The oil industry is sensitive to taxation like no other industry, and all because resource taxes alone account for about 60% of the cost of oil. Over the past 16 years, the tax system of the oil industry has undergone a large number of changes and is still at the reform stage. The implementation of tax reform in the fuel and energy complex was the most important stage in the transformation of Russian legislation. In 2019, a new tax regime appeared - the additional income tax (AIT). In 2021, there was an expansion of the scope of application of AIT. Due to the fact that an increasing number of fields are switching to the AIT, the topic is becoming even more relevant. The main objective of the new tax is to stimulate production and stop providing targeted benefits for the mineral extraction tax (MET), which do not allow taking into account the profitability of production at specific deposits. The article discusses the problems of taxation in the oil and gas industry, provides a description of the current tax regimes, and also presents a solution to the issue of distributing AIT among operating facilities, since today there is no specific method for distributing AIT and this has become a serious challenge for many oil and gas companies that have switched to tax on additional income. In this regard, the authors examined several options for distributing AIT for development objects and found an approach for distributing taxes that allows reducing labor costs, as well as improving technical and economic calculations.

References

1. Tret’ dokhodov byudzhetnoy sistemy Rossii okazalas’ svyazana s neft’yu i gazom (A third of the revenues of the Russian budget system turned out to be related to oil and gas), URL: https://www.rbc.ru/economics/22/08/2019/5d555e4b9a7947aed7a185de

2. Nalogovyy kodeks Rossiyskoy Federatsii (chast’ vtoraya). N 117-FZ ot 05.08.2000 (Tax Code of the Russian Federation (part two). N 117-FZ dated 05.08.2000)

3. Nalogi v neftedobyche: Reforma 2020 (Taxes in oil production: Reform 2020), URL: https://vygon-consulting.ru/upload/iblock/0b6/vygon_consulting_tax_reform_2020.pdf

4. Order of the Ministry of Natural Resources and Ecology of the Russian Federation No. 356 of June 14, 2016 (as amended by order No. 638 of September 20, 2019) “Ob utverzhdenii pravil razrabotki mestorozhdeniy uglevodorodnogo syr’ya” (On the approval of the rules for the development of hydrocarbon deposits), URL: https://www.consultant.ru/document/cons_doc_LAW_334817/

The work examines the main patterns of the structure of the subsalt section of the Pre-Caspian Data on the structure of each of the sides of the depression was collected and updated, and the stratigraphic reference of the sediments was clarified, taking into account modern knowledge about the existing stratigraphic scheme of the region. Based on the analysis of numerous published and archival stock materials, schematic lithological-stratigraphic columns were constructed for the northwestern, northern, eastern, southern side zones of the depression and the zone of the Astrakhan carbonate massif, which reflect the main patterns of the structure of the sections of the given zones, and also mark their reflecting seismic horizons. Areas with active carbonate accumulation are identified, which occurred in stages during the time interval from the Middle-Late Devonian to the Early Permian. At the same time, the earliest carbonates are identified on the northwestern, northern and eastern sides of the depression and on the Astrakhan massif. Within the southern marginal zone, excluding the Tengiz-Kashagan subzone, until the end of the Early Carboniferous, terrigenous sedimentation prevailed. Moreover, predominantly terrigenous sediments accumulated within a limited area of the Matken-Ushmola subzone in the south of the basin.

The varying degrees of knowledge, existing disagreements in regional stratigraphic schemes, the degree of completeness and reliability of the identified stratigraphic units are questionable, and therefore additional core, lithological, paleontological and stratigraphic studies are needed in the future. It is quite possible to use isotope geochronology methods, especially in the southern and southern-eastern parts of the Pre-Caspian basin, where there are different views on the structure and origin of the South Emba zone. The northwestern section also requires additional research, clarification of ages and correlation of horizons.

References

1. Resheniya Mezhvedomstvennogo regional’nogo stratigraficheskogo soveshchaniya po srednemu i verkhnemu paleozoyu Russkoy platformy s regional’nymi stratigraficheskimi skhemami. Devonskaya sistema (Decisions of the Interdepartmental Regional Stratigraphic Meeting on the Middle and Upper Paleozoic of the Russian Platform with regional stratigraphic schemes. Devonian system), Leningrad, 1990, 60 p.

2. Sostoyanie stratigraficheskoy bazy tsentra i yugo-vostoka Vostochno-Evropeyskoy platformy (State of the stratigraphic base of the center and southeast of the East European Platform), Meeting proceedings, Moscow, VNIGNI, 23 –25 November 2015, Moscow: Publ. of VNIGNI, 2016, 188 p.

3. Byulleten’ Regional’noy mezhvedomstvennoy stratigraficheskoy komissii po tsentru i yugu Russkoy platformy (Bulletin of the Regional Interdepartmental Stratigraphic Commission for the center and south of the Russian Platform), Moscow: Publ. of RMSK, 2015, V. 6, 128 p.

4. Rzhonsnitskaya M.A., Eykhgorn T.F., Komissiya po devonskoy sisteme. Vypiska iz protokola zasedaniya byuro komissii ot 17 yanvarya 1999 g.: Postanovleniya MSK i ego postoyannykh komissiy (Commission on the Devonian system. Extract from the minutes of the meeting of the commission bureau dated January 17, 1999: Resolutions of the Interdepartmental Stratigraphic Committee and its standing commissions): edited by Sokolov B.S., Zhamoyda A. I., St. Petersburg: Publ. of VSEGEI, 1999, V. 31, p. 18.

5. Postanovleniya Mezhvedomstvennogo stratigraficheskogo komiteta i ego postoyannykh komissiy (Resolutions of the Interdepartmental Stratigraphic Committee and its standing commissions), St. Petersburg: Publ. of VSEGEI, 2003, V. 34, pp. 38-39.

6. Postanovleniya MSK i ego postoyannykh komissiy (Resolutions of the Interdepartmental Stratigraphic Committee and its standing commissions), St. Petersburg: Publ. of VSEGEI, 1997, V. 29, pp. 15–17.

7. Astrakhanskiy karbonatnyy massiv. Stroenie i neftegazonosnost’ (Astrakhan carbonate massif. Structure and oil and gas content): edited by Volozh Yu.A., Parasyna V.S., Moscow: Nauchnyy mir Publ., 2008, 221 p.

8. Kuandykov B.M., Matloshinskiy N.G., Sentgiorgi K. et al., Neftegazonosnost’ paleozoyskoy shel’fovoy okrainy severa Prikaspiyskoy vpadiny (na primere Fedorovskogo bloka) (Oil and gas potential of the Paleozoic shelf margin of the north of the Caspian basin (on the example of the Fedorov block)): edited by Kuandykov B.M., Shomfai A., Li Gian, Almaty: Gylym Publ., 2011, 280 p.

9. Abilkhasimov Kh.B., Osobennosti formirovaniya prirodnykh rezervuarov paleozoyskikh otlozheniy Prikaspiyskoy vpadiny i otsenka perspektiv ikh neftegazonosnosti (Features of the formation of natural reservoirs of the Paleozoic sediments of the Caspian basin and assessment of the prospects of their oil and gas potential), Moscow: Publ. of Academy of Natural Sciences, 2016, 244 p.

10. Stratigrafiya i regional’naya korrelyatsiya podsolevykh neftegazonosnykh kompleksov Prikaspiyskoy vpadiny (Stratigraphy and regional correlation of subsalt oil and gas complexes of the Caspian basin): edited by Zamarenov A.K., Moscow: Nedra Publ., 1989, 168 p.

