Many tasks of exploration and development of mineral deposits, solved using modern information technologies, require a unified information system of geological and geophysical data (UIS GGD). At present, the presence of the UIS GGD is becoming a necessary condition for creating a geological model of the deposit. Such a system is impossible without the development of a unified database of geological, geophysical and field data, including both geological and geophysical data with a management system, as well as algorithms (programs) for evaluating data quality and data mining. Data mining algorithms for their evaluation and automatic interpretation involve working with multidisciplinary knowledge and are based on a wide range of methods of modern applied mathematics and theoretical physics. The methodology of developing a UIS GGD and their intelligent automated interpretation should combine integrated, systemic and multidisciplinary approaches. With a multidisciplinary approach, it is assumed that the information obtained using complex and systematic approaches is not only summarized in the form of new additional information, but also influences the sources of information themselves. With a multidisciplinary approach, both the total information received from various sources and the information received by each individual source as a result of the feedback between the total useful information about the oil (gas) deposit and the information received by individual sources should acquire new qualities. The work of the UIS GGD involves the use of an interactive multi-user mode with an approved regulation of user priorities. At the same time, the multi-user mode assumes the possibility of creating many versions of data and the availability of regulations for approving one of them as a working one.

References

1. Kozyar V.F., Afanas’ev V.S., Borodin Zh.P. et al., Sistema avtomatizirovannoy obrabotki dannykh GIS pri razvedochnom burenii na neft’ i gaz “Podschet” (System for automated processing of data from geophysical surveys of wells during exploratory drilling for oil and gas “Podschet”), Collected papers “Avtomatizirovannaya obrabotka dannykh geofizicheskikh i geologo-tekhnologicheskikh issledovaniy neftegazorazvedochnykh skvazhin i podschet zapasov nefti i gaza s primeneniem EVM” (Automated processing of data from geophysical and geological-technological studies of oil and gas exploration wells and calculation of oil and gas reserves using a computer), Moscow: Publ. of Mingeo SSSR, Soyuzpromgeofizika, 1989, pp. 18 - 26.

2. Sokhranov N.N., Aksel’rod S.M., Obrabotka i interpretatsiya s pomoshch’yu EVM rezul’tatov geofizicheskikh issledovaniy neftyanykh i gazovykh skvazhin (Processing and interpretation of geophysical survey results of oil and gas wells using a computer), Moscow: Nedra Publ., 1984, 255 p.

3. Ellanskiy M.M., Kholin A.I., Zverev G.N., Petrov A.P., Matematicheskie metody v gazoneftyanoy geologii i geofizike (Mathematical methods in gas-oil geology and geophysics), Moscow: Nedra Publ., 1972, 208 p.

4. Shein Yu.L., Pantyukhin V.A., Kuz’michev O.B., Algoritmy modelirovaniya pokazaniy zondov BKZ, BK, IK v plastakh s zonoy proniknoveniya (Algorithms for modeling probe readings, lateral logging and induction logging in formations with a penetration zone), Collected papers “Avtomatizirovannaya obrabotka dannykh geofizicheskikh i geologo-tekhnologicheskikh issledovaniy neftegazorazvedochnykh skvazhin i podschet zapasov nefti i gaza s primeneniem EVM” (Automated processing of data from geophysical and geological-technological studies of oil and gas exploration wells and calculation of oil and gas reserves using a computer), Moscow: Publ. of Mingeo SSSR, Soyuzpromgeofizika, 1989, pp. 75-81.

5. Guberman Sh.A., Izvekova M.L., Kholin A.I., Using a pattern recognition algorithm to solve field geophysics problems (In Russ.), Doklady AN SSSR, 1964, V. 154, no. 5, pp. 1082-1083.

6. Zverev G.N., Dembitskiy S.I., Otsenka effektivnosti geofizicheskikh issledovaniy skvazhin (Evaluating the effectiveness of geophysical well surveys), Moscow: Nedra Publ., 1982, 223 p.

7. Latyshova M.G., D’yakonova T.F., Tsirul’nikov V.P., Dostovernost’ geofizicheskoy i geologicheskoy informatsii pri podschete zapasov nefti i gaza (Reliability of geophysical and geological information when calculating oil and gas reserves), Moscow: Nedra Publ., 1986, 121 p.

8. Samarskiy A.A., Mikhaylov A.P., Matematicheskoe modelirovanie: Idei. Metody. Primery (Mathematical modelling: Ideas. Methods. Examples), Moscow: Fizmatlit Publ., 2001, 320 p.

9. Pel’megov R.V., Kudelin A.G., Heuristic methods and technologies of automated quality control of well logging (In Russ.), Geoinformatika, 2014, no. 2, pp. 35-43.

10. Johnson N.L., Leone F.C., Statistics and experimental design in engineering and the physical sciences, Wiley, 1977, 1090 p.

11. Kheyfets L.I., Neymark A.V., Mnogofaznye protsessy v poristykh sredakh (Multiphase processes in porous media), Moscow: Khimiya Publ., 1982, 320 p.

12. Nesterov S.A., Bazy dannykh. Intellektual’nyy analiz dannykh (Database. Data Mining), St. Petersburg: Publ. of SPbPU, 2011, 272 p.

13. Burikova T.V., Savel’eva E.N., Khusainova A.M. et al., Lithological and petrophysical characterization of Middle Carboniferous carbonates (a case study from north-western oil fields of Bashkortostan) (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2017, no. 10, pp. 18–21, DOI: https://doi.org/10.24887/0028-2448-2017-10-18-21

14. Cosentino L., Integrated reservoir studies, Paris: TECHNIP ed., 2001, 400 p.

15. Ellanskiy M.M., Povyshenie informativnosti geologo-geofizicheskikh metodov izucheniya zalezhey nefti i gaza pri ikh poiskakh i razvedke (Improving the information content of geological and geophysical methods for studying oil and gas deposits during their search and exploration), Moscow: Tekhnika Publ., 2004, 112 p.

In terrigenous rocks, feldspars are one of the main rock-forming minerals presented in the form of clastic grains, their autigenic varieties are rarely found. In the process of burial of sandy deposits, feldspars grains and fragments of volcanic rocks are most susceptible to changes and dissolution under the action of acidic pore waters. Feldspars are transformed into illite and then into kaolinite. Depending on the degree of dissolution of feldspars grains, their effect on reservoir properties is determined. As a rule, a number of other catagenetic transformations occur in parallel with this process, but the effect of dissolution of feldspars grains on the formation of final permeability can be decisive. Sandstones and siltstones mainly represent the rocks of the studied object; the mass shales fraction does not exceed 30%. Sandstones are medium- and fine-grained, the detrital material in them has a diverse shape: well-rounded and semi-rounded formations, angular fragments and chip-like relics of leached grains. Siltstones are mainly coarse-grained, the proportion of feldspars is 48–50%. According to the results of facies analysis, it was found that the rocks of the studied sediments were formed mainly in the conditions of three facies: delta plains and the periphery of estuarine bars; an active channel; and a beach. In order to ensure the process of modeling the reservoir properties testing of classification models was performed, according to the results of which the choice of a tool for petrophysical modeling of filtration heterogeneity was justified. Clarification of the permeability of the rocks of the object under consideration made it possible to more accurately characterize the spatial filtration heterogeneity, on the basis of which, using a capillary model of the transition zone, the results of assessing the nature of reservoir saturation were clarified, and oil-water contacts correlated with the results of well tests were substantiated.

References

1. Dmitrievskiy A.N., Sistemnyy litologo-geneticheskiy analiz neftegazonosnykh osadochnykh basseynov (System lithological and genetic analysis of oil and gas sedimentary basins), Moscow: Nauka Publ., 1982, 230 p.

2. Dmitrievskiy A.N., Lithological-genetic analysis and its role in predicting oil and gas content of sedimentary basins (In Russ.), Geologiya nefti i gaza, 1979, no. 12, pp. 13-19.

3. Ermolova E.P., Orlova N.A., Surkova G.I., Chepikov K.R., Postsedimentatsionnye preobrazovaniya porod-kollektorov (Post-sedimentation transformations of reservoir rocks), Moscow: Nauka Publ., 1972, 90 p.

4. Tiab D., Donaldson E C., Petrophysics: theory and practice of measuring reservoir rock and fluid transport, Elsevier Inc., 2004, 926 p.

5. Belyakov E.O., Mukhidinov Sh.V., Ispol’zovanie obobshchennykh zavisimostey dlya postroeniya petrofizicheskikh modeley fil’tratsionno-emkostnykh svoystv s otsenkoy granichnykh parametrov vydeleniya kollektorov i opredeleniya ikh kharaktera nasyshchennosti (Using the generalized relationships for constructing petrophysical models of reservoir properties estimation of reservoir boundary parameters and determine their nature saturation), Collected papers “Petrofizika slozhnykh kollektorov: problemy i perspektivy” (Petrophysics of complex reservoirs: problems and prospects), Moscow: Publ. of EAGE Geomodel’, 2015, 383 p.

6. Belyakov E.O., Frantsuzov S.E., Mukhidinov Sh.V. et al., Probabilistic model of the distribution of rocks pore space fluid saturation as a base of specification of petrophysical models of reservoir properties (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2013, no. 12, pp. 48–50.

7. Mukhidinov Sh.V., Belyakov E.O., Involving the results of petrographic analysis of thin sections when justifying the methodology for isolating reservoirs in terrigenous rocks with secondary mineral formation processes (a study of one of the deposits in Eastern Siberia) (In Russ.), Izvestiya vysshikh uchebnykh zavedeniy. Neft’ i gaz, 2018, no. 1, pp. 28-35.

8. Mukhidinov Sh.V., Belyakov E.O., Zhukovskaya E.A., Ibragimova S.V., Feature approach of petrophysical support log data interpretation for zeolite-containing clastic rock of Western Siberia (In Russ.), Geofizika, 2018, no. 4, pp. 53-58.

Currently, for every oil producing company, an urgent problem is replenishing the resource base of oil. Along with exploration in new, poorly studied areas and improvement of methods for extracting hydrocarbons from developed deposits, an urgent task is to identify and search for new complex objects confined to non-anticlinal type traps. Such objects may contain hydrocarbon reserves, both in discovered fields and in zones of their formation near the area of hydrocarbon accumulation. The majority of non-anticline traps on the territory of Udmurtia are predicted in the Lower Carboniferous terrigenous formation, mainly in the Visean stage. This formatiom is the second in terms of hydrocarbon reserves within Udmurtia, and the predominant number of structures controlling deposits in this interval are anticlinal. In the process of prospecting, appraisal and exploration, non-anticline traps were also mapped, having a complex structure and sharp lithological heterogeneity. In this regard, insufficient attention was paid to the study of their boundaries and configuration. In addition, the existing methods of studying such objects do not allow mapping their boundaries with a high level of reliability. This paper presents a method for mapping the boundaries of non-anticline oil traps having an underlying erosive surface at the base, based on the combination of standard conventional reservoir modeling techniques and identified patterns between geological and geophysical parameters within the terrigenous formation. When modeling the cyclicity of sedimentation, the proposed method takes into account the different rate of compensation of the underlying erosional surface by sediments, which makes it possible to predict the intervals of formation of non-anticlinal traps more reliably.

References

1. Patent RU 2787499 C1. Method for mapping a non-anticlinal oil trap, Inventors: Istomina N.G., Mirsaetov O.M., Kolesova S.B., Savel’ev V.A.

2. Zoloeva G.M., Denisov S.B., Bilibin S.I., Geologo-geofizicheskoe modelirovanie zalezhey nefti i gaza (Geological and geophysical modeling of oil and gas deposits), Moscow: Maks Press Publ., 2008, 172 p.

