the law of resistance in parallel channels, Phil. Trans. Roy. Soc., 1883, V. 174, pp. 935–982, DOI: http://doi.org/10.1098/rstl.1883.0029

9. Landau L.D., Lifshits E.M., Teoreticheskaya fizika (Theoretical physics), V. VI. Gidrodinamika (Hydrodynamics), Moscow: Nauka Publ., 1986, 736 p.

10. Safiullin I.R., Bykov A.A., Izvekov O.Ya. et al., Research of ceramic proppant porosity and permeability changes under constrained compression (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2024, no. 10, pp. 83–87, DOI: https://doi.org/10.24887/0028-2448-2024-10-83-87

11. Li D., Engler T.W., Literature review on correlations on the non-Darcy coefficient, SPE-70015-MS, 2001, DOI: http://doi.org/10.2118/70015-MS

The main characteristics of unconventional reservoirs include high heterogeneity and anisotropy of the pore space, low permeability due to nanoscale pore channels, significant influence of capillary forces and diffusion, active mass exchange between phases, and the presence of solid, insoluble organic components in the rock matrix. These factors complicate the application of existing physical and mathematical models for accurately describing fluid flow, and affect the precision of recoverable hydrocarbon reserves assessments, including the effectiveness of various development strategies. One of the most important parameters of multiphase flow through porous media is relative phase permeability. Applying conventional laboratory techniques to determine relative phase permeability in these reservoirs is challenging due to the lengthy duration of studies and high errors in phase saturation estimation. This study aims to develop methodological approaches for the laboratory determination of relative phase permeability in low-permeability core samples using nuclear magnetic resonance assisted profiling to determine saturation during core flooding experiments. The research involves determining phase permeability in water-gas and oil-gas systems under reservoir pressure, as well as describing changes in the pore space structure of rocks during gas filtration. The influence of different fluid flow rates is demonstrated through both steady-state and unsteady-state tests on carbonate rocks and tight sandstones. The results obtained show good agreement with data from X-ray scanning experiments conducted on similar core models.

References

1. Prishchepa O.M., Aver’yanova O.Yu., Il’inskiy A.A., Morariu D., Neft’ i gaz nizkopronitsaemykh slantsevykh tolshch – rezerv syr’evoy bazy uglevodorodov Rossii (Oil and gas is low-permeability shale strata - a reserve of raw material base of hydrocarbons in Russia), Proceedings of VNIGRI, 2014, 322 p.

2. Davydova E.S., Pyatnitskaya G.R., Skorobogatov V.A., Soin D.A., Reserves, resources and prospects for commercial development of Achim gas-oil-bearing complex at north of Western Siberia (In Russ.), Vesti gazovoy nauki, 2019, no. 4(41), pp. 121–133.

3. Kurbanov A.K., A method for calculating the relative phase permeability of oil when filtering a mixture of oil, gas and water (In Russ.), Neftepromyslovoe delo, 2023, no. 1(649), pp. 55–59, DOI: https://doi.org/10.33285/0207-2351-2023-1(649)-55-59

4. Sander R., Pan Z., Connell L.D., Laboratory measurement of low permeability unconventional gas reservoir rocks: A review of experimental methods, Journal of Natural Gas Science and Engineering, 2017, V. 37, pp. 248–279, DOI: https://doi.org/10.1016/j.jngse.2016.11.041

5. Mukherjee M., Vishal V., Gas transport in shale: A critical review of experimental studies on shale permeability at a mesoscopic scale, Earth-Science Rev., 2023,

V. 244, DOI: https://doi.org/https://doi.org/10.1016/j.earscirev.2023.104522

6. Dacy J.M., Core tests for relative permeability of unconventional gas reservoirs, SPE-135427-MS, 2010, DOI: https://doi.org/10.2118/135427-MS

7. Yu-Liang Su, Ji-Long Xu, Wen-Dong Wang et al., Relative permeability estimation of oil − water two-phase flow in shale reservoir, Pet. Sci., 2022, V. 19, pp. 1153–1164, DOI: https://doi.org/https://doi.org/10.1016/j.petsci.2021.12.024

8. Alanazi A., Baban A., Ali M. et al., Residual trapping of CO2, N2, and a CO2-N2 mixture in Indiana limestone using robust NMR coreflooding: Implications for CO2 geological storage, Fuel, 2013, V. 353, DOI: https://doi.org/10.1016/j.fuel.2023.129221

9. Baban A., Hosseini M., Keshavarz A. et al., Robust NMR examination of the three-phase flow dynamics of carbon geosequestration combined with enhanced oil recovery in carbonate formations, Energy & Fuels, 2024, V. 38, pp. 2167–2176, DOI: https://doi.org/10.1021/acs.energyfuels.3c04674

10. Mitchell J., Howe A.M., Clarke A., Real-time oil-saturation monitoring in rock cores with low-field NMR, J. Magn. Reson., 2015, V. 256, pp. 34–42,