11. Oreshkin I.V., Zholtaev G.Zh., Kulumbetova G.E., Oreshkin A.I., Characteristics of carbonate and terrigenous subsalt formations of the Caspian Depression and formation of hydrocarbon traps within them (In Russ.), Geologiya nefti i gaza, 2019, no. 4, pp. 5–16, DOI: https://doi.org/10.31087/0016-7894-2019-4-5-16

12. Pisarenko Yu.A., Ivanova L.N., Kozlovskaya O.V. et al., Local stratigraphic units of the Upper Devonian and Lower–Middle Carboniferous (In Russ.), Nedra Povolzh’ya i Prikaspiya, 2000, V. 22, pp. 3–9.

13. Iskaziev K.O., Khafizov S.F., Lyapunov Yu.V. et al., Pozdnepaleozoyskie organogennye postroyki Kazakhstanskogo segmenta Prikaspiyskoy vpadiny (Late Paleozoic organogenic structures of the Kazakhstan segment of the Caspian basin), Moscow: LENARD Publ., 2019, 250 p.

The Pre-Caspian megabasin is a large oil and gas basin with a unique geological structure. However, the region remains poorly studied, with uneven drilling and seismic sections limited in length. The presence of thick salt strata and morphological features create difficulties during geological exploration, their interpretation and forecasting of hydrocarbon potential. The results of the study allowed authors to establish the complex structure of the depression, including the Archean and Baikal basement. The study of geophysical materials, especially seismic data, makes it possible to revise the concept of the structure and history of the development of the southeastern margin of the Pre-Caspian depression. Within the limits of the North Caspian and Temir uplifts of the depression, numerous protrusions of the foundation have been revealed, which are overlain by Paleozoic sedimentary rocks. These protrusions contain promising traps for hydrocarbons at depths up to 7–8 km. The block structure of the foundation determines the features of the subsalt sedimentary complex of the basin. The study of the Pre-Caspian basin showed the presence of isometric uplifts, such as Kashagan and Tengiz, as well as a system of narrow uplifts of the eastern side zone. As a result of modeling the migration of oil and gas from source strata, it was revealed that about 4,70 trillion tons of hydrocarbon fluids emigrated, mainly liquid. The analysis of structural maps has shown the possibility of migration and filling of potential traps in the Lower Permian, Visean-Bashkir and French-Famen oil and gas complexes. The obtained simulation results made it possible to successfully reproduce the main deposits in the studied area, reflecting real data. The deposits in the west of the depression are characterized by a high content of gaseous hydrocarbons, while in the east the liquid fraction predominates, corresponding to the more oil potential of the eastern side of the Pre-Caspian depression. In the central part of the depression, exclusively gas accumulations are formed associated with the migration of gas from the oil and gas source strata. In the northern side zone, there is an increased content of liquid components. An increased content of gaseous hydrocarbons was detected on the Astrakhan platform. In the south of the Caspian sea, accumulations of hydrocarbons are observed in all the complexes under consideration. Modeling also showed the presence of new promising zones at various stratigraphic levels. Particular attention is paid to the formation of gas condensate accumulations in the central part of the depression.

References

1. Volozh Yu.A., Abukova L.A., Antipov M.P. et al., Autoclave type of the hydrocarbon systems in the Pricaspian oil-and-gas province (Russia): Conditions of formation at great depth (In Russ.), Geotektonika = Geotectonics, 2022, no. 6, pp. 59–77, DOI: https://doi.org/10.31857/S0016853X22060078

2. Bakirov A.A., Bordovskaya M.V., Mal’tseva A.K., Tabasaranskiy Z.A., Geologiya i geokhimiya nefti i gaza (Geology and geochemistry of oil and gas), Moscow: Nedra, 1982, 288 p.

3. Voronov G.V., Kuantaev N.E., Paleozoyskie karbonatnye otlozheniya Prikaspiyskoy vpadiny: nadezhdy, real’nost’, perspektivy (Paleozoic carbonate deposits of the Caspian basin: hopes, reality, prospects), In: Osobennosti karbonatnykh porod i voprosy modelirovaniya rezervuarov (Features of carbonate rocks and reservoir modeling issues), Proceedings of Kazakhstan Society of Petroleum Geologists, 2022, V. 9, pp. 27-37.

4. Zhuravlev V.S., Sravnitel’naya tektonika Pechorskoy, Prikaspiyskoy i Severomorskoy ekzogonal’nykh vpadin Evropeyskoy platformy (Comparative tectonics of the Pechora, Caspian and North Sea exogonal depressions of the European Platform), Moscow: Nauka Publ., 1972, pp. 399.

5. Abilkhasimov Kh.B., Osobennosti formirovaniya prirodnykh rezervuarov paleozoyskikh otlozheniy Prikaspiyskoy vpadiny i otsenka perspektiv ikh neftegazonosnosti (Features of the formation of natural reservoirs of the Paleozoic sediments of the Caspian basin and assessment of the prospects of their oil and gas potential), Moscow: Publ. of Academy of Natural Sciences, 2016, 244 p.

6. Antipov M.P., Bykadorov V.A., Volozh Yu.A., Leonov Yu.G., Problems of origin and evolution of Pre-Caspian depression (In Russ.), Geologiya nefti i gaza, 2009, no. 3, pp. 11–19.

7. Volozh Yu.A., Nekrasov G.E., Antipov M.P. et al., Novyy vzglyad na formirovanie konsolidirovannoy kory Prikaspiyskoy neftegazonosnoy provintsii (A new look at the formation of the consolidated crust of the Caspian oil and gas province), In: Tektonika i geodinamika Zemnoy kory i mantii: fundamental’nye problemy-2022 (Tectonics and geodynamics of the Earth’s crust and mantle: fundamental problems-2022), Materials of the LIII Tectonic Meeting, Moscow: GEOS Publ., 2022, pp. 114–119.

8. Petrovskiy V.B., Opyt primeneniya novykh tekhnologiy obrabotki dannykh distantsionnogo zondirovaniya Zemli v komplekse s geofizicheskimi metodami pri reshenii zadach neftegazovoy geologii (Experience in using new technologies for processing Earth remote sensing data in combination with geophysical methods in solving problems of oil and gas geology), In: Neftegazonosnye basseyny Kazakhstana i perspektivy ikh osvoeniya (Oil and gas basins of Kazakhstan and prospects for their development), Almaty: Publ. of Kazakhstan Society of Petroleum Geologists, 2015, pp. 442-453.

9. Voronov G.V., Kuantaev N.E., Eskozha B.A., Glubinnaya neft’ Prikaspiya: Predposylki, osobennosti, vyzovy i perspektivy (Deep oil of the Caspian region: Prerequisites, features, challenges and prospects), In: Kaspiyskiy region: Problemy stroeniya i nefteganosnosti glubokozalegayushchikh kompleksov i geneticheskaya priroda uglevodorodov (Caspian region: Problems of the structure and oil potential of deep-lying complexes and the genetic nature of hydrocarbons), Proceedings of Kazakhstan Society of Petroleum Geologists, 2015, V. 5, pp. 15-23.

10. Voronov G.V., Kuantaev N.E., Konusy vynosa i turbidity Prikaspiyskoy vpadiny – novye ob»ekty, osobennosti i perspektivy poiskov nefti i gaza (Alluvial fans and turbidites of the Caspian basin - new objects, features and prospects for oil and gas exploration), In: Kaspiyskiy region: Perspektivy neftegazonosnosti Kazakhstana, problemy, puti izucheniya i osvoeniya trudnoizvlekaemogo, netraditsionnogo uglevodorodnogo syr’ya (Caspian region: Prospects for the oil and gas potential of Kazakhstan, problems, ways of studying and developing hard-to-recover, unconventional hydrocarbon raw materials), Proceedings of Kazakhstan Society of Petroleum Geologists, 2017, V. 6, pp. 311-321.