3. Pavlova T.Yu., Korkin K.M., Purtova T.N. et al., Sovremennye predstavleniya o geologii i neftenosnosti Udmurtii (Modern ideas about the geology and oil content of Udmurtia), Izhevsk, 2001, pp. 83-88.  

4. Shpilevaya I.K., Trofimova E.V., Furman V.F., Istomin A.G., Some structural features of the Visean incisions in Udmurtia (In Russ.), Geologiya nefti i gaza, 2001, no. 6, pp. 40–43.

5. Savel’ev V.A., Neftegazonosnost’ i perspektivy osvoeniya resursov nefti Udmurtskoy Respubliki (Oil and gas potential and prospects of development of oil resources of the Udmurt Republic), Moscow - Izhevsk: Publ. of Institute of Computer Science, 2003, 287 p.

6. Kamaev G.K., Istomina N.G., Perspektivnye ob»ekty, svyazannye s erozionnymi formami verkhnedevonsko-turneyskogo intervala Arlanskogo paleoshel’fa (Promising objects associated with erosional forms of the Upper Devonian-Tournaisian interval of the Arlan paleoshelf), Proceedings of IX Scientific and practical conference, Izhevsk: Publ. of Institute of Computer Science, 2019, pp. 219-233.

7. Istomina N.G., Yarullin K.R., Perspektivy poiska novykh lovushek nefti i gaza neantiklinal’nogo tipa (Prospects for searching for new oil and gas traps of non-anticlinal type), Proceedings of XI International scientific and practical conference, Izhevsk: Publ. of Institute of Computer Science, 2021, pp. 129-135.

In old oil-bearing areas, the acute issue is to replenish the depleted resource base through additional exploration of already developed fields, when additional reserves can quickly be brought into development using the existing infrastructure. For example, in the Volga-Ural province, at the initial stages of exploration and development of fields, the main attention was paid to highly productive Lower Carboniferous and Devonian formations. The formations and deposits of the Middle and Upper Carboniferous and Permian sediments were explored concurrently by the residual principle. This was partly determined by the low productivity of wells in these formations. This led to uncertain identification of genuine contacts and associated deposits and the adoption of a reference initial fluid contact level for an indefinite period. The authors give an example how reference contact levels lead to fragmentation of the main structure into domes with different contacts, and consequent decrease in reserves. A graphical representation of the dynamics of changes in deposit areas was proposed in previous publications. In general, graphs of this kind reflect changes in areas as exploration progresses. The closer the dependence on the graph to ordinate axis, the more identified the upper horizons can be considered. With the help of such graphs, it is possible, without unnecessary labor costs, to analyze the underexploration and outline measures for the priority of additional exploration of the upper sections. From the experience of analyzing the movement of reserves of multi-formations fields at the first stages, the fact of insufficient knowledge on the middle part of the oil and gas section, mainly carbonate (Okskian, Lower Bashkirian deposits), has been established. It is shown that proposed approach can speed up the identification of productive intervals and deposits of different sizes.

References

1. Sobornov K.O., The advantaged hydrocarbons: What does it mean and where to find them (In Russ.), Nedropol’zovanie XXI vek, 2022, no. 1, pp. 36–42.

2. Voevodkin V.L., Lyadova N.A., Okromelidze G.V. et al., Experience and prospects of slim hole construction on LUKOIL-PERM oilfields (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2018, no. 12, pp. 98–102, DOI: https://doi.org/10.24887/0028-2448-2018-12-98-102

3. Fursov A.Ya., Molodtsova E.V., Expert review as a continuation of field studies and improvement of reliability of HC reserves (In Russ.), Nedropol’zovanie XXI vek, 2019, no. 4, pp. 26–29.

4. Fursov A.Ya., Molodtsova E.V., Shubina A.V., Estimation of the possibility of hydrocarbon reserves growth in durably developed fields (In Russ.), Nedropol’zovanie XXI vek, 2020, no. 3, pp. 104–109.

5. Fursov A.Ya., Galimova A.F., Comparative assessment and analysis of the causes of reserves change during exploration and development of multilayer fields (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2022, no. 9, pp. 46–48, DOI: https://doi.org/10.24887/0028-2448-2022-9-46-48

For the first time, the feasibility of transmitting electromagnetic signal at a rate exceeding 6 bit/s in the horizontal hole section with displacement of over 1500 m from the vertical axis is demonstrated for land wells, assuming the well is constructed with a casing extended to the productive formation top. Achieved volume of data transmission using the proposed signal transmission method with the required data density of two points per meter while drilling at a rate of 30 m/hour for following data, measured downhole while drilling: three curves of electrical resistivity, correction for density Rho, photoelectric factor Pe, density and porosity, density images (raster imaging), natural gamma, acoustic and density calipers, annular pressure, bottomhole temperature, as well as the service status data of the downhole tools. The influence of antenna positioning on signal strength and data transmission reliability has been explored. The most effective method involves utilizing the casing string as an antenna for land wells with a three-casing configuration and a horizontal section. This results in a stable signal effect with a consecutive amplitude attenuation over a distance exceeding 1.5 km in the productive formation. Factors affecting signal stability and limitations of electromagnetic telemetry application are discussed.

References

1. Zhdaneev O.V., Zuev S.S., Challenges for the Russian energy sector until 2035 (In Russ.), Energeticheskaya politika, 2020, no. 3(145), pp. 12-23, DOI: https://doi.org/10.46920/2409-5516_2020_3145_12

2. Zhdaneev O.V., Frolov K.N., Scientific and technological priorities of the fuel and energy complex of the Russian Federation until 2050 (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2023, no. 10, pp. 6-13, DOI: https://doi.org/10.24887/0028-2448-2023-10-6-13

3. Zhdaneev O.V., Zaytsev A.V., Prodan T.T., Possibilities for creating Russian high-tech bottomhole assembly (In Russ.), Zapiski Gornogo instituta, 2021, V. 252, pp. 872-884, DOI: https://doi.org/10.31897/PMI.2021.6.9

4. Zhdaneev O.V., Zaytsev A.V., Lobankov V.M., Metrologicheskoe obespechenie apparatury dlya geofizicheskikh issledovaniy (In Russ.), Zapiski Gornogo instituta, 2020, V. 246, pp. 667-677, DOI: https://doi.org/10.31897/PMI.2020.6.9

5. Zhdaneev O.V., Frolov K.N., Drilling technology priorities in Russia (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2020, no. 5, pp. 42–48,

DOI: https://doi.org/10.24887/0028-2448-2020-5-42-48

6. Kohnke C., Liu L., Streich R., Swidinsky A., A method of moments approach to modeling the electromagnetic response of multiple steel casings in a layered Earth, Geophysics, 2017, V. 83, no. 2, pp. 81–96, DOI: https://doi.org/10.1190/geo2017-0303.1

7. Jiefu Chen, Shanjun Li, MacMillan C. et al., Long range electromagnetic telemetry using an innovative casing antenna system, SPE-174821-MS, 2015,

DOI: https://doi.org/10.2118/174821-MS

8. Jiefu Chen, Shubin Zeng, Qiuzhao Dong, Yueqin Huang, Rapid simulation of electromagnetic telemetry using an axisymmetric semianalytical finite element method, Journal of Applied Geophysics. – 2017. – 137. – C. 49–54. - DOI: https://doi.org/10.1016/j.jappgeo.2016.12.006

9. Xia M.Y., Chen Z.Y. et al., Attenuation predictions at extremely low frequencies for measurement-while-drilling electromagnetic telemetry system, IEEE Transactions on Geoscience and Remote Sensing. – V. 31. - C. 1222–1228. - DOI: https://doi.org/10.1109/36.317441

10. Wilton D.R., Champagne N.J., Evaluation and integration of the thin wire kernel, IEEE Transactions on Antennas and Propagation, 2006, V. 54, pp. 1200–1206,

DOI: https://doi.org/10.1109/TAP.2005.872569

11. Maurer H.M., Hunziker J., Early results of through casing resistivity field tests, Petrophysics, 2020, V. 41, pp. 309–314.

12. Gorgots V.D., New methods and technologies for designing the processes of construction of wells in complex mining and geological conditions (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2011, no. 4, pp. 16-20.

13. Zaynullin A.I., On the effectiveness of horizontal wells in the development of oil fields (In Russ.), Problemy ekonomiki i upravleniya neftegazovym kompleksom, 2007, no. 10, pp. 23-31.

14. Mingazov A.N., A new milestone of Russian logging-while-drilling technology development (In Russ.), Burenie i neft’, 2023, no. 3, pp. 3-8.

15. Lu C., Jiang G., Wang Z., The development of and experiments on electromagnetic measurement while a drilling system is used for deep exploration, Journal of Geophysics and Engineering, 2016, V. 13, no. 5, pp. 824–831, DOI: http://doi.org/10.1088/1742-2132/13/5/824

The formation of a stable emulsion due to the penetration of water-based drilling fluids into the formation is one of the reasons of the decrease of new oil wells performance. It is impossible to prevent completely the penetration of drilling fluids and their filtrates into the formation. Therefore, the research was carried out to develop a method for preventing the formation of stable emulsions during the terrigenous formation exposing on the fields in Eastern Siberia. The materials from publications in the scientific and technical literature were used in the work. The optimal method of achieving the goal that is conforming to the geological conditions was found based on extensive experience. The application features of alkylbenzene sulfonat (sulfonol) in a mineralized environment were taken into account. Physical modeling of the interaction of the mineralized drilling fluid and its filtrate with crude oil demonstrated a possibility of formation of stable highly viscous emulsions. The laboratory studies and experiments were carried out to study the effect of sulfonol on the parameters and properties of the drilling fluid. The adding of sulfonol prevented the formation of stable emulsions during physical modeling of the interaction of the drilling fluid and its filtrate with crude oil. Filtration experiments were carried out to determine a core permeability coefficient after exposure to model drilling fluid filtrates and emulsion models with and without the addition of sulfonol on identical core columns under conditions simulating reservoir. There was a significant increase in the core permeability coefficient. Thus, the ability of sulfonol to prevent the formation of stable highly viscous emulsions when interacting with crude oil was confirmed. The considered method for improving the composition of mineralized drilling fluid is characterized by ease of implementation and low cost.

References

1. Akhmetshin M.A., Issledovanie vliyaniya poverkhnostno-aktivnykh veshchestv na obrazovanie i razrushenie vodoneftyanoy emul’sii v poristoy srede (Investigation of the influence of surfactants on the formation and destruction of water-oil emulsion in a porous medium), Collected papers “Burenie skvazhin, razrabotka i ekspluatatsiya neftyanykh mestorozhdeniy Turkmenii” (Well drilling, development and operation of oil fields in Turkmenistan), Moscow: Nedra, 1965 Publ., pp. 84–95.

2. Akhmetshin M.A., Solomatin G.G., Vliyanie slabokontsentrirovannykh vodnykh rastvorov Sul’fonola NP-1 na ostatochnuyu vodonasyshchennost’ prizaboynoy zony plasta (The influence of weakly concentrated aqueous solutions of Sulfonol NP-1 on the residual water saturation of the bottomhole formation zone), Collected papers “Burenie skvazhin, razrabotka i ekspluatatsiya neftyanykh mestorozhdeniy Turkmenii” (Well drilling, development and operation of oil fields in Turkmenistan), Moscow: Nedra, 1965 Publ., pp. 96-107.

3. Stepanyants A.K., Vskrytie produktivnykh plastov (Opening of productive formations), Moscow: Nedra Publ., 1967, 416 p.

4. Bennon D.B., Thomas F.B., Bennon D.W., Bietz R.F., Fluid design to minimize invasive damage in horizontal wells, Journal of Canadian petroleum technology, 1996, no. 9, pp. 45–52, DOI: https://doi.org/10.2118/96-09-02

5. Glushchenko V.N., Obratnye emul’sii i suspenzii v neftegazovoy promyshlennosti (Inverse emulsions and suspensions in the oil and gas industry), Moscow: Interkontakt - Nauka Publ., 2008, 725 p.