DOI: https://doi.org/https://doi.org/10.1016/j.jmr.2015.04.011

11. Mukhametdinova A.Z., Dorzhi D.B., Bakulin D.A. et al., Determination of relative phase permeability for the oil-gas system in low-permeability reservoirs of the Achimov deposits (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2024, no. 7, pp. 98–103, DOI: https://doi.org/10.24887/0028-2448-2024-7-98-103

12. Abragam A., The principles of nuclear magnetism, Clarendon Press, Oxford, 1961, DOI: https://doi.org/10.1063/1.3057238

13. Bloembergen N., Purcell E.M., Pound R.V., Relaxation effects in nuclear magnetic resonance absorption, Phys. Rev., 1948, V. 73, DOI: https://doi.org/10.1103/PhysRev.73.679

14. Straley C., Rossini D., Vinegar H.J. et al., Core analysis by low-field NMR, The Log Analyst, 1997, V. 38, pp. 84–94.

This paper presents the results of a study of combustion processes of an ammonia-nitrate composition with the following mass ratio of components: 72 % ammonia-nitrate (NH4NO3), 25 % epoxy binder and 3 % potassium dichromate (K2Cr2O7), used as a mixed solid fuel for enhanced oil recovery. This study predicts the fundamental ballistic characteristics of the energy material itself. In order to improve the efficiency and reliability of the ammonia-nitrate composition charges, a software module based on a multilayer neural network, implemented in the NeuroShell environment, was developed and verified. The module provides an accurate prediction of the combustion rate (average relative error up to 6 %) for various operating parameters: charge density (1,4-1,46 g/cm³), pressure (5-25 MPa) and charge diameter (36 mm). The possibility of modeling complex nonlinear dependencies is demonstrated, including a decrease in the combustion rate by 22-23 % with an increase in charge density and an increase in pressure by 75-79 %. A comparative analysis of the experimental data is carried out and key patterns are revealed, such as the dominant effect of pressure and structural changes on the combustion kinetics. A comparative analysis of the obtained dependencies of the combustion rate on pressure and charge density is carried out. It is established that the curves of the dependence of the combustion rate on pressure have a similar nonlinear character. The results obtained open up prospects for designing highly reliable solid propellant systems in conditions close to real oil production processes.

References

1. Mukhutdinov A.R., Vakhidova Z.R., Lyubimov P.E., Improving the efficiency of the TP-230 boiler using neural network technologies (In Russ.), Vestnik Kazanskogo tekhnologicheskogo universiteta, 2011, V. 14, no. 21, pp. 91–94.

2. Mukhutdinov A.R., Vakhidova Z.R., Efimov M.G., Modeling of the combustion process of solid fuel in a furnace device (In Russ.), Vestnik Kazanskogo tekhnologicheskogo universiteta, 2014, V. 17, no. 20, pp. 114–116.

3. Mukhutdinov A.R., Marchenko G.N., Vakhidova Z.R., Neyrosetevoe modelirovanie i optimizatsiya slozhnykh protsessov i naukoemkogo teploenergeticheskogo oborudovaniya (Neural network modeling and optimization of complex processes and high-tech thermal power equipment), Kazan: Publ. of Kazan State Power Engineering University, 2011, 296 p.

4. Mukhutdinov A.R., Efimov M.G., Safiullin R.I., Mefod’ev A.V., Neural network based software module for predicting combustion rate of mixed solid fuel (In Russ.), Vestnik tekhnologicheskogo universiteta, 2017, V. 20, no. 24, pp. 102–104.

5. Mukhutdinov A.R., Lubimov P.E., Application of a neural network model for revealing specific features and regularities of solid fuel burning process, Thermal Engineering, 2010, V. 57, no. 4, pp. 336–340, DOI: https://doi.org/10.1134/S0040601510040105

6. Mukhutdinov A.R., Okulin M.V., Development of a neural network programming module for predicting the strength properties of solid fuel, Chemical and Petroleum Engineering, 2011, V. 47, no. 3, pp. 266–269, DOI: https://doi.org/10.1007/s10556-011-9457-3

Mini hydraulic fracturing (minifrac) analysis is an analytical method for evaluating the efficiency of hydraulic fracturing fluid, closing pressure, instantaneous injection stop pressure, net pressure in the crack, crack geometry and filtration coefficients according to test injection data before the main hydraulic fracturing process. Initially, the methodology for analyzing mini hydraulic fracturing, which quantified the fracturing process according to estimates based on measured pressure reduction data, was formulated by Nolte and modified by Castillo. In 1988, and again in 1992, Mayer and Hagel developed a methodology for analyzing minifrac, which enabled to solve the fundamental equations of conservation of mass and momentum for liquids obeying a power law using equations of state for the propagation of a two-dimensional crack. Their proposed method did not assume that the crack width was proportional to the measured pressure. Instead, the underlying equations of mass and momentum were combined with the measured closing time to predict crack propagation characteristics. Using the crack geometry, pressure, fluid efficiencies, and filtration coefficients obtained by numerical methods, it became possible to determine which of the two-dimensional crack models (GDK, PKN or Ellipsoidal) most closely corresponds to the measured change in reservoir pressure and permeability. The results calculated by analytical methods are considered together with the measured pressure reduction data in order to correlate a number of crack characteristics, such as Young's modulus, crack resistance coefficient, friction multiplier, end effects, etc. The closing time can also be estimated with greater accuracy by clarifying these parameters.