The 3D basin modeling is fraught with a number of uncertainties, one of them being the correct reconstruction of geothermal history. The article examines the major issues that complicate the forecasting as well as the methods used to overcome them using the Pre-Caspian depression as an example. The purpose of the work is to enhance the accuracy of assessing the thermal field variations during the evolution of the Pre-Caspian depression. The account of the temperature measurements of the Earth’s surface from spacecraft can reduce forecast uncertainties. Repeated temperature measurements over a sufficiently close network from different spacecraft provide more information. However, obtaining reliable data characterizing exactly the endogenous component of the thermal field is associated with certain difficulties. Combining the results of the Earth's thermal field surface measurements with measured data from temperature surveys performed in deep wells made it possible to obtain a 3D vertical gradient model for the thermal field. The model’s evolution over time was traced using geothermal modeling in Temis Flow™ software. The modeling outputs were surface temperature and heat flow distribution maps updated based on actual well data. The results obtained demonstrate a non-uniform temperature distribution in the sedimentary cover due to halokinesis, which affects the distribution of the source rock catagenetic alteration degree: catagenetic maturity is lower under thick salt diapirs than in the salt thinning zones. The data obtained allow a more accurate assessment of potential hydrocarbon fluid generation volumes. In places at the same depth, sediments beneath the diapirs are transformed to gradation MK3-MK4, and in the interdome zone to MK5-AK1.

References

1. Eremeev V.A., Mordvintsev I.N., Platonov N.G., Modern hyperspectral sensors and hyperspectral data processing methods (In Russ.), Issledovaniya Zemli iz Kosmosa, 2003, no. 6, pp. 80-91.

2. Petrovskiy V.B., Opyt primeneniya novykh tekhnologiy obrabotki dannykh distantsionnogo zondirovaniya Zemli v komplekse s geofizicheskimi metodami pri reshenii zadach neftegazovoy geologii (Experience in using new technologies for processing Earth remote sensing data in combination with geophysical methods in solving problems of oil and gas geology), In: Neftegazonosnye basseyny Kazakhstana i perspektivy ikh osvoeniya (Oil and gas basins of Kazakhstan and prospects for their development), Almaty: Publ. of Kazakhstan Society of Petroleum Geologists, 2015, pp. 442-453.

3. Gornyy V.I., Shilin B.V., Yasinskiy G.I., Teplovaya aerokosmicheskaya s»emka (Thermal aerospace imaging), Moscow: Nedra Publ., 1993, 128 p.

4. Nikitin A.A., Petrov A.V., Aleksashin A.S., Kompleks spektral’no korrelyatsionnogo analiza dannykh “KOSKAD 3D” (Complex of spectral correlation data analysis “COSKAD 3D”), Moscow: Publ. of Russian State University for Geological Prospecting, 2004.

5. Sydykov Zh.S., Chakabaev S.E., Mukhamedzhanov M.A. et al., Karta raspredeleniya temperatur i geotermicheskikh gradientov Aralo-Kaspiyskogo regiona (Map of temperature distribution and geothermal gradients of the Aral-Caspian region), Alma-Ata: Nauka Publ., 1977.

6. Khutorskoy M.D., Antipov M.P., Volozh Yu.A., Polyak B.G., Temperature field and a 3D geothermal model of the North Caspian basin (In Russ.), Geotektonika = Geotectonics, 2004, no. 1, pp. 63-72.

7. Geotermicheskaya karta SSSR (Geothermal map of the USSR): edited by Makarenko F.A., Moscow: Publ. of GUGK SSSR, GIN AN SSSR, 1972.

8. Dal’yan I.B. Sydykov Zh.S., Geothermal conditions of the eastern margin of the Caspian basin (In Russ.), Sovetskaya geologiya, 1972, no. 6.

Studying the influence of formation of authigenic clayey mineral deposits on the physical properties of rocks is a current issue today. The lithological features of reservoirs predetermine their physical properties, the main of which are filtration-capacitance characteristics and are divided into primary and secondary. The primary factors include the granulometric composition of the clastic part of rocks and structural characteristics (sorting, grain size). Secondary factors include the nature of compaction of sedimentary rocks (intergranular contacts) and superimposed transformations of rock fragments and cement, among which authigenic mineral formation of clay minerals is distinguished. Clay minerals, which are found in cement of terrigenous rocks, have a direct impact on the reservoir properties. The purpose of the work is to study the interdependence between reservoir properties of the rock and the composition of clay minerals and their forms of selection. The object of the study were core samples of the А, В, С layers. The analysis of lithological, petrophysical, petrographic, mineral and geochemical data was carried out in the work. The research results showed that clay cement simultaneously with stage changes underwent superimposed epigenetic processes, which led to the transformation of the mineral composition of clay particles (kaolinization, chloritization and hydromica of cement), a change in the structural characteristics of clays and the emergence of new structural polytype modification. The comprehensive study made it possible to establish the authigenic nature of kaolinite and chlorite, as well as staging of their formation. Late generation kaolinite is represented by large, thick particles resembling pseudohexagonal crystals in their shape. The chlorite component of an earlier generation in the most cases directly contacts the surface of a detrital grain, while flakes of hidromicaceous composition are the latest in generation. The authigenic clay formation in the pores of terrigenous peservoirs leads to deterioration of reservoir properties. It should be noted that an increase in the hydromicaceous and, to a greater extent, mixed-layer component in the stone leads to a complication of the structure of the pore space and to a noticeable decrease in reservoir properties. Secondary mineral formation is an indicator for identifying reservoir zones with increased filtration-capacitance properties for rocks of various facies complexes.

References

1. Teodorovich G.I., Autigennye mineraly osadochnykh porod (Authigenic minerals of sedimentary rocks), Moscow: Gostoptekhizdat Publ., 1958, 572 p.

2. Yapaskurt O.V., Geneticheskaya mineralogiya i stadial’nyy analiz protsessov osadochnogo porodo- i rudoobrazovaniya (Genetic mineralogy and stage analysis of processes of sedimentary rock and ore formation), Moscow: ESLAN Publ., 2008, 356 p.

Natural bitumen refers to organically formed minerals with a primary hydrocarbon basis, which are confined to the subsurface in viscous, visco-plastic and solid states. Such substances form a wide range of compounds from high-carbon differences to individual classes of hydrocarbons containing asphalt-resinous components and metals: malt, asphalts, asphaltites and other analogs. The Osinsky productive horizon of the Lower Cambrian (productive formation B1) in the Irkutsk region is one of the main ones for increasing the hydrocarbon resource base in Rosneft's assets. At present, nine oil deposits have been put in the State Register of Reserves. Production of bitumen and high-viscosity oil in the future will allow optimizing the development system with the most complete recovery of hydrocarbons at maximum economic profitability. In most cases oil of the Osinsky horizon can be classified as light, but at the same time there is a widespread development of very viscous to oxidized bitumen in the sediments. The presence of bitumen and viscous oils is due to the fact that the carbonate sediments under consideration are ancient (low Lower Cambrian) and are characterized by a complex structure. The transformation of sediments considering the long history of formation caused a highness of reservoir properties anisotropy, and also led to the reformation of hydrocarbon accumulations. The proportion of bitumen in the rock is often significant and often affects the assessment of reservoir properties. The article presents the methodology of bitumen estimation in the carbonate reservoirs of the Osinsky productive horizon based on well logging data. The quantitative content of bitumen in the void space is determined by the dependence of pyrolysis data on the transverse relaxation rate according to nuclear magnetic logging data. Consideration of bituminosity in the void space allows estimating its volume by section and by area. For this reason, quantitative assessment of bitumen in open oil deposits was performed.