6. Glushchenko V.N., Silin M.A., Neftepromyslovaya khimiya (Oilfield chemistry), Part 3. Prizaboynaya zona plasta i tekhnogennye faktory ee sostoyaniya (Bottom-hole formation zone and technogenic factors of its condition), Moscow: Interkontakt Nauka Publ., 2010, 650 p.

7. Myslyuk M.A., Salyzhin Yu.M., Bogoslavets V.V., Selection of drilling fluid optimal formulation for productive layers drill-in (In Russ.), Stroitel’stvo neftyanykh i gazovykh skvazhin na sushe i na more, 2012, no. 3, pp. 35–39.

8. Nikolaeva L.V., Vasenyova E.G., Buglov E.N., Features of drilling in production horizons at oil fields in Eastern Siberia (In Russ.), Vestnik IrGTU, 2012, no. 9, pp. 68 – 71.

9. Myslyuk M.A., Kisil’ I.S., Bodnar R.T. et al., Some aspects referring to control of surface phenomena while opening productive layers (In Russ.), Stroitel’stvo neftyanykh i gazovykh skvazhin na sushe i na more, 2015, no. 3, pp. 20–27.

10. Yangirov F.N., Yakhin A.R., Dikhtyar’ T.D. et al., Study of surfactants used in well drilling (In Russ.), Problemy sbora, podgotovki i transporta nefti i nefteproduktov, 2018, no. 1, pp. 61–67.

11. Gomora-Figueroa A.P., Camacho-Velazquez R.G., Guadarrama-Cetina J., Guerrero-Sarabia T.I., Oil emulsions in naturally fractured porous media, Petroleum, 2018, no. 5, pp. 215-226, DOI: https://doi.org/10.1016/j.petlm.2018.12.004

12. Bragina O.A., Tashkevich I.D., Akchurin R.Kh. et al., Problems of primary opening during exploration, development and operation of the Verkhnechonsky gas-condensate-oil field (Irkutsk region) (In Russ.), Stroitel’stvo neftyanykh i gazovykh skvazhin na sushe i na more, 2021, no. 4, pp. 31–37,

DOI: https://doi.org/10.33285/0130-3872-2021-4(340)-31-37

13. Babayan E.V., Burovye tekhnologii (Drilling technologies), Krasnodar: Sovetskaya Kuban’ Publ., 2005, 584 p.

14. Kondrashev O.F., Features of film oil destruction by surfactant solutions (In Russ.), Neft’ i gaz, 2013, no. 2, pp. 34–39.

The article is devoted to the study of new approaches to the application of the acoustic method for continuous monitoring of well cementing integrity (scientific research was carried out with the support of the Russian Science Foundation). It is noted, there are a huge number of natural and man-made factors affecting the integrity of the casing fastening. Improving and optimizing existing approaches, models and methods for assessing the condition of a field facility, accident risks, computer implementation and modeling are the most urgent tasks for companies and enterprises, including at the state level. The authors proposed a new principle of crack detection. This approach will improve the efficiency of oil and gas production in difficult operating conditions and will help to predict the destruction of the cement stone at early stages. This will increase safety at work due to the ability to identify and manage risks, as well as make more informed decisions on the further operation. The possibility of using a pulsed acoustic wave transmission method to determine the presence of cracks in a cement stone is shown. The results obtained can be used in the creation of promising ultrasonic devices for conducting research and production monitoring, as well as a control of fluid phases in oil and gas wells. In further research, proposals will be formed on the expediency of developing applied research and planning promising research projects, which will be aimed at finding new principles and ways to create modern types of devices and hardware complexes for energy efficient technologies using new ultrasonic systems.

References

1. Huseynov R., Babayev J., Sadikoglu K. et al., Water breakthrough effect on well productivity and skin factor change, SPE-189033-MS, 2017,

DOI: https://doi.org/10.2118/189033-MS

2. Zalyatdinov A.A., Khuzina L.B., Abdrakhmanov G.S., Analysis of relationship between quality of isolation of thief formations and casing leakage problems (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2018, no. 1, pp. 36-37, DOI: https://doi.org/10.24887/0028-2448-2018-1-36-37

3. Lutoev P., Kuznetsov D., Nikishin I. et al., The use of chromate desorption systems to optimize the position of the wells relative to the contact boundaries during the development of oil rim fields, SPE-206488-MS, 2021, DOI: https://doi.org/10.2118/206488-MS

4. Brigante M., Sumbatyan M.A., Acoustic methods for the nondestructive testing of concrete: A review of foreign publications in the experimental field (In Russ.), Defektoskopiya = Russian Journal of Nondestructive Testing, 2013, no. 2, pp. 52–67.

5. Myshkin Yu.V., Metody i sredstva povysheniya effektivnosti akusticheskogo kontrolya trub (Methods and means of increasing the efficiency of acoustic inspection of pipes): thesis of candidate of technical science, St. Petersburg, 2020.

6. Ryden N., Park C.B., Ulriksen P., Miller R.D., Lamb wave analysis for non‐destructive testing of concrete plate structures, Proceedings of Symposium on the Application of Geophysics to Engineering and Environmental Problems 2003, 2003, pp. 782–793, DOI: https://doi.org/10.4133/1.2923224

7. Froelich B., Multimode evaluation of cement behind steel pipe, J. Acoust. Soc. Am., 2008, v. 123, article no. 3648, DOI: https://doi.org/10.1121/1.2934929

The article examines the experience of drilling directional wells in Turkmenistan, using the latest advanced technologies, in order to increase the extraction of gas and oil from productive horizons in hard-to-reach coastal zones of the coastal waters of the Caspian Sea. One of the priority tasks being solved today by the oil and gas industry of Turkmenistan to increase oil production volumes is the comprehensive modernization of production, the widespread introduction of new technologies and highly efficient equipment. The relevance lies in the application of innovative drilling methods for efficient oil production from hard-to-reach horizons, which is becoming a strategic necessity in the context of the development of the oil industry in the country. The purpose of this study was to analyse the effectiveness of the simultaneous separate operation method in the context of hydrocarbon production in one of the fields of Turkmenistan. The use of the innovative technologies allows to increase the production potential, both by extracting hard-to-reach oil from long-exploited fields, and by putting deep-lying oil horizons into development. Currently, the oil industry of Turkmenistan is facing the issue of involving in the active development hard-to-recover oil reserves, the bulk of which is located in low-permeability reservoirs. The results of the study indicated that the introduction of advanced technologies and equipment in the process of well drilling and completingt in Turkmenistan had a profound impact on oil production. It has led not only to increased efficiency and reduced well construction time, but also increased oil production. This work results can be used to accelerate the development of fields in difficult-to-develop shallow waters and reduce costs during their drilling, as well as to increase oil produced, in order to develop the field in an accelerated manner, without sacrificing oil recovery coefficient.

References

1. Orazmetova A., Development of innovative technologies in Turkmenistan (In Russ.), Vestnik nauki = Science Bulletin, 2023, V. 2, no. 6 (63), pp. 858–860.

2. Deryaev A.R., Analysis of the opening of zones with abnormally high reservoir pressures in the oil and gas fields of the Western part of Turkmenistan (In Russ.), SOCAR Proceedings Special, 2023, no. 2, pp. 22–27, DOI: http://doi.org/10.5510/OGP2023SI200871

3. Huszar T., Wittenberger G., Skaverkova E., Warning signs of high-pressure formations of abnormal contour pressures when drilling for oil and natural gas, Processes, 2022, V. 10(6), http://doi.org/10.3390/pr10061106

4. Qun Lei, Yun Xu, Zhanwei Yang et al., Progress and development directions of stimulation techniques for ultra-deep oil and gas reservoirs, Petroleum Exploration and Development, 2021, V. 48(1), pp. 221–231, DOI: http://doi.org/10.1016/S1876-3804(21)60018-6

5. Al Saadi A.J., Naidu R.N., Challenges of drilling deep wells in a complex overburden with severe depletion and experiences from Caspian sea, SPE-214057-MS, 2023, DOI: https://doi.org/10.2118/214057-MS

6. Deryaev A.R., Features of forecasting abnormally high reservoir pressures when drilling wells in the areas of Southwestern Turkmenistan (In Russ.), SOCAR Proceedings Special Issue, 2023, no. 2, pp. 7–12, DOI: http://doi.org/10.5510/OGP2023SI200872

7. Deryaev A.R., Drilling of horizontal wells in Western Turkmenistan (In Russ.), SOCAR Proceedings Special Issue, 2023, no. 2, pp. 32–40, DOI: http://doi.org/10.5510/OGP2023SI200877

8. Khakimzyanov I.N., Yusupkhodzhaev M.A., Khakimzyanova O.I., Sheshdirov R.I., Customizing TATNEFT’s horizontal drilling technology for oil production from mature Uzbekistan fields (In Russ.), Neftyanaya Provintsiya, no. 1(25), 2021, pp. 101-113, DOI https://doi.org/10.25689/NP.2021.1.101-113

9. Orazmukhamedov D.Ya., Ekonomicheskaya i tekhnicheskaya tselesoobraznost’ tekhnologii gorizontal’nogo bureniya skvazhin (Economic and technical feasibility of horizontal well drilling technology), Collected papers “Perspektivy realizatsii mezhdistsiplinarnykh issledovaniy” (Prospects for the implementation of interdisciplinary research), Proceedings of conferences, 2023, pp. 32–36, DOI: https://doi.org/10.58351/230221.2023.47.37.002

10. Abdyrakhmanov A.Ch., The use of innovative technologies in the extraction of hydrocarbons in Turkmenistan (In Russ.), Innovatsii i investitsii, 2019, no. 8, pp. 194–196.

11. Deryaev A.R., Well trajectory management and monitoring station position borehole (In Russ.), SOCAR Proceedings Special Issue, 2023, no. 2, pp. 1–6,

DOI: http://doi.org/10.5510/OGP2023SI200870

12. Deryaev A.R., Selection of drilling mud for directional production and evaluation wells (In Russ.), SOCAR Proceedings, 2023, no. 3, pp. 51–57,

DOI: http://doi.org/10.5510/OGP20230300886

13. Eren T., Suicmez V.S., Directional drilling positioning calculations, Journal of Natural Gas Science and Engineering, 2020, V. 73,

DOI: http://doi.org/10.1016/j.jngse.2019.103081

14. Rossi E., Adams B., Vogler D. et al., Advanced drilling technologies to improve the economics of deep geo-resource utilization // Proceedings of MIT Applied Energy Symposium: MIT A+B, 2020, pp. 148, DOI: http://doi.org/10.3929/ethz-b-000445213

15. Schneising O., Buchwitz M., Reuter M. et al., Remote sensing of methane leakage from natural gas and petroleum systems revisited, Atmospheric Chemistry and Physics, 2020, V. 20(15), pp. 9169–9182, DOI: http://doi.org/10.5194/acp-20-9169-2020

16. Ouadi H., Mishani S., Rasouli V., Applications of underbalanced fishbone drilling for improved recovery and reduced carbon footprint in unconventional plays, Petroleum & Petrochemical Engineering Journal, 2023, V. 7(1), DOI: http://doi.org/10.23880/ppej-16000331

17. Ma Tianshou, Jinhua Liu, Jianhong Fu et al., Drilling and completion technologies of coalbed methane exploitation: an overview, International Journal of Coal Science & Technology, 2022, V. 9(1), p. 68, DOI: http://doi.org/10.1007/s40789-022-00540-x

18. Zhigarev V.A., Minakov A.V., Neverov A.L., Pryazhnikov M.I., Numerical study of the cuttings transport by drilling mud in horizontal directional well, Journal of Physics: Conference Series, 2019, V. 1382, no. 1, DOI: http://doi.org/10.1088/1742-6596/1382/1/012080