References

1. Salimov V.G., Ibragimov N.G., Nasybullin A.V., Salimov O.V., Gidravlicheskiy razryv karbonatnykh plastov (Hydraulic fracturing of carbonate formations), Moscow: Neftyanoe khozyaystvo Publ., 2013, 472 p.

2. Salimov V.G., Nasybullin A.V., Salimov O.V., Proektirovanie gidravlicheskogo razryva plasta v sisteme Mayera (Design of hydraulic fracturing in the Mayer system), Moscow: Publ. of VNIIOENG, 2008, 156 p.

3. Meyer B.R., Hagel M., Simulated mini-frac analysis, Journal of Canadian. Petroleum Technology, 1988, V. 28, no. 5, DOI: http://doi.org/10.2118/89-05-06

4. Hagel M., Meyer B.R., Utilizing mini-frac data to improve design and production, Journal of Canadian Petroleum Technology, 1994, V. 33, no. 3,

DOI: http://doi.org/10.2118/94-03-03

5. Economides M., Oligney R., Valko P., Unified fracture design. Bridging the gap between theory and practice, Orsa Press, Alvin, Texas, 2002, 262 p.

6. Ibatullin R.R., Salimov V.G., Nasybullin A.V., Salimov O.V., Experimental study of fracture toughness (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2009, no. 6, pp. 54–57.

7. Mullayanov A.I., Salikhov A.R., Lobova E.Yu., Arzhantsev V.S., The study of the elastic properties of carbonate rocks of Kashir-Podolsk, Bashkir-Vereisk and Tournaisian deposits at Republic of Bashkortostan fields (In Russ.), Neftegazovoe delo, 2022, no. 6, pp. 139-152, DOI: https://doi.org/10.17122/ogbus-2022-6-139-152

8. Salimov O.V., Nasybullin A.V., Salimov V.G., Effect of multiple cracks of far fields on deposit hydrfracture success (In Russ.), Neftepromyslovoe delo, 2010, no. 10,

pp. 24–27.

9. Ibatullin R.R., Salimov V.G., Salimov O.V., Nasybullin A.V., Experimental determination of coefficient of gelled liquid leak through carbonaceous rocks (In Russ.), Oborudovanie i tekhnologii dlya neftegazovogo kompleksa, 2012, no. 6, pp. 22–25.

This article presents a comprehensive analysis of the factors influencing the effectiveness of acid treatments at oil fields in Eastern Siberia. The study examines key parameters such as the compatibility of oil with mineralized spacer fluids and acid compositions, as well as the potential formation of emulsions and their viscosity properties. The article also focuses on the impact of temperature changes in the oil during the transition of gas from a dissolved to a free state, which significantly affects the process end effectiveness of acid treatment. The experiential work was carried out to evaluate the interaction of the components and determine the conditions under which the formation of stable emulsions is minimized, thereby increasing the permeability of the reservoir. An important aspect of the study is the use of surfactants, which help to reduce the negative effects associated with these factors. The results of the study demonstrated that applying selected surfactants improves interactions between acids, oil, and mineralized spacer fluids, as well as stabilizes emulsion viscosity properties. Consequently, implementing these methods increases treatment efficiency, leading to higher well productivity and optimized development of oil fields in Eastern Siberia. These findings are vital for improving technological reliability and economic performance in regional oil extraction operations.

References

1. Glushchenko V.N., Ptashko O.A., Kharisov R.Ya., Denisova A.V., Kislotnye obrabotki. Sostavy, mekhanizmy reaktsii. Dizayn (Acid treatments. Compositions, reaction mechanisms. Design), Ufa: Gilem Publ., 2010, 392 p.

2. Rebinder P.A., Poverkhnostnye yavleniya v dispersnykh sistemakh. Fiziko-khimicheskaya mekhanika: Izbrannye trudy (Surface phenomena in dispersed systems. Physicochemical mechanics: Selected works), Moscow: Nauka Publ., 1978, 368 p.