References

1. Slovar’ po geologii nefti i gaza (Dictionary of oil and gas geology), Leningrad: Nedra Publ., 1988, 680 p.

2. Khisamov R.S. et al., Mineral’no-syr’evaya baza prirodnykh bitumov Respubliki Tatarstan i ee osvoenie (Mineral resource base of natural bitumen of the Republic of Tatarstan and its development), Proceedings of International scientific and practical conference “Prirodnye bitumy i tyazhelye nefti” (Natural bitumens and heavy oils), St. Petersburg, 2006.

3. Kashirtsev V.A., Prirodnye bitumy severo-vostoka Sibirskoy platformy (Natural bitumens of the northeast of the Siberian platform), Yakutsk, Publ. of Yakut branch of the Siberian Branch of the USSR Academy of Sciences, 1988, 126 p.

4. Bezrukov V.M., Tverdye bitumy i ikh svyaz’ s neftegazonosnost’yu i metallogeniey (Solid bitumens and their relationship with oil and gas potential and metallogeny): thesis of candidate of geological and mineralogical science, Moscow, 1993.

5. Shavaleev I.I. et al., Podgotovka i pererabotka prirodnykh bitumov (Preparation and processing of natural bitumen), Proceedings of International scientific and practical conference “Prirodnye bitumy i tyazhelye nefti” (Natural bitumens and heavy oils), St. Petersburg, 2006.

6. Reitner J., Queric N.-V., Gernot A., Advances in stromatolite geobiology. Lecture notes in Earth Sciences, Springer, 2011, 559 p.

7. Maslov V.P., Atlas porodoobrazuyushchikh organizmov (izvestkovykh i kremnevykh) (Atlas of rock-forming organisms (calcareous and flint)), Moscow: Nauka Publ., 1979, 271 p.

8. Gubina E.A., Tikhonova K.A., Vinokurova O.A. et al., Model of the Osinsky productive horizon (formation B1) in the fields of the Irkutsk region (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2022, no. 2, pp. 46-51, DOI: https://doi.org/10.24887/0028-2448-2022-2-46-51

The efficiency of bottomhole zone hydrochloric acid treatment depends on geological and physical characteristics of the productive formation (formation temperature, fracturing, proximity of water-oil and gas-oil contacts, etc.), the degree of rock dissolution during interaction with acid composition, and formation coverage. To assess the influence of these parameters, an integrated approach is required when planning the design of acid treatment of horizontal wells. In order to improve the efficiency of acid treatment in the conditions of Riphean deposits of the Yurubcheno-Tokhomskoye oilfield, represented by low-temperature dolomitized rocks, a set of analytical and laboratory studies was carried out to determine the optimal treatment technology. The main features of this object are: low share of working intervals in relation to the total length of the open wellbore of production wells, low reservoir temperature, fractured dolomitized reservoir, risks of acid breakthrough into water- and gas-saturated parts of the deposit. In the course of physico-chemical experiments, the prospect of increasing the efficiency of exposure with an acid composition based on 24% HCl, modified by a mutual solvent, which provides an increase in the rate of reaction of the composition with the rock of the Riphean object of the Yurubcheno-Tokhomskoye field, was shown. In order to evaluate the effect of the modified acid composition on the rock matrix, a filtration experiment was carried out, the results of which revealed the formation of a highly conductive dissolution channel, which confirms the effectiveness of the composition. The horizontal well treatment design adapted to the conditions of the Riphean object was developed. Pilot tests of acid treatment technology with the use of modified composition were carried out; the results of the research and the technology effectiveness were confirmed.

References

1. Hill A.D., Schechter R.S., Economides M.J., Nolte K.G., Fundamentals of acid stimulation, In: Reservoir Simulation, John Wiley & Sons Ltd., 2000, 856 p.

2. Bulgakova G.T., Kharisov R.Ya., Sharifullin A.R., Pestrikov A.V., Optimizing the acidizing operations of horizontal wells in carbonate reservoirs (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2013, no. 6, pp. 102–105.

3. Hoefner M.L., Pore evolution and channel formation during flow and reaction in porous media, AIChE Journal, 1988, V. 34, no. 1, pp. 45–54, DOI: https://doi.org/10.1002/aic.690340107

4. Lund K., Fogler H.S., McCune C.C., Acidization – I. The Dissolution of Dolomite in Hydrochloric Acid, Chemical Engineering Science, 1973, V. 28, no. 3, pp. 691–700.

5. Kristian M., Sokol S., Konstantinesku A., Uvelichenie produktivnosti i priemistosti skvazhin (Increasing productivity and injectivity of wells), Moscow: Nedra Publ., 1985, 184 p.

6. Cherepanova N.A., Maksimova E.N., Chertina K.N. et al., Influence of the carbonate rocks dolomitization in the Eastern Siberia on the acid impact efficiency (In Russ.), Neftepromyslovoe delo, 2022, no. 10(646), pp. 48–53, DOI: https://doi.org/10.33285/0207-2351-2022-10(646)-48-53

7. Folomeev A.E., Magadiev A.F., Khatmullin A.R. et al., Acidizing combined with heat generating system in low-temperature dolomitized wax damaged carbonates, SPE-202069-MS, 2020, DOI: https://doi.org/10.2118/202069-MS

8. Harris O.E., Hendrickson A.R., Coulter A.W., High-concentration hydrochloric acid aids stimulation results in carbonate formations, Journal of Petroleum Technology, 1966, V. 18, no. 10, pp. 1291–1296, DOI: https://doi.org/10.2118/1654-PA

9. Liu H., Coston C., Yassin M. et al., A novel stimulation technique for horizontal openhole wells in carbonate reservoirs – A case study in Kuwait, SPE-105127-PA, 2009, DOI: https://doi.org/10.2118/105127-PA

10. Folomeev A.E., Taipov I.A., Khatmullin A.R. et al., Gelled acid vs. Self-diverting systems for carbonate matrix stimulation: an experimental and field study, SPE-105127-PA, 2009, DOI: https://doi.org/10.2118/105127-PA

One of the most effective thermal methods for oil recovery enhancement in case of high-viscosity oil reservoirs is the technology of steam cyclic stimulation of the well. Using this method, RITEK LLC was able to put into development previously unprofitable high-viscosity oil reservoir in the Volga-Ural oil and gas bearing region. However, sequential laboratory studies of physico-chemical processes occurring in carbonate rock during steam cyclic treatment of the reservoir at temperatures of 250-350°C allowed to identify processes that affect the reduction of rock permeability, which leads to a decrease in the treatment efficiency. In the course of determining the relative phase permeability in the stationary mode during the filtration of oil and water, a significant irreversible decrease in the permeability of the core model was noted. Extended studies of samples of rock-reservoirs of high-viscosity oils allowed to identify a series of sequential, interrelated processes that underlie the reduction of permeability. Such a process is partial or complete destruction of the microcrystalline calcite rim with subsequent colmatation, local formation of organic hydrophobic films in the pore space, as well as the formation of needle-like technology-induced crystals at high temperatures. This study is devoted to the study of newly formed minerals as a result of high-temperature filtration experiments on the core model and hydrothermal impact on the rock crumb in reservoir conditions. The study of the rock was carried out by a number of lithological-mineralogical methods: petrographic study of thin sections, X-ray phase analysis, scanning electron microscopy, transmission electron microscopy with electron diffraction, micro-X-ray spectral analysis. According to the results of the study, it was found that during the hydrothermal impact on carbonate rocks in the presence of quartz, minerals of the group of calcium hydrosilicates (tobermorite, xonotlite, etc.) are formed, which fill the void space and significantly reduce the pore space and filtration ability of the rock, which worsens the filtration of fluids in the reservoir. The obtained results will allow to reasonably approach the development of ways to prevent the filling of the void space with newly formed crystals during the steam cyclic stimulation, which will lead to an increase in oil recovery.