19. Deshmukh V., Dewangan S.K., Review on various borehole cleaning parameters related to oil and gas well drilling, Journal of the Brazilian Society of Mechanical Sciences and Engineering, 2022, V. 44(5), p. 185, DOI: http://doi.org/10.1007/s40430-022-03501-2

20. Mansouri V., Khosravanian R., Wood D.A., Aadnøy B.S., Optimizing the separation factor along a directional well trajectory to minimize collision risk, Journal of Petroleum Exploration and Production Technology, 2020, V. 10, pp. 2113–2125, DOI: http://doi.org/10.1007/s13202-020-00876-7

21. Hazbeh O., Aghdam S.K.Y., Ghorbani H. et al., Comparison of accuracy and computational performance between the machine learning algorithms for rate of penetration in directional drilling well, Petroleum Research, 2021, V. 6(3), pp. 271–282, DOI: http://doi.org/10.1016/j.ptlrs.2021.02.004

22. Deryaev A.R., Forecast of the future prospects of drilling ultra-deep wells in difficult mining and geological conditions of Western Turkmenistan (In Russ.), SOCAR Proceedings Special Issue, 2023, no. 2, pp. 13–21, DOI: http://doi.org/10.5510/OGP2023SI200874

23. Deryaev A.R., Drilling of directional wells in the fields of Western Turkmenistan (In Russ.), SOCAR Proceedings Special Issue, 2023, no. 2, pp. 22–31,

DOI: http://doi.org/10.5510/OGP2023SI200875

24. Deryaev A.R., Well design development for multilayer horizons for the simultaneous separate operation by one well (In Russ.), SOCAR Proceedings, 2022, V. 1, pp. 94–102, DOI: http://doi.org/10.5510/OGP20220100635

The article addresses a problem regarding the efficiency of waterflooding using surfactants. In author’s opinion, this effectiveness is not justified by scientific data. According to the results of studying the lessons of pilot flooding with the use of aqueous solutions of nonionic surfactants, the following conclusion was obtained. To obtain a real effect from reducing the interfacial tension at the displacement front, it is necessary to create surfactants capable of lowering the interfacial tension to values of at least 10-3 mN/m. Today, there are no such surfactants, and the task of synthesizing them remains super-urgent. This conclusion is not taken into account by scientists and manufacturers when designing industrial applications of surfactant flooding. The described mechanism is achieved by using gaseous agents, especially carbon dioxide. In addition, as practice and laboratory experiments show, highly effective surfactants should have low or moderate adsorption in a porous medium. Currently, chemical reagents that have the ability to influence radically the energy of intermolecular bonds have already been mastered by industry. But apart from isolated reports on the technological features of their application, convincing data on the results of their industrial testing and implementation are not published. The creation of effective physical and chemical methods for enhanced oil recovery (EOR) does not lose its relevance. In this regard, geological and field data obtained at Bashneft PJSC during the period of the greatest volume of work using physico-chemical EOR methods are presented.

References

1. Shakhparonov M.I., Devlikamov V.V., Tumasyan A.B. et al., Fiziko-khimicheskie osnovy primeneniya mitselloobrazuyushchikh PAV dlya povysheniya nefteotdachi (Physicochemical basis for the use of micelle-forming surfactants for enhanced oil recovery), Proceedings of XII Mendeleevskiy s»ezd po obshchey i prikladnoy khimii (XII Mendeleev Congress on General and Applied Chemistry), Moscow: Nauka Publ., 1981, P. 149.

2. Shakhparonov M.I., Usacheva T.M., Devlikamov V.V. et al., Problema uvelicheniya nefteotdachi v svete predstavleniy neravnovesnoy termodinamiki i khimicheskoy fiziki (The problem of increasing oil recovery in the light of the concepts of nonequilibrium thermodynamics and chemical physics), Collected papers “Issledovaniya stroeniya, teplovogo dvizheniya i svoystv zhidkosti” (Studies of the structure, thermal motion and properties of liquids), Moscow: Publ. of MSU, 1986, pp. 5-34.

3. Babalyan G.A., Voprosy mekhanizma nefteotdachi (Oil recovery mechanism issues), Baku: Aznefteizdat Publ., 1956, 232 p.

4. Lozin E.V., Effektinost’ dorazrabotki neftyanykh mestorozhdeniy (Efficiency of additional development of oil fields), Ufa: Bashknigoizdat Publ., 1987, 152 p.

5. Rakhimkulov I.F., Portnov V.I., Kravchenko I.I., Malysheva L.N., Laboratornye i opytno-promyshlennye issledovaniya po primeneniyu zagustiteley vody s tsel’yu uvelicheniya nefteotdachi (Laboratory and pilot-industrial research on the use of water thickeners to increase oil recovery), Proceedings of UfNII, 1968, V. 24,

pp. 302-309.

6. Levi B.I., Lenchevskiy A.V., Stankevich I.A., O tekhnologicheskoy effektivnosti primeneniya polimerov dlya uvelicheniya nefteotdachi obvodnennykh plastov mestorozhdeniy s povyshennoy vyazkost’yu nefti (On the technological efficiency of using polymers to increase oil recovery from watered reservoirs of fields with increased oil viscosity), Proceedings of BashNIPIneft’, 1976, V. 47, pp. 19-22.

7. Rakhimkulov I.F. et al., Eksperiment po zakachke vody, zagushchennoy poliakrilamidom na Novo-Khazinskom uchastke (Experiment on injection of polyacrylamide-thickened water at the Novo-Khazinsky site), Proceedings of BashNIPIneft’, BashNIPIneft’, 1978, V. 51, pp. 48-52.

8. Almaev R.Kh., Application of polymer and nonionic surfactant compositions for oil displacement (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 1993, no. 12, pp. 22-24.

Cavernous-fractured reservoirs are characterized by significant heterogeneity in the distribution of microfractures and cavernousness, which does not allow obtaining reliable data using traditional methods due to the presence of a scale effect. A partial solution of this problem is filtration studies on full-size core samples, however, mass sampling of cores in vertical and directional wells allows studies to be carried out on reservoir models oriented only perpendicular to the bedding or at a certain angle. This article discusses the experience of creating a technology for determining relative phase permeability and displacement coefficients for the gas –water and oil – water system for cavernous-fractured reservoirs, taking into account the above problems. The created technology is based on many years of experience in conducting filtration experiments in domestic and foreign research laboratories. As part of the development of this technology, the influence of the scale effect on the evaluation of reservoir filtration parameters was studied based on the results of flow experiments. In addition, a procedure was developed for determining the relative phase permeability and residual oil saturation both for a single full-size core sample and for the entire full-size core column related to a specific sedimentation environment based on tomography of this column and measurements using standard methods for determining relative phase permeability for a limited number of samples with a volume of 21–27 cm3 and more. The procedure is based on the use of a hydrodynamic model of a given reservoir interval, created based on the results of tomography of a column of full-size core samples of this reservoir interval and the results of measuring the filtration-capacitance properties, displacement coefficients and relative phase permeability of core samples cut from characteristic density zones of this column. The hydrodynamic model makes it possible to calculate the relative phase permeability in the volume of a full-size core sample (or an entire column belonging to a certain sedimentation environment) depending on the orientation relative to the selected directions (for example, along the bedding or perpendicular to the bedding).

References

1. Kheyfets L.I., Neymark A.V., Mnogofaznye protsessy v poristykh sredakh (Multiphase processes in porous media), Moscow: Khimiya Publ., 1982, 320 p.

2. Rodionov S.P., Sokolyuk L.N., Calculation and use of modified relative phase permeabilities when transforming a geological model into a hydrodynamic one (In Russ.), Trudy MFTI, 2010, V. 2, no. 2, pp. 130-136.

3. Cheremisin N.A., Shul’ga R.S., Zagorovskiy A.A. et al., Core modeling of oil penetration into the gas cap of complex-structured fields (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2022, no. 7, pp. 90-96, DOI: https://doi.org/10.24887/0028-2448-2022-7-90-96

4. Rassokhin S.G., Anisotropy of filtration properties of rocks and its effect on the relative phase permeability (In Russ.), Geologiya nefti i gaza = Oil and Gas Geology, 2003, no. 3, pp. 53-56.

5. Gurbatova I.P., Masshtabnye i anizotropnye effekty pri eksperimental’nom izuchenii fizicheskikh svoystv slozhnopostroennykh karbonatnykh kollektorov (Scale and anisotropic effects in the experimental study of the physical properties of complex carbonate reservoirs): thesis of candidate of technical science, Moscow, 2011.

6. Congcong Li, Shuoliang Wang, Qing You, Chunlei Yu, A new measurement of anisotropic relative permeability and its application in numerical simulation, Energies, 2021, V. 14, p. 4731, DOI: http://doi.org/10.3390/en14164731

The article reveals methodological issues of laboratory flow tests to measure the oil-water displacement ratio. Example data for thin-layered heterogeneous reservoirs presents some cases when researchers go beyond the “classical” industry standards, and this leads to distortions in the assessment of the displacement ratio coefficient. The first violation is non-compliance of the core sample length similarity criterion (Efros criterion). Flow tests are often carried out with single core samples (separate plugs) due to the high reservoir heterogeneity and the limited amount of core material. A positive effect of this approach is the detailing of the reservoir structure, which can later be taken into account in hydrodynamic modeling. However, in the pursuit of additional information, researchers skip the basic step of sample selection – calculation of the minimum length of the core column for the flow test. The area of border effects becomes comparable to the size of the entire core sample when using single samples, and this leads to an incorrect assessment of its saturation. Formal calculations indicate the need to use composite core columns rather than single samples when working with highly permeable intervals. The second significant violation is non-compliance with the content of residual water (or initial oil saturation) in the core sample and in the real reservoir. The authors give an example where researchers displace too much water during the formation of residual water saturation. Mismatch between the initial oil saturation values in the laboratory flow tests and in the reservoir description documents can lead to a significant overestimation of the displacement coefficient and, in general, to overestimation of recoverable reserves values.

References

1. OST 39-195-86, Neft'. Metod opredeleniya koeffitsienta vytesneniya nefti vodoy v laboratornykh usloviyakh (Oil. The method of determining the coefficient of oil displacement by water in the laboratory).

2. GOST 26450.0-85. Rocks. General requirements for sampling and sample preparation for determination of collecting properties.

3. Efros D.A., Issledovaniya fil'tratsii neodnorodnykh sistem (Research on filtration of heterogeneous systems), Leningrad: Gostoptekhizdat Publ., 1963, 351 p.

4. Chertenkov M.V., Aleroev A.A., Ivanishin I.B. et al., Physical modeling of production stimulation in low permeability carbonate reservoirs (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2015, no. 10, pp. 90–92.

5. Yazynina I.V., Shelyago E.V., Chertenkov M.V., Ivanishin I.B., Physical modeling of production stimulation in carbonate reservoirs (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2015, no. 9, pp. 92–95.

6. Kokorev V.I. et al., Hysteresis of relative permeabilities in water-gas stimulation of oil reservoirs, SPE-171224-MS, 2014, DOI: https://doi.org/10.2118/171224-MS

7. Zolotukhin A.B., Yazynina I.V., Shelyago E.V., Relative permeability hysteresis for oil-water system in hydrophilic rocks reservoirs (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2016, no. 3, pp. 78–80.

8. Karpov V.B. et al., Experimental study of hysteresis phase permeability water-gas stimulation in the conditions of Vostochno-Perevalnoye oil field (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2015, no. 7, pp. 100–103.