Currently, there in an increase in a number of injection wells equipped with a downhole liquid pumping systems maintaining the formation pressure. One of the important engineering measures to improve the flooding efficacy is the conformance control (CC), with a special interest of a number of Rosneft Oil Company subsidiaries to «approachless» technologies which do not require withdrawal of the downhole pumping equipment. At the same time, the downhole liquid pumping well design restricts the use of conventional CC technologies without extensive testing or requires the development of new technologies. This work presents the results of development of a CC technology for downhole pumping systems which uses a blend of a sedimentogenic composition with a surfactant. The extensive studies showed that a composition containing sodium organic salts, when interacting with mineralized water, forms a colloidal suspension composed of solid thin particles. The solid phase size distribution depends on the calcium chloride concentration and total water salt content. The composition contains surfactants to keep dispersion phase suspended and prevent the premature sedimentation of colloid particles. The experiments have demonstrated that the composition developed possess adjustable dynamic viscosity and long-term sedimentation stability at different dilution ratios thereby minimizing packer space deposition risks. It is also non-strain-ageing, has an ability to provide an additional filtration resistance and should not have any negative effect on the oil gathering and preparation system.

References

1. Ardalin A.A., Golovacheva E.G., Intra-well formation fluid pumping for reservoir pressure maintenance at Samaraneftegas OGSC (In Russ.), Nauchno-tekhnicheskiy vestnik OAO “NK “Rosneft’”, 2010, no. 4, pp. 8–11.

2. Amirov A., Ardalin A., Timashev E., Downhole pumping of formation water (In Russ.), Neftegazovaya vertikal’, 2011, no. 11, pp. 80–82.

3. Kozhin V.N., Sergeeva E.V., Cherepanov V.G. et al., An integrated approach to development of a program of measures for levelling the injectivity profile of injection wells on the example of PJSC «Orenburgneft» field (In Russ.), Neftepromyslovoe delo, 2019, no. 4, pp. 8–12, DOI: https://doi.org/10.30713/0207-2351-2019-4(604)-8-12

4. Almaev R.Kh., Safonov E.N., Metody izvlecheniya ostatochnoy nefti na mestorozhdeniyakh Bashkortostana (Methods of extracting residual oil in Bashkortostan fields), Ufa: Publ. of Bashneft’, 1997, 245 p.

5. Baranov Yu.V. et al., The technology of using a fibrous-dispersed system is a new promising means of increasing oil recovery from heterogeneous formations with hard-to-recover oil reserves (In Russ.), Neftepromyslovoe delo, 1995, no. 2–3, pp. 65–71.

6. Gazizov A.Sh., Galaktionova L.A., Geuyuzov A.A., Enhancement of oil recovery at a late stage of field development using polymer-dispersed systems and other chemical reagents (In Russ.), Neftepromyslovoe delo, 1995, no. 2–3, pp. 29–34.

7. Gazizov A.Sh., Muslimov R.Kh., Nauchno-tekhnologicheskie osnovy povysheniya nefteotdachi plastov na mestorozhdeniyakh Tatarstana (Scientific and technological foundations for enhancing oil recovery at Tatarstan fields), Al’met’evsk, 1996, pp. 36–37.

8. Gazizov A.Sh., Nikolaev V.I., Polimerdispersnye kompozitsii dlya povysheniya okhvata plastov vozdeystviem (Polymer-dispersed compositions for increasing the coverage of formations by impact), Collected papers “Sostoyanie i perspektivy rabot v oblasti sozdaniya kompozitsiy PAV dlya povysheniya nefteotdachi plastov” (Status and prospects of work in the field of creating surfactant compositions for enhancing oil recovery), Moscow, 1987, pp. 74–83.

9. Gorbunov A.T., Buchenkov L.N., Shchelochnoe zavodnenie (Alkaline flooding), Moscow: Nedra Publ., 1989, 160 p.

10. Kovaleva G.A., Manyrin V.N., Shvetsov I.A., Primenenie kol’matiruyushchikh sostavov dlya povysheniya koeffitsienta okhvata (Use of colmatation compounds to increase the coverage coefficient), Proceedings of 4th scientific and production conference “Sostoyanie i perspektivy rabot po povysheniyu nefteotdachi plastov” (Status and prospects of work on enhanced oil recovery), Samara, 15–17 June 2000, Samara, 2000, pp. 28–31.

11. Kukin V.V., Shvetsov I.A., Gorbatova A.N. et al., On alignment of the injection well intake profile (In Russ.), Neftepromyslovoe delo, 1967, V. 18, pp. 30–35.

12. Muslimov R.Kh., Gazizov A.Sh., Nauchno-tekhnologicheskie osnovy povysheniya nefteotdachi zavodnennykh kollektorov (Scientific and technological foundations for enhancing oil recovery from flooded reservoirs), Proceedings of meeting “Kontseptsiya razvitiya metodov uvelicheniya nefteizvlecheniya” (Concept of development of methods for increasing oil recovery), Bugul’ma, 27–28 May 1996, Kazan, 1997, pp. 92–115.