References

1. Kuznetsov V.G., Prirodnye rezervuary nefti i gaza karbonatnykh otlozheniy (Natural reservoirs of oil and gas carbonate sediments), Moscow: Nedra Publ., 1992, 320 p.

2. Roehl P.O., Choquette P.W., Carbonate petroleum reservoirs, Springer New York, 1985, 622 p.

3. Altunina L.K. et al., Chemically evolving systems for oil recovery enhancement in heavy oil deposits, AIP Conference Proceedings, 2017,

DOI: http://doi.org/10.1063/1.5013686

4. Kudinov V.I., Thermal technology of intricately built viscous and highly-viscous oils fields development (In Russ.), Georesursy = Georesources, 2009, no. 2(30), pp. 16-20.

5. Ya-fei Chen et al., A preliminary feasibility analysis of in situ combustion in a deep fractured-cave carbonate heavy oil reservoir, Journal of Petroleum Science and Engineering, 2019, V. 174, pp. 446–455, DOI: http://doi.org/10.1016/j.petrol.2018.11.054

6. Mukhametdinova A. et al., Reservoir properties alteration in carbonate rocks after in-situ combustion, SPE-212281-PA, 2023, DOI: https://doi.org/10.2118/212281-PA

7. Darishchev V.I., Slavkina O.V., Malaniy S.Ya. et al., Results and prospects in applying thermal effective methods at the high-viscous oil fields of "RITEK" LLC (In Russ.), Neft'.Gaz.Novatsii, 2022, no. 2, pp. 24–28.

8. Lesina N.V., Osadchaya N.S., Popov E.Yu., Slavkina O.V., Evaluation of temperature effect on displacement coefficient and permeability of high-viscous oil carbonate reservoirs by the results of laboratory studies (In Russ.), Geologiya, geofizika i razrabotka neftyanykh i gazovykh mestorozhdeniy, 2022, no. 9(369), pp. 69-75, https://doi.org/10.33285/2413-5011-2022-9(369)-69-75

9. Lesina N.V., Nikolaeva S.N., Karamov T.I. et al., Determination of the reasons for the decrease in the high-viscosity oil carbonate reservoirs permeability with increasing temperature based on the laboratory studies results (In Russ.), Geologiya, geofizika i razrabotka neftyanykh i gazovykh mestorozhdeniy, 2023, no. 5(377), pp. 55-61.

The article considers a development system based on controlling the formation stress state. This development system combines the advantages of using horizontal wells with fractures oriented across the horizontal wellbore for fluid production, and horizontal wells with longitudinal fractures for injection of displacement agent. The required orientation is achieved by controlling the direction of fracture growth by controlling the stress state of the formation. The mechanism that allows to control the direction of hydraulic fractures is based on the influence of the pore pressure gradient on the local stress state of the rock mass. However, for the successful implementation of a development system, it is necessary to analyze its stability to a number of geological, geomechanical and technological parameters. A simulator for calculating the direction of initiation and growth of fracture was used as an analysis tool. This simulator is based on a physical and mathematical model of the stressed state of a formation with arbitrarily oriented fractures and a non-uniform pressure field. The model is based on the theory of poroelasticity using the maximum tensile stress criterion to determine the direction of formation and calculate the trajectory of a growing crack. It is shown that the development system is most sensitive to those parameters that are responsible for the energy of the stressed state in the formation. Such parameters include, in particular, the initial stress contrast, as well as the parameters of reservoir thickness and Biot constant. The direction of regional stress does not directly relate to the energy state of the formation, but can affect the energy of the hydraulic fracture system depending on their direction. The permeability of the reservoir determines the time interval in which stress reorientation occurs, the propagation pressure of a hydraulic fracture determines the degree of fracture trajectory deviation of the from the original direction. With the observed deterioration in the reservoir properties of fields, the implementation of this development system with transverse fractures will improve the efficiency of development of hard-to-recover reserves.

References

1. Maltsev V.V., Asmandiyarov R.N., Baykov V.A. et al., Testing of auto hydraulic-fracturing growth of the linear oilfield development system of Priobskoye oil field (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2012, no. 5, pp. 70-73.

2. Patent RU 2779696 C1, Method for developing oil tight deposits, Inventors: Fedorov A.I., Mulyukov D.R., Murtazin R.R., Kolonskikh A.V.

3. Salimov O.V., Gidravlicheskiy razryv karbonatnykh plastov neftyanykh mestorozhdeniy Tatarstana (Hydraulic fracturing of carbonate formations in oil fields of Tatarstan): thesis of doctor of physical and mathematical science, Bugul'ma, 2017.

4. Murtazin R.R., Fedorov A.I., Savchenko P.D., Mulyukov D.R., Modification of the unconventional reserves’ exploitation approach based on the reservoir’s stress-deformed state management (In Russ.), SPE-196998-MS, 2019, DOI: https://doi.org/10.2118/196998-MS

5. Fedorov A.I., Davletova A.R., Reservoir stress state simulator for determining of fracture growth direction (In Russ.), Geofizicheskie issledovaniya = Geophysical research, 2014, V. 15, no. 1, pp. 15–26.

6. Blokhin A.M., Dorovskiy V.N., Problemy matematicheskogo modelirovaniya v teorii mnogoskorostnogo kontinuuma (Problems of mathematical modeling in multi-continuum theory), Novosibirsk, 1994, 183 p.

7. Cherepanov G.P., Mekhanika khrupkogo razrusheniya (The mechanics of brittle fracture), Moscow: Nauka Publ., 1974, 640 p.

8. Abass H.H., Tahini A.M., Abousleiman Y.N., Khan M., New technique to determine biot coefficient for stress-sensitive dual-porosity reservoirs, SPE-124484-MS, 2009, DOI: http://doi.org/10.2118/124484-MS

9. McPhee C., Reed J., Zubizarreta I., Core analysis: a best practice guide, Elseiver B.V., 2015, 852 p.

10. Krasnikov A., Mel'nikov R., Pavlov V.A. et al., Consideration of elastic properties and stresses anisotropy in fracturing planning (In Russ.), SPE-196899-MS, 2019,

DOI: https://doi.org/10.2118/196899-MS

11. Lapin V.N., Modelirovanie rasprostraneniya treshchin, nagruzhennykh davleniem vyazkoy zhidkosti (Modeling the propagation of cracks loaded with viscous fluid pressure): thesis of candidate of physical and mathematical science, Novosibirsk, 2022.

Over the last decades, humankind has been searching for new ways to improve the effectiveness of civilization. Firstly, the research and production community is learning to adopt ideas from nature for new technological solutions that allow improving efficiency of current production processes. Secondly, it is increasingly trying to manage natural phenomena in balanced manner.. The Presidential Decree "On the development of nature-like technologies in the Russian Federation" provides a substantial push towards this field. For the first time the various issues surrounding the comprehension and replication of natural systems, as well as their efficient management – mainly pertaining to energy systems – are presented as one, unified approach. Under the direction of nature-like technologies, first of all, one understands the task of studying and reproducing individual samples of living nature. This paper proposes to broaden the range of subjects studied to include macrosystems - components of an ecotope. This would address the specific need for efficient management of the existing ecotope or for replicating natural phenomena in order to achieve a desired outcome. One possible directional outcome of applying natural phenomena is a decrease in the expenses related to constructing and maintaining objects and production facilities. In this context, the paper considers examples of controlling the following natural phenomena: wind effects, hydrological processes, including lithodynamics, control of permafrost. The paper also considers examples of application of various microbiological technologies in construction. Both examples of directed impact and examples of minimizing negative impacts from the development of undesirable phenomena are considered. Some of the given examples relate to natural phenomena that have the most significant impact on construction objects during economic activities in the Arctic region.