9. Mott R., Cable A., Spearing M., Measurements and simulation of inertial and high capillary number flow phenomena in gas-condensate relative permeability,

SPE-62932-MS, 2000, DOI: https://doi.org/10.2118/62932-MS

10. Berlin A.V., Coefficient of displacement of oil by water. The main mistakes in its definition (In Russ.), PRONEFT''. Professional'no o nefti = PROneft. Professionally about Oil, 2022, no. 7(1), pp.41-51.

11. Beloshapka I.E., Ganiev D.I., Primenenie fil'tratsionnykh issledovaniy dlya izucheniya tekhnologiy razrabotki mestorozhdeniy netraditsionnykh kollektorov i trudnoizvlekaemykh zapasov nefti (In Russ.), Vestnik Rossiyskogo universiteta druzhby narodov. Ser. Inzhenernye issledovaniya = RUDN Journal of Engineering Research, 2018, V. 19, no. 3, pp. 343–357, DOI: https://doi.org/10.22363/2312-8143-2018-19-3-343-357

The article is an additional paper in the series of articles, which describes transformation of Rosneft Oil Company approach to project design, explores the current problem of long period designing (long-term planning), construction and commissioning of capital construction projects. An analysis of the reasons for the delays in project development has been conducted and a new approach to front-end engineering design (FEED) has been proposed to optimize the investment cycle. The requirements for the results of development and the composition of work for the new FEED document, namely “The main technical solutions”, have been described. The relationship of the approach with previously proposed methods for developing design estimates have been described. The interconnectedness between the effectiveness of implementing the main technical solutions and the availability of results from scientific and applied research has been identified. The effect of reducing the investment cycle through the development of technical requirements for long-term manufacturing equipment has been calculated, assessment of the increase in the economic efficiency of the project with applying the described approach was carried out. The main advantages of implementing the new approach to FEED have been listed (including the optimization of capital investments volumes, increased accuracy in investment planning and project implementation timelines, improved quality of project documentation, reduced implementation timelines for investment projects, reducing work defects and costs for design and construction works on a project). The feasibility of methodological support for changing the approach to FEED, approaches to the cost estimation of design and construction works, and equipment procurement procedures has been emphasized. The information was provided on the use of performance improvement tools (sample projects, platform solutions) at the pre-project stage for Rosneft Oil Company.

References

1. Kravchenko A.N., Kosarev A.S., Pavlov V.A. et al., Typical design - on the pulse of time (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2020, no. 11, pp. 13-15,

DOI: https://doi.org/ 10.24887/0028-2448-2020-11-13-15

2. Didichin D.G., Pavlov V.A., Ivanov S.A. et al., Innovative Rosneft tools to improve development of design documentation efficiency: digital etalon project (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2023, no. 5, pp. 111-115, DOI: https://doi.org/10.24887/0028-2448-2023-5-111-115

3. Didichin D.G., Pavlov V.A., Ivanov S.A. et al., New tools of Rosneft to improve the efficiency of design: platform solutions (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2023, no. 12, pp. 135-138, DOI: https://doi.org/10.24887/0028-2448-2023-12-135-138

4. Avrenyuk A.N., Didichin D.G., Pavlov V.A. et al., 3D engineering for Rosneft oil producing facilities construction (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2022, no. 11, pp. 64-67, DOI: https://doi.org/10.24887/0028-2448-2022-11-64-67

5. Didichin D.G., Pavlov V.A., Volkov M.G. et al., New tools of Rosneft to improve the efficiency of design: the transition to 3D technology and information modeling in the block of capital construction (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2023, no. 8, pp. 64-68, DOI: https://doi.org/10.24887/0028-2448-2023-8-64-68

The article presents the algorithm of optimization of operating regimes of a group of oil wells, equipped by electrical submergible pumps and sucker rod pumps, with presence of limitations on the total liquid rate, oil rate and energy consumption. The optimization means the control of frequency of rotation of the submergible motor shaft, which enables torsion of pump impellers, or variation of number of swinging of pumping unit, which leads to change of speed of opening and closing of valve of a rod pump. In the case of periodic operation of the well the optimization is the variation of pumping and storage periods, which change each other during periodic turning on and off of the pump. During optimization the algorithm selects the combination of parameters of well operation in the way to achieve for wells in total the maximum oil rate at fixed liquid rate or energy consumption; minimum specific energy consumption or minimum total energy consumption at fixed oil or liquid rate. The specialty of the algorithm is the taking into account the change of the wells parameters, such as reservoir and bottomhole pressure, water cut, well head pressure and liquid volume rate in time, which enables to specify the effect of optimization for a horizon of several months accounting for interaction between wells and their influence on the ground infrastructure. Information is provided on pilot field tests of group optimization of wells at one of the fields of Bashneft-Dobycha LLC to diminish the specific energy consumption preserving the total oil rate.

References

1. Redutskiy Yu.V., Consideration of oil well interference when solving control problems for well operating regimes (In Russ.), Territoriya Neftegaz, 2011, no. 5, pp. 16–21.

2. Vasil'ev V.V., Use of results of an estimation of producing and injection wells interference for the waterflooding optimization (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2009, no. 6, pp. 30–32.

3. Ponomareva I.N., Martyushev D.A., Chernyy K.A., Research of interaction between expressive and producing wells based on construction of multilevel models (In Russ.), Izvestiya Tomskogo politekhnicheskogo universiteta. Inzhiniring georesursov, 2021, V. 332, no. 2, pp. 116–126, DOI: http://doi.org/10.18799/24131830/2021/2/3048

4. Zipir V.G., Basic principles for constructing an integrated model of a developed hydrocarbon field (In Russ.), Problemy razrabotki mestorozhdeniy uglevodorodnykh i rudnykh poleznykh iskopaemykh, 2017, no. 1, pp. 142–145.

5. Pashali A.A., Zeygman Yu.V., Intellectualization of oil production intensification process under conditions of lack of capacity of the cluster power supply system (In Russ.), Neftegazovoe delo, 2020, V.18, no. 6, pp. 56–63, DOI: https://doi.org/10.17122/ngdelo-2020-6-56-63

6. Enikeev R.M., Topol'nikov A.S., The integrated model of a digital asset energy efficiency (In Russ.), Ekspozitsiya Neft' Gaz, 2023, no. 7, pp. 78–83,

DOI: https://doi.org/10.24412/2076-6785-2022-7-78-83

7. Pashali A.A., Kolonskikh A.V., Khalfin R.S. et al., A digital twin of well as a tool of digitalization of bringing the well on to stable production in Bashneft PJSOC (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2021, no. 3, pp. 80–84, https://doi.org/10.24887/0028-2448-2021-3-80-84

8. Pashali A.A., Sil'nov D.V., Integrated model "reservoir-well-pump" for simulation of periodic well operation (In Russ.), Collected papers “Nauka. Issledovaniya. Praktika“, St. Petersburg, Publ. of Natsrazvitie, 2021, pp. 81–82.

9. Brill J.P., Mukherjee H., Multiphase flow in wells, SPE Monograph, Henry L. Dogherty Series, V.17, 1999, 164 p.

10. Bunday B.D., Basic linear programming, E. Arnold, 1984, 163 p.

11. Ashmanov S.A., Lineynoe programmirovanie (Linear programming), Moscow: Nauka Publ., 1981, 340 p.

12. Vasil'ev F. P., Ivanitskiy A.Yu., Lineynoe programmirovanie (Linear programming), Moscow: Faktorial Publ., 1998, 176 p.

The usage of foam systems in oil and gas production processes is widespread today. The use of foams in one or another operation at the well determines its main parameters, such as foam-forming ability, foam expansion factor, its stability and other properties. The article analyzes the existing methods of studying the properties of foam systems. In the experimental part of the work the results of research of properties of foam containing foaming agent RGU NG MGS mark RL are given. A comparative assessment of the values of the main parameters of the foam system obtained in accordance with the method of V.A. Amiyan, as well as with the help of a dynamic foam analyzer. All experiments were carried out at a temperature of 25°C and atmospheric pressure. The influence of preparation conditions on the height of the foam column formed was studied. The results of determination of half-life, specific number of bubbles, and foam structure at different gas feed rates were compared. When using the dynamic foam analyzer, an increase in the time of separation of 50 % of liquid from the foam was found when the stirring speed was increased, but an increase in the gas feed rate gave the opposite effect. In the case of V.A. Amiyan's method, the result of the determination depended largely on the amount of air involved in the system during the foam preparation process. Based on the results of studies on the Kruss DFA 100 dynamic foam analyzer, the advantages of an automated approach to the study of foam systems have been experimentally proven. The device allows to determine more accurately the stability index of the foam system, and also simultaneously records the dispersion and half-life of the foam during one experiment. The device is able to analyze the change of foam system properties in time, which is difficult when using non-automated methods.

References

1. Schramm L.L., Surfactants: Fundamentals and applications in the petroleum industry, N.Y.: Cambridge University Press, 2010, DOI: http:// doi.org/10.2307/3515635

2. Konyukhov V.Yu. et al., Fizicheskaya i kolloidnaya khimiya (Physical and colloidal chemistry), Part 2: Kolloidnaya khimiya (Colloid chemistry): edited by Konyukhov V.Yu., Popov K.I., Yurayt Publ., 2023, 309 p.

3. Samoylova S.S., Tarasov V.E., Complex application of a new technique for determining the volume weight of foam (In Russ.), Mezhdunarodnyy nauchno-issledovatel'skiy zhurnal, 2022, no. 7(121), pp. 32–39, DOI: https://doi.org/10.23670/IRJ.2022.121.7.005

4. Amiyan V.A. et al., Primenenie pennykh sistem v neftegazodobyche (Application of foam systems in oil and gas production), Moscow: Nedra Publ., 1987, 229 p.

5. Lunkenheimer K., Malysa K., Winsel K. et al., Novel method and parameters for testing and characterization of foam stability, Langmuir, 2009, V. 26(6), pp. 3883–3888, DOI: https://doi.org/10.1021/la9035002

6. Patent RU 2191367 C1. Procedure determining degree of dispersion of foam, Inventors: Prosekova A.Yu., Romanov A.S., Prosekova O.E., Kandabaev V.V.

7. Erasov V.S., Pletnev M.Yu., Pokid'ko B.V., Stability and rheology of foams containing microbial polysaccharide and particles of silica and bentonite clay (In Russ.), Kolloidnyy zhurnal = Colloid Journal, 2015, no. 77(5), pp. 625–633, DOI: https://doi.org/10.7868/S0023291215050079

8. Mogensen K., Recovery of oil using surfactant-based foams, In: Surfactants in Upstream E&P, Springer, 2021, pp. 291-314, DOI: https://doi.org/10.1007/978-3-030-70026-3_10

9. Samedov T.A., Novruzova S.G., Aliev S.A., New composition for prevention complications in oil wells (In Russ.), Bulatovskie chteniya, 2019, V. 2, pp. 194–197.

10. Tarasenko V.N., Teoreticheskie osnovy razrabotki sostavov effektivnykh penobetonov (Theoretical basis for the development of effective foam concrete compositions), Belgorod: Publ. of BSTU, 2017, 91 p.