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14. Patent RU 2125647 C1, Compound for oil recovery and method of making compound, Inventors: Pozdnyshev G.N., Manyrin V.N. et al.

15. Patent RU 2131513 C1, Composition for shutoff of water inflow in oil wells, Inventors: Abaturov S.V., Ramazanov D.Sh. et al.

16. Patent RU 2167281 C1, Method of nonuniform formation development, Inventors: Shvetsov I.A., Manyrin V.A. et al.

17. Pozdnyshev G.N., Novye emul’sionno-dispersionnye sistemy dlya dobychi nefti na osnove reagenta RDN (New emulsion-dispersion systems for oil production based on RDN reagent), Proceedings of 2nd scientific conference “Sostoyanie i perspektivy rabot po povysheniyu nefteotdachi plastov” (Status and prospects of work on enhanced oil recovery), Samara, 14–16 June 1998, Samara, 1998, pp. 19–22.

18. Red’kin I.I., Laboratornye i promyslovye issledovaniya protsessa kol’matatsii provodyashchikh kanalov porovo-treshchinovatykh kollektorov (Laboratory and field studies of the process of colmatation of conducting channels of porous-fractured reservoirs), Kuybyshev: Publ. of Giprovostokneft’, 1984, pp. 70–77.

19. Tarasyuk A.V., Galantsev I.N., Sukhanov V.N. et al., Gelling compositions for leveling the intake profile and selective isolation of water inflows (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 1994, no. 2, pp. 64–68.

20. Shvetsov I.A., Manyrin V.N., Fiziko-khimicheskie metody uvelicheniya nefteotdachi pri zavodnenii (Physical and chemical methods of enhanced oil recovery for water flooding), Samara: Rosing Publ., 2000, 336 p.

21. Ibatullin R.R., Khisametdinov M.R., Gaffarov Sh.K. et al., New technologies of increase in layers sweep by water flooding (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2007, no. 7, pp. 46–49.

22. Gershtanskiy O.S., Intensification of an oil recovery by application of temporarily blocking structures (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2004, no. 9, pp. 96–98.

23. Gorbunov A.T., Petrakov A.M., Kayumov L.Kh.
et al., Application of chemical reagents of Himeko-GANG JSC to enhance oil
recovery and intensify oil production (In Russ.), Neftyanoe khozyaystvo = Oil
Industry, 1997, no. 12, pp. 65–69.

The oil produced at the fields of Vietsovpetro JV has an increased paraffin content and a high pour point, which leads to risks in the operation of the oil and gas production, collection and transportation system: the wax formation in the tubing (pump pipes), treatment equipment and oil pipelines; a decrease in well flow rates and pipeline throughput; an increase in transportation pressure and impassability of oil pipelines. During the late stage of field development and related problems (a decrease in oil production and the temperature of the extracted products, the formation of wax) negatively affects oil production, which leads to high risks in field operation. A widely used method of combating wax in well tubing, equipment and oil pipelines is the treatment of oil with reagents – pour point depressants and wax inhibitors. This method is not always feasible for downhole treatment of products. The article analyzes the factors influencing the process of well product preparation, and on this basis proposes a technological solution for treating paraffin oil with a depressant additive by feeding it into gas-lift lines of wells at the offshore facilities of Vietsovpetro JV to ensure a safe and efficient production and transportation process. Pilot tests of the technical solution showed its effectiveness, which consists in reducing the oil freezing point and increasing the inter-cleaning period compared to feeding the reagent to the wellhead. In addition, an economic effect is achieved due to the lack of need to install downhole equipment for reagent supply.

References

1. Nguyen Van Thang, Pham Thanh Vinh, M.K. Rogachev et al., A comprehensive method for determining the dewaxing interval period in gas lift wells, Journal of Petroleum Exploration and Production Technology, 2023, no. 1, pp. 27–44, DOI: http://doi.org/10.1007/s13202-022-01598-8

2. Akhmadeev A.G., Pham Thanh Vinh, Le Dang Tam, Implementation of adaptive gathering systems as the method to optimize oil transportation at offshore field (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2019, no. 2, pp. 78–81, DOI: https://doi.org/10.24887/0028-2448-2019-10-104-107

3. Ахмадеев А.Г., Tong Canh Son, Pham Thanh Vinh, High-paraffin crude treatment technology by the pour point depressant at shelf fields (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2016, no. 10, pp. 115–117.