References

1. Koval’chuk M.V., Naraykin O.S., Yatsishina E.B., Nature-like technologies: new opportunities and new challenges (In Russ.), Vestnik Rossiyskoy akademii nauk, 2019, V. 89, no. 5, pp. 455-465, DOI: https://doi.org/10.31857/S0869-5873895455-465

2. Desjardins J., How machines destroy and create jobs, Visual Capitalist, 2016, June, V. 29, URL: https://www.visualcapitalist.com/how-machines-destroy-and-create-jobs/

3. Mati B.M., Overview of water and soil nutrient management under smallholder rain-fed agriculture in East Africa, 2005, URL: https://www.iwmi.cgiar.org/Publications/Working_Papers/working/WOR105.pdf

4. Beer C., Zimov N., Olofsson J. et al., Protection of permafrost soils from thawing by increasing herbivore density, Sci Rep., 2020, V. 10, p. 4170,

DOI: https://doi.org/10.1038/s41598-020-60938-y

5. Burkov P.V., Kochurov B.I., Osadchaya G.G., Dudnikov V.Yu., On the issue of the trends of application of the composite cryogel-based materials and the techniques of soil cryostructuring in the Russian Arctic zone (In Russ.), Problemy regional’noy ekologii, 2020, no. 1, pp. 34-40, DOI: https://doi.org/10.24411/1728-323X-2020-11034

6. Patent RU 2703142 C1, Pseudoalteromonas arctica strain for decomposition of oil and oil products, Inventors: Shestakov A.I. , Serezhkin I.N. , Lomova Ya.A. , Gavrilova L.A. , Shestakova O.O., Ershova O.A. , Shabalin N.V. , Isachenko A.I.

7. Strokova V.V., Vlasov D.Yu., Frank-Kamenetskaya O.V., Microbial sarbonate biomineralisation as a tool of natural - like technologies in construction material science (In Russ.), Stroitel’nye materialy, 2019, no. 7, pp. 66–72, DOI: https://doi.org/10.31659/0585-430X-2019-772-7-66-72

8. Raza A.M., El Ouni H., Khan Q. et al., Sustainability assessment, structural performance and challenges of self-healing bio-mineralized concrete: A systematic review for built environment applications, Journal of Building Engineering, 2023, V. 66, DOI: https://doi.org/10.1016/j.jobe.2023.105839

9. Konstantinou C., Wang Y., Unlocking the potential of microbially induced calcium carbonate precipitation (MICP) for hydrological applications, A Review of Opportunities, Challenges, and Environmental Considerations. Hydrology, 2023, V. 10(9), DOI: https://doi.org/10.3390/hydrology10090178

10. Kendon V.M., Nemoto K., Munro W.J., Quantum analogue computing, Phil. Trans. R. Soc. A, 2010, V. 368, Issue 1924, pp. 3609-3620,

DOI: https://doi.org/10.1098/rsta.2010.0017

11. Lunin D.A., Minchenko D.A., Noskov A.B. et al., Technologies applicability matrix for protecting production wells from the complicating factors negative impact (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2023, no. 6, pp. 74-77, DOI: https://doi.org/10.24887/0028-2448-2023-6-74-77

The article considers approaches to the analysis and evaluation of the possibility of effective use of associated petroleum gas (APG) at the fields of the Samara region. A selection of the observed objects of Samaraneftegas JSC was carried out to assess APG in flares and check the characteristic indicators of their condition for evaluation as a solution for the possible development of more intensive use of APG. The quantitative criterion for selecting a cluster of candidate facilities was limited by intersection of a certain volume of gas flaring (at least 5 mln m3 per year) and a low degree of utilization of the facility in question as a whole (up to 75-77%). For a selected group of facilities, each of which, for the purpose of depersonalization, is called a licensed area, characterized by a serial number and gas flaring volume, calculations were made to model the relative unit costs of capital investments for a number of classical and often used in practice optimization measures use of APG. It is noted that the wells production in the Volga region quite often is sulfurous and hydrogen sulfide-containing oil, which objectively reduces the profitability of using petroleum gas in local areas of oil fields. The need for a detailed study of the use of APG resources in relation to the conditions of the Volga region is emphasized, in order to take into account, in each specific case, the specifics of the state of the oilfield infrastructure, gas quality, and the need for energy of one kind or another.

References

1. Ryadinskaya A.P., Cherepovitsyna A.A., Utilization of associated petroleum gas in russia: methods and prospects for the production of gas chemistry products (In Russ.), Sever i rynok: formirovanie ekonomicheskogo poryadka, 2022, no. 2, pp. 19-34, DOI: https://doi.org/10.37614/2220-802X.2.2022.76.002

2. Gumerov A.G., Bazhaykin S.G., Il’yasova E.Z. et al., Choice of oil gas recycling methods and estimation of efficiency of their introduction at LUKOIL-Komi OOO oilfields (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2008, no. 9, pp. 50-52.

3. 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.

4. Analiticheskiy doklad ob ekonomicheskikh i ekologicheskikh izderzhkakh szhiganiya PNG v Rossii (Analytical report on the economic and environmental costs of APG flaring in Russia), URL: https://istina.msu.ru/publications/book/4729948/

5. Levshin P.M., Meritsidi I.A., Shotidi K.Kh., Khalikov P.R., Technical, economic and environmental aspects of associated petroleum gas utilization (software package) (In Russ.), Territoriya Neftegaz, 2011, no. 8, pp. 56-63.

6. 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

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

8. 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.

9. 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

10. 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

11.  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.

12. 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

13. Shakirov V.A., Vilesov A.P., Morozov V.P. et al., Vulcanite rocks in condensed Domanic facies of the Mukhanovo-Erokhovskaya intra-shelf depression (In Russ.), Geologiya, geofizika i razrabotka neftyanykh i gazovykh mestorozhdeniy, 2022, no. 2(362), pp. 14–26, DOI: https://doi.org/10.33285/2413-5011-2022-2(362)-14-26

14. 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.

15. Nagnetanie poputnogo neftyanogo gaza s primeneniem nasosno-ezhektornykh sistem (Injection of associated petroleum gas using pump-ejector systems), URL: https://chemtech.ru/nagnetanie-poputnogo-neftjanogo-gaza-s-primeneniem-nasosno-jezhektornyh-sistem/

16. Donets K.G., Gidroprivodnye struynye kompressornye ustanovki (The hydraulically driven jet compressor units), Moscow: Nedra Publ., 1990, 174 p.

As a rule, the effectiveness of an oil production technology based on chemical reagents is usually associated with the composition of the reagent and the technological parameters of injection. However, when developing new technologies, it is also necessary to take into account the heterogeneity of the response of the dispersed oil system to external influences. It is known that the composition and properties of oil, especially at the late stage of oil field development, are largely determined by the continuous change in geological and physical conditions during the development process. Temperature and pressure affect the stability of asphaltenes in the petroleum dispersed system and, accordingly, the physicochemical characteristics of the produced oil. Despite a fairly large amount of research into the interaction of oil and various chemical reagents, the question remains to what extent the results obtained are universal.