11. Lake L.W., Johns R.T., Rossen W.R., Pope G.A., Fundamentals of enhanced oil recovery, Society of Petroleum Engineers, 2014, 489 p.,

DOI: https://doi.org/10.2118/9781613993286

One of the ways to ‘green’ oil production is to replace chemically synthesized surfactants with biosurfactants that are products of microbial synthesis. Despite on many data available on biousurfactants tolerance to extreme environmental conditions (salinity, pH) and their ability to reduce the surface tension and to emulsify crude oil, the information on their effectiveness in real conditions or in enhanced oil recovery (EOR) methods simulation remains poor. In this work, biosurfactants of rhamnolipid class produced by Pseudomonas fluorescens PCS-20 were obtained and characterized, and their effectiveness was evaluated in a model experiment with sand packed column in comparison with a chemical surfactant. It has been established that the yield of the acid-precipitated fraction of the biosurfactant followed by solvent extraction with a mixture of chloroform-methanol (volume to volume ratio – 1:1) is 102 mg/l. Emulsification index E24 was estimated to 75%. To simulate tertiary oil recovery, sand packed columns with a volume of 200 ml were sequentially filled with brine and high-viscosity oil from the Romashkinskoye field (the Republic of Tatarstan). The pore volume was 53 ml, the original oil in place volume (OOIP) was 45.5 ml. The secondary recovery using brine was estimated to be 42% from OOIP. When using 0.1 and 0.5% biosurfactant solutions, additional oil recovery was 28 and 31%, respectively. For a chemical surfactant in similar concentrations, the increase in oil recovery did not differ statistically. Thus, rhamnolipids produced by P. fluorescens PCS-20 may be considered as an environmentally friendly alternative to chemical surfactants in the production of high-viscosity oil.

References

1. Kryanev, D.Yu., Zhdanov S.A., Methods for enhanced oil recovery: Experience and application prospects (In Russ.), Neftegazovaya vertikal, 2011, no. 5, pp. 30-33.

2. Chowdhury S., Shrivastava S., Kakati A., Sangwai J.S., Comprehensive review on the role of surfactants in the chemical enhanced oil recovery process, Ind. Eng. Chem. Res., 2022, V. 61, no. 1, pp. 21–64, DOI: https://doi.org/10.1021/acs.iecr.1c03301

3. Podymov E.D., Slesareva V.V., Rafikova K.R., Obzor predstavleniy o klassifikatsii metodov uvelicheniya nefteizvlecheniya (Review of ideas on the classification of enhanced oil recovery methods), Proceedings of TatNIPIneft / Tatneft, 2010, V. 78, pp. 150-160.

4. Aparna A., Srinikethan G., Hegde S., Effect of addition of biosurfactant produced by pseudomonas sps. on biodegradation of crude oil, IPCBEE, 2011, V. 6, pp. 71-77.

5. Zargar A.N., Kumar A., Sinha A. et al., Asphaltene biotransformation for heavy oil upgradation, AMB Express, 2021, V. 11, Article no.127, DOI: https://doi.org/10.1186/s13568-021-01285-7  

6. Suthar H., Hingurao K., Desai A., Nerurkar A., Evaluation of bioemulsifier mediated microbial enhanced oil recovery using sand pack column, J. Microbiol. Methods, 2008, V. 75, no. 2, pp. 225–230, DOI: https://doi.org/10.1016/j.mimet.2008.06.007

7. Rivera M.A.H., Vasconcellos J.M., Morales M.E.O., Factors affecting microbial enhanced oil recovery (MEOR), Proceedings of the 25th Pan-American Conference of Naval Engineering - COPINAVAL 2017, Springer, Cham, 2019, DOI: https://doi.org/10.1007/978-3-319-89812-4_33

8. Amani H., Müller M.M., Syldatk C., Hausmann R., Production of microbial rhamnolipid by Pseudomonas aeruginosa MM1011 for ex situ enhanced oil recovery, Applied biochemistry and biotechnology, 2013, V. 170, pp. 1080–1093, DOI: https://doi.org/10.1007/s12010-013-0249-4

9. Li G., McInerney M.J., Use of biosurfactants in oil recovery, In: Consequences of microbial interactions with hydrocarbons, oils, and lipids: Production of fuels and chemicals. Handbook of hydrocarbon and lipid microbiology: edited by Lee S., Springer, Cham, 2016, DOI: https://doi.org/10.1007/978-3-319-31421-1_364-1

10. Trummler K., Effenberger F., Syldatk C., An integrated microbial/enzymatic process for production of rhamnolipids and L-(+)-rhamnose from rapeseed oil with Pseudomonas sp. DSM 2874, Eur. J. Lipid Sci. Technol., 2003, V. 105, no. 10, pp. 563–571, DOI: https://doi.org/10.1002/ejlt.200300816

11. Rabiei A., Sharifinik M., Niazi A. et al., Core flooding tests to investigate the effects of IFT reduction and wettability alteration on oil recovery during MEOR process in an Iranian oil reservoir, Appl. Microbiol. Biotechnol., 2013, V. 97, pp. 5979–5991, DOI: https://doi.org/10.1007/s00253-013-4863-4

12. Oliveira F.J.S., Vazquez L., De Campos N.P., De França F.P., Production of rhamnolipids by a Pseudomonas alcaligenes strain, Process Biochemistry, 2009, V. 44, no. 4, pp. 383–389, DOI: https://doi.org/10.1016/j.procbio.2008.11.014

13. Gordadze G.N., Tikhomirov V.I., On the oil sources in the northeast of Tatarstan, Petroleum Chemistry, 2007, V. 47, pp. 389–398, DOI: https://doi.org/10.1134/S0965544107060023

14. Invally K., Sancheti A., Ju L-K., A new approach for downstream purification of rhamnolipid biosurfactants, Food and Bioproducts Processing, 2019, V. 114, pp. 122-131, DOI: https://doi.org/10.1016/j.fbp.2018.12.003

15. Kalvandi S., Garousin H., Pourbabaee A.A., Farahbakhsh M., The release of petroleum hydrocarbons from a saline-sodic soil by the new biosurfactant-producing strain of Bacillus sp., Scientific reports, 2022, V. 12, Article no. 19770, DOI: https://doi.org/10.1038/s41598-022-24321-3

16. Sakthipriya N., Doble M., Sangwai J.S., Action of biosurfactant producing thermophilic Bacillus subtilis on waxy crude oil and long chain paraffins, International Biodeterioration & Biodegradation, 2015, V. 105, pp. 168-177, DOI: https://doi.org/10.1016/j.ibiod.2015.09.004

17. Câmara J.M.D.A., Sousa M.A.S.B., Barros Neto E.L., Oliveira M.C.A., Application of rhamnolipid biosurfactant produced by Pseudomonas aeruginosa in microbial-enhanced oil recovery (MEOR), J. Pet. Explor. Prod. Technol., 2019, V. 9, pp. 2333–2341, DOI: https://doi.org/10.1007/s13202-019-0633-x

18. Phulpoto I.A., Jakhrani B.A., Phulpoto A.H. et al., Enhanced oil recovery by potential biosurfactant-producing halo-thermotolerant bacteria using soil washing and sand-packed glass column techniques, Current Microbiology, 2020, V. 77, pp. 3300–3309, DOI: https://doi.org/10.1007/s00284-020-02172-3

19. Geetha S.J., Banat I.M., Joshi S.J., Biosurfactants: Production and potential applications in microbial enhanced oil recovery (MEOR), Biocatalysis Agriculture Biotechnology, 2018, V. 14, pp. 23–32, DOI: https://doi.org/10.1016/j.bcab.2018.01.010

The new high-performance demulsifiers and the (tetrakis (hydroxymethyl) phosphonium sulfate) THPS-based chemical have been trialed in order to eliminate the negative effects of naphthenic emulsions and scales. The field trials were fully executed in line with trial programs and proved to be successful. Field trials were executed in two operation modes – simultaneous injection of new demulsifiers with THPS-based chemical and only just demulsifiers. Based on the trial results, the effective chemical solutions for crude oil treatment at oil and gas production facilities on the continental shelf of the Russian Federation were found in conditions were naphthenic emulsions and sediments can be formed. The effective dosage rates of new demulsifiers are found to be in range from 20 to 60 ppm per based on production volume, KPI of chemicals are confirmed. The synergetic technology for offshore chemical injection was trialed and introduced as simultaneous continuous injection of a high-efficiency demulsifier with 20-60 ppm dosage rate and 100 ppm of special THPS-based reagent inlet to HP separator. The proposed chemical treatment program enables to stabilize oil treatment process, to improve quality of produced water and to reduce platform operations workload. It was proved that simultaneous injection of the demulsifier and THPS-based reagent leads to: a) reducing of high-molecular naphthenic acids volume in sediments found in platform’s process vessels; b) increasing of calcium content and phosphorus content in sediments, originating from organophosphorus compounds which are products of THPS decomposition interacting with calcium ions from produced water. Based on trial results new special production chemicals are recommended for injection at Sakhalin Energy production facilities.

References

1. Kunaev R.U., Glukhova I.O., Patrushev M.G., Sukhoverkhov S.V., Identification of high-molecular weight naphthenic acids in crude oil and methods of management of their calcium salts depositson Sakhalin-2 project assets (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2023, no. 3, pp. 89-94, DOI: https://doi.org/10.24887/0028-2448-2023-3-89-94

2. Barros E.V., Filgueiras P.R., Lacerda Jr.V. et al., Characterization of naphthenic acids in crude oil samples – A literature review, Fuel, 2022, V. 319, Article No. 123775, DOI: https://doi.org/10.1016/j.fuel.2022.123775

3. Turner M.S., Smith P.C., Controls on soap scale formation, including naphthenate soaps – drivers and mitigation, SPE-94339-MS, 2005, DOI: https://doi.org/10.2118/94339-MS

4. Rosseau G., Zhou H., Hurtevent C., Calcium carbonate and naphthenate mixed scale in deep offshore fields, SPE-68307-MS, 2001, DOI: https://doi.org/10.2118/68307-MS

5. Vindstad J.E., Bye A.S., Grande K.V. et al., Fighting naphthenate deposition at the Heidrun field, SPE-80375-MS, 2003, DOI: https://doi.org/10.2118/80375-MS

6. Debord J., Srivastava P., Development and field application of a novel non-acid calcium naphthenate inhibitor, SPE-123660-MS, 2009, DOI: https://doi.org/10.2118/123660-MS

7. Gallup D.L., Star J., Soap sluges: aggravating factors and mitigation measures, SPE-87471-MS, 2004, DOI: https://doi.org/10.2118/87471-MS

8. Melvin K., Cummine C., Youles J. et al., Optimising calcium naphthenate control in the Blake field, SPE-114123-MS, 2008, DOI: https://doi.org/10.2118/114123-MS

9. Kelland M.A., Production chemicals for the oil and gas industry, CRC Press, 2014, 454 p., DOI: https://doi.org/10.1201/b16648.

10. Patent US8003574B2, Inhibiting naphthenate solids and emulsions in crude oil, Inventors: Debord J.D., Srivastava P., Gallagher C., Asomaning S., Hart P.

The problem of formation of high molecular weight organic deposits (asphaltene-resin-paraffin deposits – ARPD) in well equipment, technological elements of oil gathering and treatment system is one of the most urgent in oil production and entails an increase in current operating costs of oil producing enterprises. When researching, designing and further implementation of technologies for prevention and removal of ARPD for deposits and fields at a late stage of development, it is necessary to take into account the uncertainty of the conditions of technology application due to increasing heterogeneity of the reservoir system. Application of protective coatings and materials provides a comprehensive solution to the problems of oil production, including protection from corrosion and erosion wear, reduction of hydraulic resistance, reduction of mechanical impurities in the pumped fluid. In order to determine the main factors determining the protective properties of coatings and materials against the formation of high molecular weight organic deposits (ARPD), experimental studies were carried out. Coatings and oil samples with different characteristics were used for the research. As a result, it was shown that the formation of deposits is determined by the processes of intermolecular interaction and depends on both the composition and properties of the surface and the composition of oil, while low surface roughness is not the main factor determining its protective properties. Taking into account that the use of coating systems and materials provides a comprehensive solution to technological problems, for further development and improvement of the efficiency of protective coatings application it is necessary to expand not only research in this direction, but also the list of normative characteristics characterizing the quality and operational reliability of protective coatings.

References

1. Thota S.T., Onyeanuna Ch., Mitigation of wax in oil pipelines, International Journal of Engineering Research and Reviews, 2016, no.4, pp. 39–47.