There is a current need to change approaches to managing the oil production process developed over more than half a century. The article proposes a concept for adaptive management of oil well stock equipped with electric vane pumps considering the high probability of operational complications. The core of the concept lies in the integration of predictive analytics, Internet of Things (IoT) technologies, and real time analysis of field data. A detailed analysis of equipment failure cases at a Western Siberia oilfield for the period 2018–2020 was conducted, identifying key parameters preceding malfunctions, including fluctuations in electric current, temperature, and pressure. Based on these findings, an adaptive control algorithm was developed to dynamically adjust pump operation modes in accordance with the predicted risk of complications. This approach improves the operational reliability of the artificial lift system and enables a reduction in operating expenses by 25 % and a decrease in downtime by 30 %. Special attention is paid to the verification of sensor data, the construction of digital twins, and the implementation of feedback mechanisms for automatic system response. The proposed methodology contributes to reducing unplanned failures and supports decision-making under uncertainty. Thus, the presented approach highlights the potential of digital transformation in oilfield operations management and facilitates the transition toward intelligent decision support systems within the framework of the smart oilfield concept.

References

1. Cherepovitsyn A.E., Tret’yakov N.A., Development of new system for assessing the applicability of digital projects in the oil and gas sector (In Russ.), Zapiski Gornogo instituta, 2023, V. 262, pp. 628–642.

2. Kuzmin M.I., Grekhov I.V., Gerasimov R.V., Autonomous asset: Concept and solutions (In Russ.), PRONEFT. Professional’no o nefti = PROneft. Professionally about Oil, 2023, no. 8(1), pp. 129–137, DOI: https://doi.org/10.51890/2587-7399-2023-8-1-129-137

3. Kamaletdinov R.S., Mechanical oil production: new challenges – new solutions (In Russ.), Delovoy zhurnal Neftegaz.RU, 2023, no. 4(136), pp. 32–37.

4. Chernova K.V., Aptykaev G.A., Shaydakov V.V., Operation of electrocentrifugal deep-well working barrels in the conditions of intensive scale (In Russ.), Sovremennye naukoemkie tekhnologii, 2007, no. 10, pp. 17–22.

5. Shangaraeva L.A., Methods for preventing scale in oil wells (In Russ.), Innovatsii v nauke, 2013, no. 27, pp. 163–167.

6. Saychenko L., Tananykhin D., Ashena R., Prevention of scale in the downhole equipment and productive reservoir during the oil well operation, Journal of Applied Engineering Science, 2021, V. 19, No. 2, pp. 363–368, DOI: https://doi.org/10.5937/jaes0-29696

7. Gerasimov R.V., Kuz’min M.I., Dubrovin A.N., Results of pilot field tests of equipment within the framework of the Autonomous Asset project (In Russ.), Inzhenernaya praktika, 2024, no. 1–2, pp. 48–50.

8. Certificate of state registration of a computer program no. 2019611336 RF. Sibintek. Prediktivnaya analitika: programma dlya EVM (Sibintek. Predictive analytics: computer program).

9. Patent US no. 20190317488. Predicting failures in electrical submersible pumps using pattern recognition: 12.04.2018.

10. Patent US no. 20070252717. System and method for real-time monitoring and failure prediction of electrical submersible pumps: 23.03.2006.

11. Patent CN no. 112983843. Intelligent control system and method for submersible electric pump: 18.06.2021.

12. Patent CN no. 112785091. Method for carrying out fault prediction and health management on oil field electric submersible pump: 11.05.2021.

13. Patent CN no. 212407002. Electric submersible pump unit monitoring and fault prediction device: 26.01.2021.

The article examines the problem of ensuring reliable and accident-free operation of marine terminals in the Russian Federation. It is shown that such facilities are characterized by a unique combination of two factors, on the one hand, an extremely low probability of emergency situations, and on the other hand, a significant amount of damage that may happen after the occurrence of an emergency situation. Based on retrospective studies of various technical condition management systems implemented during the operation of particularly hazardous industries, it was shown that the most promising system for marine oil terminals is the one based on the methodology of man-made protection proposed in the works of N.A. Makhutov. The article shows that the risk-oriented approach methods used today in practice, methods based on probabilistic assessments of failure rates and residual life, as well as practices for standardizing reserve factors in calculations for limit states have a certain imperfection that does not enable to guarantee accident free operation of the marine terminal. An algorithm for formalizing, creating and implementing the concept of man-made protection of marine oil terminals based on the methodology for assessing accumulated defects is proposed. The main elements of the system that will enable implementation of this algorithm are established.

References

1. Baza dannykh intsidentov s tankerami (Tanker Incident Database), URL: https://incidentnews.noaa.gov/incident/6223

2. Zanardi-Lamardo E., Bícego M.C., Weber R.R., The fate of an oil spill in São Sebastião channel: A case study, Brazilian Journal of Oceanography, 2013, V. 61,

pp. 93-104, DOI: https://doi.org/10.1590/S1679-87592013000200002

3. Statement of Basis: Star Enterprise Terminal, Pickett Road Facility, Fairfax, Virginia (PDF) (Report). Philadelphia, Pennylvania: EPA Region III. April 1998. Retrieved

24 July 2024.

4. Chile oil spill: 40,000 litres of diesel spilled into sea off Patagonia, URL: https://www.theguardian.com/environment/2019/jul/29/chile-oil-spill-40000-litres-of-diesel-spilled-i...