In the article, based on experimental laboratory studies of the influence of solvents in various concentrations on changes in the viscosity-temperature characteristics of oil samples taken from wells of one deposit, differences in their rheological behavior were identified and the intervals of the most significant changes were determined. The results obtained show the need to expand research into the heterogeneity of the response of petroleum dispersed systems to external influences and the potential for increasing the efficiency of technologies for extracting hard-to-recover oil reserves using solvents. Considering that during field development the nature of changes in the composition and properties of oil is dynamic and complex, an in-depth study of the processes occurring during the interaction of oil and chemical reagents is of high scientific and practical significance.

References

1. Xiang Zhou, Qingwang Yuan, Xiaolong Peng et al., A critical review of the CO2 huff ‘n’ puff process for enhanced heavy oil recovery, Fuel, 2018, V. 215, pp. 813-824, DOI: https://doi.org/10.1016/j.fuel.2017.11.092

2. Khisamov R.S., Effektivnost' vyrabotki trudnoizvlekaemykh zapasov nefti (Efficiency of stranded oil development), Kazan: Fen Publ., 2013, 310 p.

3. Eremin N.A., Digital technologies for recovery of unconventional oil reserves (In Russ.), Izvestiya Tul'skogo gosudarstvennogo universiteta. Nauki o Zemle, 2022, no. 2, pp. 255-270.

4. Musin K.M., Gibadullin A.A., Kadkin V.I. et al., Opyt otbora predstavitel'nykh prob sverkhvysokovyazkoy nefti i opredelenie ee vyazkosti pri termobaricheskikh usloviyakh plasta (Experience in selecting representative samples of ultra-high-viscosity oil and determining its viscosity under thermobaric reservoir conditions), Proceedings of TatNIPIneft / Tatneft, 2014, V. 82, pp. 202-214.

5. Khisamov R.S., Musin M.M., Musin K.M., Obobshchenie rezul'tatov laboratornykh i opytno-promyshlennykh rabot po izvlecheniyu sverkhvyazkoy nefti iz plasta (Generalization of the results of laboratory and pilot-industrial work on the extraction of super-viscous oil from the reservoir), Kazan': Fen Publ., 2013, 232 p.

6. Rakhimova Sh.G., Amerkhanov M.I., Ibatullin R.R., Issledovanie vliyaniya rastvoriteley na koeffitsient nefteizvlecheniya sverkhvyazkoy nefti pri teplovom vozdeystvii (Study of the influence of solvents on the oil recovery factor of ultra-viscous oil under thermal influence), Proceedings of TatNIPIneft / Tatneft, Moscow: Publ. of VNIIOENG, 2008, pp. 185-194.

7. Pratama R.A., Babadagli T., A review of the mechanics of heavy-oil recovery by steam injection with chemical additives, Journal of Petroleum Science and Engineering, 2022, V. 208, Part D, Article No. 109717, DOI: https://doi.org/10.1016/j.petrol.2021.109717

8. Kayukova G.P., Petrov S.M., Uspenskiy B.V., Svoystva tyazhelykh neftey i bitumov permskikh otlozheniy Tatarstana v prirodnykh i tekhnogennykh protsessakh (Properties of high-viscosity oil and bitumen of Permian deposits of Tatarstan in natural and technogenic processes), Moscow: GEOS Publ., 2015, 343 p.

9. Rakhimova Sh.G., Amerkhanov M.I., Issledovanie zavisimosti vyazkosti tyazhelykh neftey ot temperatury pri dobavlenii uglevodorodnogo rastvoritelya (Study of the dependence of the viscosity of heavy oils on temperature when adding a hydrocarbon solvent), Proceedings of TatNIPIneft / Tatneft, Moscow: Publ. of VNIIOENG, 2009, pp. 147-151.

10. Xingang Li, Lin He, Guozhong Wu et al., Operational parameters, evaluation methods, and fundamental mechanisms: Aspects of nonaqueous extraction of bitumen from oil sands, Energy & Fuels, 2012, V.26, pp. 3553-3563, DOI: https://doi.org/10.1021/ef300337q

11. Musin K.M., Gibadullin A.A., Amerkhanov I.I., Podkhody k opredeleniyu parametrov sverkhvyazkoy tyazheloy nefti (Approaches to determining the parameters of ultra-viscous heavy oil), Collected papers “Vysokovyazkie nefti i prirodnye bitumy: problemy i povyshenie effektivnosti razvedki i razrabotki mestorozhdeniy” (High-viscosity oils and natural bitumens: problems and increasing the efficiency of exploration and development of fields), Proceedings of International scientific and practical conference, Kazan, 05–07 September 2012, Kazan: FEN Publ., 2012, pp. 265-269.

12. Ganeeva Yu.M., Yusupova T.N., Romanov G.V., Asphaltene nano-aggregates: structure, phase transitions and effect on petroleum systems (In Russ.), Uspekhi khimii = Russian Chemical Reviews, 2011, V. 80, no. 10, pp. 1034–1050, DOI: https://doi.org/10.1070/RC2011v080n10ABEH004174

13. Yunfeng Liu, Zhengsong Qiu, Hanyi Zhong et al., Bitumen recovery from crude bitumen samples from Halfaya oilfield by single and composite solvents – Process, parameters, and mechanism, Materials, 2019, V. 12, Article No. 2656, DOI: https://doi.org/10.3390/ma12172656

14. Romanov G.V., Yakubov M. R., Borisov D.N. et al., Experimental modeling of the displacement of super-viscous oils by solvents with visualization and study of changes in the physico-chemical properties of oil components (In Russ.), Georesursy, 2010, no. 2(34), pp. 38-41.

15. Musin K.M., Gibadullin A.A., Amerkhanov I.I., Metodicheskie podkhody po opredeleniyu parametrov sverkhvyazkikh tyazhelykh neftey (Methodological approaches for the characterization of extra heavy oil), Proceedings of TatNIPIneft' / OAO “Tatneft'”, Moscow: Publ. of VNIIOENG, 2012, V. 80, pp. 56–65.

16. Nikitin M.N., Gladkov P.D., Kolonskikh A.V. et al., Analysis of rheological properties of Yaregskoe field heavy high-viscosity oil (In Russ.), Zapiski Gornogo instituta, 2012, V. 195, pp. 73–77.

17. Nghiem L.X., Sammon P.H., Kohse B.F., Modeling asphaltene precipitation and dispersive mixing in the Vapex process, SPE-66361-MS, 2001, DOI: https://doi.org/10.2118/66361-MS

18. Yusupova T.N., Ganeeva Yu.M., Romanov G.V., Barskaya E.E., Fiziko-khimicheskie protsessy v produktivnykh neftyanykh plastakh (Physical and chemical processes in the productive oil reservoirs), Moscow: Nauka Publ., 2015, 410 p.

19. Das S.K, Butler R.M., Mechanism of the vapor extraction process for heavy oil and bitumen, Journal of Petroleum Science and Engineering, 1998, V. 21, no. 1-2, pp. 43-59, DOI: https://doi.org/10.1016/S0920-4105(98)00002-3

The article presents the results of the study of graphene oxide additives influence on the physical and mechanical properties of cement stone. The prerequisite for the study was the use of carbon nanomaterials, in particular graphene and graphene oxide, for cement slurry, since these substances have unique physical and mechanical characteristics and determine the rheological properties of liquids at various temperatures and pressures. The authors present the result of experimental studies including graphene oxides during the hardening of the cement mixture, the strength of cement stone, the rheological properties of cement slurry, the properties of the adhesive action of the metal – cement pair, and the structure of cement stone. PCT-I-G cement was used as the basis of the cement mixture. RG-T1 graphene oxide nanoplates were used as a additive. Methods of experimental studies of cement slurry properties correspond to national standards GOST 310.1-76 – GOST 310.3-76, GOST 310.1–4–81. The setting time of the cement paste is carried out using the VIKA IV-2 device according to TU 25-04.2550-80. The rheological properties of cement slurries were measured using an OFITE 900 rotational viscometer. It has been established that the addition of graphene oxide in an amount of 0.5-1.5% leads to a significant reduction in the setting time of the cement slurry compared to cement without additives. It has been experimentally shown that an increase in the proportion of graphene oxide leads to an increase in the tensile strength of cement stone. The influence of graphene oxide components on the rheological properties of cement slurry was also discovered, which is manifested in a decrease in dynamic shear stress and effective viscosity at a shear rate of 300 s-1. Using electron microscopic methods, it has been established that the development of graphene oxide has a significant impact on the structure of cement stone, changing its characteristics and porosity. These results indicate the potential of using graphene oxide to improve the properties of cement materials.