2. Sousa A.M., Ribeiro T.P., Pereira M.J., Matos H.A., On the economic impact of wax deposition on the oil and gas industry, Energy Conversion and Management, 2022, V. 16, Article No. 100291, DOI: https://doi.org/10.1016/j.ecmx.2022.100291

3. Bai Jie, Jin Xu, Wu Juntao, Multifunctional anti-wax coatings for paraffin control in oil pipelines, Petroleum Science, 2019, №16, pp. 619–631,

DOI: http://doi.org/10.1007/s12182-019-0309-7

4. Darvin B.S., Tubing pipes with an internal coating that prevents ARPD (In Russ.), Proceedings of XIV International scientific and practical conference “Novoe slovo v nauke: strategii razvitiya” (A new word in science: development strategies), Cheboksary: Interaktiv plyus Publ., 2020, pp. 95–96.

5. Roldugin V.I., Fizikokhimiya poverkhnosti (Surface physicochemistry), Dolgoprudnyy: Intellekt Publ., 2011, 568 p.

6. Ganeeva Y.M., Yusupova T.N., Romanov G.V., Waxes in asphaltenes of crude oils and wax deposits, Petroleum Science, 2016, V. 13, no. 4, pp. 737–745,

DOI: https://doi.org/10.1007/s12182-016-0111-8

7. Gus’kova I.A., Mekhanizm i usloviya formirovaniya ASPO na pozdney stadii razrabotki neftyanogo mestorozhdeniya (Mechanism and conditions for the formation of paraffin deposits at the late stage of oil field development): thesis of candidate of technical science, Bugul’ma, 1998.

8. Berezovskiy D.A., Samoylov A.S., Bashardust M.D., Analysis of wells, complicated by the formation of asphalt-resin-paraffin deposits on the example of the Matrosovskoye oil field, and development of recommendations on the application of methods to dissolution of asphalt-resin-paraffin deposits (In Russ.), Nauka. Tekhnika. Tekhnologii, 2017, no. 3, pp. 124–141.

9. Antoniadi D.G., Shostak N.A., Savenok O.V., Ponomarev D.M., Analysis of existing methods for combating asphalt, resin and paraffin deposits (ARPD) in oil production (In Russ.), Stroitel’stvo neftyanykh i gazovykh skvazhin na sushe i na more, 2011, no. 9, pp. 32–37.

10. Gorodilova K.E., Aleksandrin A.S., Silicate-enamel coating is an effective way to protect pipelines from corrosion and ARPD (In Russ.), Inzhenernaya praktika, 2020, no. 5-6, URL: https://glavteh.ru/wp-content/uploads/2020/08/silikatno-emalevoe-pokrytie.png

11. Presedov A., Enamel against ARPD and pipe corrosion (In Russ.), Neftegazovaya vertikal’, 2012, no. 19, pp. 58–61.

12. Semenov A.A., Protective coating «ARGOF» for oil and gas equipment and other company products for the oil industry (In Russ.), Inzhenernaya praktika, 2020, no. 8, pp. 86–88.

13. Chuyko A.G., Kuzyaev F.F., Rakoch A.G. et al., Effective protection of tubing and submersible equipment for oil production from hydrogen sulfide corrosion, asphalt-resin-paraffin deposits, scale deposits and water-abrasive wear (In Russ.), Territoriya Neftegaz, 2007, no. 6, pp. 60–61.

14. Rashidi M., Mombekov B., Marhamati M.A., Study of a novel inter pipe coating material for paraffin wax deposition control and comparison of the results with current mitigation technique in oil and gas industry, OTC-26695-MS, 2016, DOI: https://doi.org/10.4043/26695-MS

15. Haji-Savameri M., Norouzi-Apourvari S., Irannejad A. et al., Experimental study and modelling of asphaltene deposition on metal surfaces with superhydrophobic and low sliding angle inner coatings, Scientific Reports, 2021, V. 11, Article No. 16812, DOI: https://doi.org/10.1038/s41598-021-95657-5

16. Pankov V.D., Hilong coatings: effective protection of tubing and drill pipes (In Russ.), Inzhenernaya praktika, 2019, no. 8.

17. Yi SJ, Hu K, Li B, Yang JX, Zhang W., Field application of the technology of microbial paraffin cleaning and prevention in high temperature and hyperhaline wells (In Chinese), Jianghan Oilfield. J Oil Gas Technol., 2009, V. 31(4).

18. Moradi S., Amirjahadi S., I. Danaee, Soltani B., Experimental investigation on application of industrial coatings for prevention of asphaltene deposition in the well-string, Journal of Petroleum Science and Engineering, 2019, V. 181, Article No. 106095, DOI: https://doi.org/10.1016/j.petrol.2019.05.046

19. Mikhaylov N.N., Ermilov O.M., Sechina L.S., Wettability change of reservoir rocks during the adsorption of asphaltenes on the interstitial surface (In Russ.), Aktual’nye problemy nefti i gaza, 2021, no. 1(32), DOI: https://doi.org/10.29222/ipng.2078-5712.2021-32.art1

20. Abdrafikova I.M., Ramazanova A.I., Kayukova G.P. et al., Colloid-chemical studies in the development of acid compositions (In Russ.), Vestnik Kazanskogo tekhnologicheskogo universiteta, 2013, no. 7, pp. 237–242.

21. Ivanova L.V., Safieva R.Z., Koshelev V.N., IR spectrometry in the analysis of oil and petroleum products (In Russ.), Vestnik Bashkirskogo gosudarstvennogo universiteta, 2008, V. 13, no. 4, pp. 869–874.

22. Ganeeva Yu.M., Nadmolekulyarnaya struktura vysokomolekulyarnykh komponentov nefti i ee vliyanie na svoystva neftyanykh sistem (Supramolecular structure of high-molecular components of oil and its influence on the properties of oil systems): thesis of doctor of chemical science, Kazan’, 2013, 43 p.

23. Barskaya E.E., Ganeeva Yu.M., Yusupov T.N., D’yanova D.I., Forecasting problems in oil production based on analysis of their chemical composition and physicochemical properties (In Russ.), Vestnik Kazanskogo tekhnologicheskogo universiteta, 2012, V. 15, no. 6, pp. 166–169.

24. Karnaukhov A.P., Adsorbtsiya. Tekstura dispersnykh i poristykh materialov (Adsorption. Texture of dispersed and porous materials), Novosibirsk: Nauka Publ., 1999, 470 p.

25. Tronov V.P., Mekhanizm obrazovaniya smolo-parafinovykh otlozheniy i bor’ba s nimi (Mechanism of formation of resin-paraffin deposits and its control), Moscow: Nedra Publ., 1969, 192 p.

Reducing capital investments to expand on-site oil, gas and water treatment facilities is one of the priorities for oil and gas producing companies. This publication analyzes the performance indicators of several typical on-site oil, gas and water treatment facilities. Using a standard approach to solving the problems of increasing loads, destruction of stable water-oil emulsions and preparation of produced water, the fleet of capacitive technological equipment of the facility is being expanded. This approach is associated with a number of significant time and financial costs and does not allow organizing a solution to the problem in a short time. Based on the conducted research, the most overloaded technological block of the studied oil and water field treatment facilities is the tank block of vertical steel water treatment facilities. The scientific and technical approach proposed by the authors is not innovative for Russian oil companies; however, it allows increasing the efficiency of water treatment tanks when performing a list of certain engineering works. Field studies assessed the density of distribution and dispersion of particles of petroleum products and mechanical impurities in samples of produced water. It has been established that residual oil products are mainly represented by particles with a dispersity of less than 50 microns. Criteria for the use of new internal components of water treatment plant tanks have been determined, such as: maximum use of tank volume by distributing water flows and eliminating stagnant zones; ensuring maximum efficiency of internal components; minimizing the risk of sedimentation of suspended particles in water inlet and outlet pipelines. The technical and technological solutions under consideration make it possible to optimize the introduction of liquid and its distribution throughout the water treatment tank, to form an additional surface to intensify the physical and chemical processes of sedimentation and coalescence of particles.

References

1. Gerasimov Yu.A., Akhmetshin R.I., An alternative approach to improving the efficiency of onshore infrastructure for oil, gas and water treatment (In Russ.), Inzhenernaya praktika, 2020, no. 8, pp. 54–59.

2. Akimenko V.V., Perunov R.E., Increasing the degree of destruction of the structural-mechanical barriers of the dispersed phase in the preparation of oil and water (In Russ.), Nauchno-tekhnicheskiy vestnik OAO “NK “Rosneft’”, 2016, no. 1, pp. 66–70.

Main line pumps designed for transportation of crude oil and oil products on main line transportation facilities have large overall dimensions, which demand much effort to design and optimize their wet ends. Referring to the theoretical justification of the scaling methodology, Transneft Oil Pumps JSC and The Pipeline Transport Institute LLC in collaboration with Bauman Moscow State Technical University and Ural Engineering Center LLC carried out the research and development (R&D) project Pump Wet End Parametric Test Bench Design and Manufacture to assess the parameters of pump scale models and to optimize the wet ends before the full-scale pump units can be manufactured. The project output was a designed and manufactured bench and a pump unit scale model with a detachable wet end, acceptance tests, and receipt of a patent for the group of inventions. The bench and the scale model designed as a part of the R&D project provide the following opportunities: 1) studying the effect of pump unit scale model geometrical parameters to determine the best geometry of the wet end before the full-scale manufacturing is initiated; 2) parametric tests of pump scale models according to the methods specified in national standard GOST 6134 to scale the pump wet end further up to the actual dimensions using scale factors and to design pump units with enhanced performance rating; studying cavitation formation and development in various operating conditions on a pump unit scale model combined with cavitation phenomena imaging and assessment of the actual cavitation characteristics of the designed pumps.

References

1. Gorbenko P.E., Lomakin V.O., Petrov A.I., Experimental verification of numerical experiment data based on the differential method as applied to a double-entry centrifugal pump (In Russ.), Molodezhnyy nauchno-tekhnicheskiy vestnik, 2013, no. 2, 10 p.

2. Lomakin A.A., Tsentrobezhnye i osevye nasosy (Centrifugal and axial flow pumps), Leningrad: Mashinostroenie Publ., 1965, 364 p.

3. Lopastnye nasosy. Spravochnik (Vane pumps. Reference book): edited by Zimnitskiy V.A., Umov V.A., ), Leningrad: Mashinostroenie Publ., 1986, 336 p.

4. Mikhaylov A.K., Malyushenko V.V., Lopastnye nasosy (Vane pumps), Moscow: Mashinostroenie Publ., 1977, 288 p.

5. GOST 6134-2007. Nasosy dinamicheskie. Metody ispytaniy (Rotodynamic pumps. Test methods), Moscow: Standartinform Publ., 2008.

6. Yaremenko O.V., Ispytaniya nasosov (Pump testing), Moscow: Mashinostroenie Publ., 1976, 114 p.

7. Laboratornyy kurs gidravliki, nasosov i gidroperedach (Laboratory course on hydraulics, pumps and hydraulic transmissions): edited by Rudnev S.S., Podvidz L.G., Moscow: Mashinostroenie Publ., 1974, 245 p.

8. Lomakin V.O., Petrov A.I., Numerical simulation of flow parts of pump models and verification of simulation results by comparison of obtained values with experimental data (In Russ.), Nauka i obrazovanie, 2012, no. 5, 10 p., DOI: https://doi.org/10.7463/0512.0356070

9. Patent RU 2709753 C1. Bench for parametrical testing of scale models of flow-through parts of pump equipment and scale model of pump, Inventors: Voronov V.I., Flegentov I.A., Petelin A.N., Minyaylo S.L., Shoter P.I.