5. Oil spill from ship reaches East Coast Park, sea activities on Sentosa beaches halted, CAN, Retrieved 15 June 2024, URL: https://sg.trendquest.io/trending/2024/06/15/oil-spill-sentosa

6. Johor oil spill at Tanjung Langsat Port Terminal linked to pipeline leak during VLSFO transfer, URL: https://en.portnews.ru/news/375596/ (data obrashcheniya: 25.05.2025)

7. Makhutov N.A., Topical security issues of critical and strategic facilities (In Russ.), Zavodskaya laboratoriya. Diagnostika materialov, 2018, V. 84(1(I)), pp. 5–9,

DOI: https://doi.org/10.26896/1028-6861-2018-84-1-I-05-09

8. Makhutov N.A., Gadenin M.M., Analysis and control of the strength, useful life, and safe operation risks of power plants with various kinds of energy commodities

(In Russ.), Problemy mashinostroyeniya i nadezhnosti mashin = Journal of Machinery Manufacture and Reliability, 2022, no. 1, pp. 47-56,

DOI: https://doi.org/10.31857/S0235711922010060

9. Makhutov N.A., Abrosimov N.V., Gadenin M.M., Provision of safety – the priority in the sphere of fundamental and applied research (In Russ.), Ekonomicheskiye i sotsial′nyye peremeny: fakty, tendentsii, prognoz, 2013, no. 3(27), pp. 46-70.

10. Gorban′ N.N., Ivanets V.K., Vasil′yev G.G., Leonovich I.A., Prospects for parametric standardization of mechanical safety of oil and gas facilities (In Russ.), Neftyanoye khozyaystvo = Oil Industry, 2024, no. 9, pp. 137–143, DOI: https://doi.org/10.24887/0028-2448-2024-9-137-143

11. Order of Rostekhnadzor no. 387 “Ob utverzhdenii Rukovodstva po bezopasnosti “Metodicheskiye osnovy analiza opasnostey i otsenki riska avariy na opasnykh proizvodstvennykh ob′′yektakh” (On approval of the Safety Guide “Methodological principles for hazard analysis and accident risk assessment at hazardous industrial facilities”)

12. Gorban′ N.N., Vasil′yev G.G., Leonovich I.A., Assessment of the possibility of resource management of a marine terminal tank by regulating the intensity of cyclic loading (In Russ.), Neftyanoye khozyaystvo = Oil Industry, 2024, no. 6, pp. 107–111, DOI: https://doi.org/10.24887/0028-2448-2024-6-107-111

13. Safety Guide no. 478 “Metodicheskie rekomendatsii po provedeniyu kolichestvennogo analiza riska avariy na opasnykh proizvodstvennykh ob»ektakh magistral’nykh nefteprovodov i nefteproduktoprovodov” (Guidelines for conducting a quantitative analysis of the risk of accidents at hazardous production facilities of main oil pipelines and oil product pipelines)

14. Order of Rostekhnadzor no. 331 “Ob utverzhdenii Rukovodstva po bezopasnosti “Metodika ustanovleniya dopustimogo riska avarii pri obosnovanii bezopasnosti opasnykh proizvodstvennykh ob»ektov neftegazovogo kompleksa” (On approval of the Safety Guide “Methodology for determining the permissible risk of an accident while justifying the safety of hazardous production facilities of the oil and gas complex”.

15. Decision of April 29, 2022 in case No. A32-8101/2022, URL: https://sudact.ru/arbitral/doc/FViay0lslHrZ/

16. Koptev D.V., Norilsk spill: Lessons and consequences (In Russ.), Bureniye i neft′, 2020, no. 7–8, pp. 3–9.

17. Makhutov N.A., Gadenin M.M., Kompleksnyy analiz resursa i bezopasnosti VVER v shtatnykh i avariynykh situatsiyakh (Comprehensive analysis of the resource and safety of WWER in normal and emergency situations), URL: https://textarchive.ru/c-1530834.html

18. Makhutov N.A., Nauchnaya baza kompleksnogo obosnovaniya bezopasnosti morskikh podvodnykh truboprovodov i ob′′yektov (Scientific basis for comprehensive justification of safety of offshore underwater pipelines and facilities), URL: https://expertmore.ru/pub_60.html

19. Gorban’ N.N., Razrabotka metodiki monitoringa malotsiklovoy ustalosti v lokal’nykh geometricheskikh defektakh stenki rezervuarov morskikh terminalov nefti (Development of a technique for monitoring low-cycle fatigue in local geometric defects in the walls of tanks at sea oil terminals): thesis of candidate of technical science, Moscow, 2021.

20. Gorban N.N., Vasil’ev G.G., Leonovich I.A., Sal’nikov A.P., Methodology for the quantitative assessment of the parameters of the cyclic operation of reservoirs of a large unit volume of sea terminals (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2021, no. 10, pp. 102-107, DOI: http://doi.org/10.24887/0028-2448-2021-10-102-107

There is a need for digitalization of the industry system for product conformity assessment used by Transneft PJSC by automating the verification of compliance with the requirements of regulatory documents (RD) and technical documents (TD) of product manufacturers. The compliance of equipment with the requirements of RD shall be confirmed using digital (SMART) certification. SMART-certification requires the development of relevant subsystems and software modules enabling the use of RD and TD in SMART-format. The modernization of the Information System for Regulatory Document Management (ISRDM) should involve the development of a digital certification subsystem, including a module for creating the templates of TD SMART-versions and a module for SMART-analysis of product manufacturers’ TD. TD SMART-versions should be formed by selecting from the list and filling the previously created templates of TD SMART-versions. TD SMART-versions will be generated in a template filling tool of the Core Product Automated Control System (CP ACS). Mutual integration of ISRDM and CP ACS will enable to transfer the templates of TD SMART-versions from ISRDM to CP ACS with their placement in an open resource for filling data by third-party users in the template filling service. One of the essential requirements for creating an information environment for the SMART-certification is that the templates of TD SMART-versions created in ISRDM and the TD SMART-versions generated in CP ACS should comply with PNST 864-2023 «Smart (SMART) standards. General provisions». The paper addresses the all aspects of creating a digital certification subsystem in ISRDM.

References

1. Aralov O.V. et al., Automatic control of processes for products conformity assessment applied in Transneft (In Russ.), Nauka i tehnologii truboprovodnogo transporta nefti i nefteproduktov = Science & Technologies: Oil and Oil Products Pipeline Transportation, 2018, V. 8, no. 4, pp. 426–435, DOI: https://doi.org/10.28999/2541-9595-2018-8-4-426-435

2. V’yunov S.I., Aralov O.V., Tuzov V.Yu., Investigation of the possibility to create a SMART standard of the GS type of Transneft PJSC and subsequent SMART certification of equipment (In Russ.), Nauka i tehnologii truboprovodnogo transporta nefti i nefteproduktov = Science & Technologies: Oil and Oil Products Pipeline Transportation, 2024, V. 14, no. 5, pp. 470–480, DOI: https://doi.org/10.28999/2541-9595-2024-14-5-470-480

3. V’yunov S.I., Buyanov I.V., Kontseptsiya tsifrovogo razvitiya sistemy upravleniya kachestvom produktsii v truboprovodnom transporte nefti i nefteproduktov (The concept of digital development of the quality management system for products in pipeline transportation of oil and oil products), Proceedings of XIX International scientific and practical conference “Truboprovodnyy transport – 2024” (Pipeline Transport – 2024), Ufa, 20–22 November 2024, V. 1, pp. S. 225–227.

4. “TechExpert”: the path to SMART standards (In Russ.), Ekspozitsiya Neft’ Gaz, 2022, no. 5(90), pp. 80–81.

5. Dmitrieva S.Yu., Basic principles for SMART standards development (In Russ.), Standarty i kachestvo, 2021, no. 12(1014), pp. 22–25.

6. Artemova V.R., Dmitrieva S.Yu., Techexpert SMART: Creating documents in smart format (In Russ.), Standarty i kachestvo, 2023, no. 3(1029), pp. 48–53.

7. AO “Kodeks”: Promyshlennost’ nuzhdaetsya v umnykh standartakh («Kodeks» JSC: Industry needs smart standards), 2021, URL: https://kodeks.ru/news/read/promyshlennost-nujdaetsya-v-umnyh-standartah

8. Sysoeva E.A., Rozhkova T.A., Digital technologies in the products conformity assessment (In Russ.), Kompetentnost’, 2019, no. 8, pp. 20–25.

9. Unguryan E., SMART standards (In Russ.), Standarty i kachestvo, 2021, no. 12, pp. 26-28.

10. Kolmykov E.A., Vorontsova Yu.V., Vorontsova A.N., How to go to smart (machine-readable) standards (In Russ.), Izvestiya VolgGTU, 2022, no. 1, pp. 17–20,

DOI: https://doi.org/10.35211/1990-5297-2022-1-260-17-20

11. Loibl A., Manoaran T., Nagarajan A., Procedure for the transfer of standards into machine-actionability, Journal of Advanced Mechanical Design, Systems, and Manufacturing, 2020, V. 14, no. 2, DOI: https://doi.org/10.1299/jamdsm.2020jamdsm0022

12. Ehring D., Luttmer I., Pluhnau R., Nagarajah A., SMART standards – concept for the automated transfer of standard contents into a machine-actionable form, Proceedings of 31st CIRP Design Conference 2021 (CIRP Design 2021), DOI: https://doi.org/10.1016/j.procir.2021.05.025