The article covers the results of the comprehensive anticorrosive protection approach implementation for the subsea gathering and transport pipelines, oil-gas-fluid mixture treatment pipelines at Vietsovpetro offshore facilities. The process and linear subsea oil pipelines have been designed and laid for gathering and transporting the oil-gas-fluid mixture (the mixture of oil, associated gas and reservoir water), and treated commercial oil between the oil production and process platforms, as well as between the floating storage and offloading unit on Vietsovpetro fields. The author consider the actions on protecting the subsea pipelines from external and internal corrosion, and main factors that affect the safe operation: an increase of water cut, hydrogen sulphide and carbon dioxide content in the produced medium leads to evolvement of corrosive processes on the internal side of the pipelines. Lack of pig lunching and receiving chambers complicates the in-line diagnostics and cleaning of the internal pipeline walls in order to analyse the actual condition of the pipelines. The special attention is given to the assessment of acid solutions corrosivity while performing the bottomhole treatment and scale removal operations. Considering the actual operational lifetime of the pipelines, it is required to implement an inhibitor protection and corrosion monitoring, and perform the actions aimed at cleaning and inspecting the internal side of the pipelines with the high corrosive risks.

References

1. Savel’ev V.V., Avdeev A.S., Ivanov A.N. et al., Corrosion activity of transported fluids and implementation of technical solutions to protect Vietsovpetro offshore pipelines (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2022, no. 2, pp. 102–105, DOI: https://doi.org/10.24887/0028-2448-2022-2-102-105

2. Zapevalov D.N., Vagapov R.K., Mel’sitdinova R.A., Assessing corrosion environment and internal corrosion remedies for offshore objects (In Russ.), Vesti gazovoy nauki, 2018, no. 4(36), pp. 79-86.

3. Uhlig H.H., Revie R.W., Corrosion and corrosion control: An introduction to corrosion science and engineering, Hoboken, NJ: Wiley Interscience Publ., 1963, 371 p.

The article presents the results of comprehensive comparative studies of domestic and foreign industrial adsorbents of the zeolite type and silica gels for drying processes of associated petroleum and natural gas during field gas treatment. Domestic and foreign adsorbents of zeolite type NaX-BS and 13X and silica gels GP-SORB H and KC-Trockenperlen N were studied under static and dynamic conditions of gas drying. Humid methane and air were used as a model gas. It was revealed that the domestic industry produces efficient zeolite-type adsorbents (NaX-BS) and silica gels (GP-SORB H) for drying associated petroleum and natural gas; these absorbents have high adsorption activity and are not inferior in quality to foreign analogues. It was found that NaX-BS zeolite has higher values of such characteristics as adsorption activity and time of protective action of the layer among the studied adsorbents. It has been shown that the minimum time to reach equilibrium is observed for NaX-BS zeolite at 50°C. It has been experimentally established that zeolite adsorbents, in comparison with silica gels at 50°C, have a higher maximum adsorption value and a shorter time to achieve it. But silica gel adsorbents, in comparison with zeolite ones at 5 and 25°C, have a higher maximum adsorption value, but the time to reach an equilibrium state on silica gels is much longer. It has been established that in drying humid air, over the entire range of changes in temperature and volumetric gas flow rate, the dynamic activity of zeolite adsorbents is 1.5-2.5 times greater than for silica gels. Studies of adsorbents in methane drying have been carried out. It was noted that in methane dehydration, the dynamic activity of zeolites is also significantly greater than the dynamic activity of silica gels (approximately 2 times). The stability of the dynamic adsorption activity of adsorbents was studied in 50 adsorption – regeneration cycles in air drying. It has been established that with an increase in a number of adsorption – regeneration cycles, the dynamic activity of all adsorbents decreases by 1.8-2.5%. The research results make it possible to use domestic adsorbents for the purpose of import substitution in the drying of associated petroleum and natural gases.

References

1. Vovk V.S., Zaychenko V.M., Krylova A.Yu., New direction of associated petroleum gas utilization (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2019, no. 10, pp. 94-97, DOI: https://doi.org/10.24887/0028-2448-2019-10-94-97

2. Andreeva N.N., Tarasov M.Yu., Ivanov S.S., The use of light liquid hydrocarbons at design of the systems of field treatment, transport and sales of associated petroleum gas (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2011, no. 11, pp. 92-94.

3. Zav'yalov A.P., A concept of a technological complex to be used for processing associated petroleum gas to develop oil deposits on the Russian Arctic shelf (In Russ.), Oborudovanie i tekhnologii dlya neftegazovogo kompleksa, 2019, no. 5(113), pp. 56-61, DOI: https://doi.org/10.33285/1999-6934-2019-5(113)-56-61

4. Vyakhirev, R.I., Korotaev Yu.P., Kabanov N.I., Teoriya i opyt dobychi gaza (Theory and experience of gas production), Moscow: Nedra Publ., 1998, 479 p.

5. Tekhnologiya pererabotki prirodnogo gaza i gazokondensata. Spravochnik (Technology for processing natural gas and gas condensate. Reference book), Part 1, Moscow: Nedra-Biznestsentr Publ., 2002, 517 p.

6. Istomin V.A., Kvon V.G., Preduprezhdenie i likvidatsiya gazovykh gidratov v sistemakh dobychi gaza (Prevention and elimination of gas hydrates in gas production systems), Moscow: Publ. of IRTs Gazprom, 2004, 506 p.

7. Zaporozhets E.P., Zibert G.K., Zaporozhets E.E. et al., Promyslovaya podgotovka neftyanykh i prirodnykh gazov (Field preparation of oil and natural gases), Moscow: Publ. of Gubkin University, 2016, 424 p.

8. Mel'nikov V.B., Promyslovyy sbor i pererabotka gaza i gazovogo kondensata (Field collection and processing of gas and gas condensate), Moscow: Publ. of Gubkin University, 2017, 464 p.

The article is devoted to the issues of involving Russian oil and gas producing enterprises in the climate agenda in terms of environmental protection within the framework of the overall energy strategy of Russian Federation and the implementation of the goals of the Paris Agreement, which oblige oil industry to look for ways to reduce the carbon footprint when fields developing and operating and prerequisites for achieving a clean carbon neutrality in the future until 2050. The inconsistency and ambiguity of the situation is noted when the decarbonization procedure to achieve neutrality conditions can formally be aimed at reducing hydrocarbon production, which in relation to the richest reserves of these energy resources in Russia cannot be considered acceptable. On this basis, authors proposed to look for a solution by comparing methods for utilizing associated petroleum gas (APG) together with expanding the absorption capacity of the surrounding ecosystems. The article consistently examines the economic and environmental aspects of the APG utilization using the example of the volumes of gas flared at the oil and gas facilities of Samaraneftegas JSC. Changes in the ratio of emission and sink (absorption) of carbon dioxide according to APG utilization options are presented in comparison with the absorptive capacity of forests in the Samara region under various assessment scenarios. Two main directions have been identified for the Samara region: 1) reorganization of Samaraneftegas JSC production activities in technical and technological terms in order to find and apply measures to reduce carbone dioxide emissions, and 2) activities aimed at maintaining and developing natural ecosystems which can absorbing greenhouse gas emissions.

References

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4. Kokorin A.O., Lugovaya D.L., Absorption of CO2 by Russian forests in the context of the Paris Agreement (In Russ.), Ustoychivoe lesopol’zovanie, 2018, no. 2(54), pp. 13–18.

5. Knizhnikov A.Yu., Il’in A.M., Problemy i perspektivy ispol’zovaniya poputnogo neftyanogo gaza v Rossii (Problems and prospects for the use of associated petroleum gas in Russia), URL: https://wwf.ru/resources/publications/booklets/problemy-i-perspektivy-ispolzovaniya-poputnogo-neftya...

6. Gilaev G.G., Gladunov O.V., Gilaev R.G., On the possibility of optimizing the use of hydrocarbon gas at the facilities of Samaraneftegaz JSC (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2024, no. 1, pp. 70-74, DOI: https://doi.org/10.24887/0028-2448-2024-1-70-74

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10. Vaganov E.A., Porfir’ev B.N., Shirov A.A. et al., Assessment of the contribution of russian forests to climate change mitigation (In Russ.), Ekonomika regiona, 2021, V. 17, no. 4, pp. 1096–1109, DOI: https://doi.org/10.17059/ekon.reg.2021-4-4

11. Shakirov V.A., Vilesov A.P., Kozhin V.N. et al., Features of the geological structure and development of the Mukhanovo-Erokhovsky trough within the Orenburg region (In Russ.), Geologiya, geofizika i razrabotka neftyanykh i gazovykh mestorozhdeniy, 2021, no. 6(354), pp. 5–16, DOI: https://doi.org/10.33285/2413-5011-2021-6(354)-5-16

12. Gilaev G.G., Manasyan A.E., Khamitov I.G. et al., Experience in performing MOGT-3D seismic surveys with Slip-Sweep method (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2013, no. 4, pp. 82–85.

13. Gilaev G.G., Khabibullin M.Ya., Gilaev G.G., Basic aspects of using acid gel for propant injection during fracturing works in carbonate reservoirs in the Volga-Ural region (In Russ.), Nauchnye trudy NIPI Neftegaz GNKAR = SOCAR Proceedings, 2020, no. 4, pp. 33–41, DOI: https://doi.org/10.5510/OGP20200400463

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15. Gilaev G.G., Methods of dealing with the main types of complications during well operation (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2020, no. 4, pp. 62–66, DOI: https://doi.org/10.24887/0028-2448-2020-4-62-66

16. Gilaev G.G., Control of technological processes on an oil output intensification (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2004, no. 10, pp. 74–77.

17. Gilaev G.G., Gorbunov V.V., Gen’ O.P., Introduction of new technologies to increase wells operation efficiency at Rosneft - Krasnodarneftegaz NK OAO deposits (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2005, no. 8, pp. 86–89.

18. Gilaev G.G., Khabibullin M.Ya., Bakhtizin R.N., Improvement of oil and gas production infrastructure as an effective tool for maintaining basic oil and gas production (In Russ.), Nauchnye trudy NIPI Neftegaz GNKAR = SOCAR Proceedings, 2021, no. S2, pp. 121–130, DOI: http:// doi.org/10.5510/OGP2021SI200581

19. Gilaev G.G., Gladunov O.V., Ismagilov A.F. et al., Monitoring the quality of design solutions and optimization of the designed structures of capital construction objects in the oil industry (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2015, no. 8, pp. 94–97.

Oil sludge is known as the most massive and hard utilized waste generated in the oil industry. The amount of accumulated oil sludge at any refinery is usually measured in tens of thousands of tons in spite of the ongoing recycling activities. The problem of oil sludge utilization is complicated by climatic conditions of Russia. The absorption capacity of the rubber crumb made from end of life tires in relation to oil sludge absorption for the purpose of further utilization as a fuel in cement kilns is discussed in the article. The oil sludge of one of the refineries of the middle zone of the Russian Federation was studied. Oil sludge is a stable colloidal system with high-water content and dispersion phase distributed in it in the form of petroleum products with a particle sizes of 1-10 microns. The studied oil sludge sample contained water, 61.2%wt. organic components and 15.5%wt. of ash residue according to thermogravimetric analysis. The composition and calorific value of the organic part of the oil sludge does not allow its fire disposal due to the low energy potential of the petroleum products included in its composition. It is proposed to separate the organic component of oil sludge by absorption with a rubber crumb. One quota of rubber crumbs absorbs 1.0–1.1 mass quota of oil sludge per day at a temperature of 65°C and the product preserves the technological properties of the bulk material. The ash residue during the burning of end of life tires contains inorganic oxides that are naturally included into the cement clinker and therefore do not require separate disposal. The organic components during combustion release a significant amount of heat sufficient for its fire disposal in cement kilns, which saves the main process fuel.

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