References

1. Agi A., Junin R., Gbadamosi A., Mechanism governing nanoparticle flow behavior in porous media: insight for enhanced oil recovery applications, International Nano Letters, 2018, V. 8(2), pp. 49–77, DOI: https://doi.org/10.1007/s40089-018-0237-3

2. Agzamov F.A., Ismagilova E.R., Self-healing cements - the key to maintaining the integrity of cement sheath. Part 1. (In Russ.), Nanotekhnologii v stroitel'stve, 2019, V. 11, no. 5, pp. 577-586, DOI: https://doi.org/10.15828/2075-8545-2019-11-5-577-586

3. Bekbaev A.A., Agzamov F.A., Dispersed reinforcement as a factor of increasing the quality of the lightweight cements (In Russ.), Stroitel'stvo neftyanykh i gazovykh skvazhin na sushe i na more, 2018, no. 8, pp. 38-42, DOI: https://doi.org/10.30713/0130-3872-2018-8-38-42

4. Mohammedameen A.I.M., Berkane W., Tsenev N.K., Some features of the effect of nanosilica on modification for cement slurry in oil-gas wells, Collected papers “Tekhnologicheskie resheniya stroitel'stva skvazhin na mestorozhdeniyakh so slozhnymi geologo-tekhnologicheskimi usloviyami ikh razrabotki” (Technological solutions for the construction of wells in fields with complex geological and technological conditions for their development), Proceedings of II international scientific and practical conference dedicated to the memory of Viktor Efimovich Kopylov, Tyumen, 15–17 February 2022, Tyumen: Publ. of TIU, 2022, pp. 466-472.

5. Hajiabadi S.H., Aghae H., Kalateh-Aghamohammadi M., Shorgasthi M., An overview on the significance of carbon-based nanomaterials in upstream oil and gas industry, Journal of Petroleum Science and Engineering, 2020, V. 186, Article no. 106783, DOI: https://doi.org/10.1016/j.petrol.2019.106783

6. Hamza M.F., Sinnathambi C.M., Merican Z.M., Recent advancement of hybrid materials used in chemical enhanced oil recovery (CEOR): a review, IOP Conference Series: Materials Science and Engineering, 2017, V. 206, Article no. 012007, DOI: https://doi.org/10.1088/1757-899x/206/1/012007

7. Sharma M.M., Chenevert M.E., Guo Q. et al., A new family of nanoparticle based drilling fluids, SPE-160045-MS, 2012, DOI: https://doi.org/10.2118/160045-MS

8. Suleymanov B.A., Veliev E.F., The effect of particle size distribution and the nano-sized additives on the quality of annulus isolation in well cementing (In Russ.), SOCAR Proceedings, 2016, no. 4, pp. 4–10, DOI: https://doi.org/10.5510/ogp20160400293

9. Artioli G., Ferrari G., Dalkoni M.C., Valentini L., 10-Nanosemines as modifiers of the cement hydration kinetics, Smart Nanoconcretes and Cement-Based Materials, 2020, pp. 257–269, DOI: https://doi.org/10.1016/B978-0-12-817854-6.00010-6

10. Fedorova G.D., Aleksandrov G.N., Smagulova S.A., Research of stability of water suspension of graphene oxide (In Russ.), Stroitel'nye materialy, 2015, no. 2, pp. 15–21.

11. Shawgi A., Chinedum P.E., Saeed S., Improvement in cement sealing properties and integrity using conductive carbon nano materials: from strength to thickening time, SPE-191709-MS, 2018, DOI: https://doi.org/10.2118/191709-MS

12. Ryabchikov P., Yakimovich V., Batyanovskiy E., Assessment of influence of carbon nanomaterials on properties of cement and cement stone, In: Contemporary issues of concrete and reinforced concrete: Collected research papers, Minsk: Publ. of Institute BelNIIS, 2017, V. 9, pp. 393–413, DOI: https://doi.org/10.23746/2017-9-24

13. Agzamov F.A., Grigor'ev A.Yu., Modification of portland cement with nanoadditives (In Russ.), Nanotekhnologii v stroitel'stve, 2022, no. 14(4), pp. 319–327,

DOI: https://doi.org/10.15828/2075-8545-2022-14-4-319-327

To date computer technologies are being actively introduced into the industry. One of the urgent issues at the moment is a proactive approach to the prevention of equipment failures. The purpose of this paper is a review of existing approaches to diagnostics and failures prediction of electric submersible pumps (ESP) units. A literature review was conducted in the domain of diagnostics and forecasting of ESP malfunctions. There are 4 main approaches observed: deterministic, expert-based, data-based, and hybrid. A deterministic approach uses functional or analytical dependencies, an expert approach is based on the available knowledge base, which is used in the form of patterns interpreted by specialists, a data-based approach identifies existing patterns based on the historical archive of data, and hybrid approach may include various options for combining main approaches. For each group examples, features and results are provided where possible. Applicability and limitations of each category are given. As a result of literature analysis, the advantages and disadvantages of existing approaches are established. Main advantages of deterministic approaches are interpretability and non-dependence on historical data. Expert rules are mainly used in the diagnosis of the current state without forecasting, unlike fuzzy logic approaches. The effectiveness of this approach depends on the quality of the applied rules and data. The main advantage of the data-based approach is the absence of detailed physical modeling of systems or processes. The main disadvantage is the dependence on the volume and quality of historical data. A promising direction is combined approaches that include several models, thereby adopting the advantages of each one of them.

References

1. Abdelaziz M., Lastra R., Xiao J.J., ESP Data Analytics: Predicting failures for improved production performance, SPE-188513-MS, 2017, DOI: https://doi.org/10.2118/188513-MS

2. Carvalho T.P., Soares F.A.A.M.N., Vita R. et al., A systematic literature review of machine learning methods applied to predictive maintenance, Computers & Industrial Engineering, 2019, V. 131, Article No. 106024, DOI: https://doi.org/10.1016/j.cie.2019.106024

3. Bruijnen P.M., Nodal analysis by use of ESP intake and discharge pressure gauges, SPE-178433-PA, 2016, DOI: https://doi.org/10.2118/178433-PA

4. Iranzi J., Son H., Lee Y., Wang J.A., Nodal analysis based monitoring of an electric submersible pump operation in multiphase flow, Applied Sciences, 2022, V. 12(6), Article No. 2825, DOI: https://doi.org/10.3390/app12062825

5. Grassian D., Bahatem M., Scott T., Olsen D., Application of a fuzzy expert system to analyze and anticipate ESP failure modes, SPE-188305-MS, 2017, DOI: https://doi.org/10.2118/188305-MS

6. Awaid A., Al-Muqbali H., Al-Bimani A. et al., ESP well surveillance using pattern recognition analysis, oil wells, petroleum development Oman, IPTC-17413-MS, 2014, DOI: https://doi.org/10.2523/IPTC-17413-MS

7. Li L., Hua C., Xu X., Condition monitoring and fault diagnosis of electric submersible pump based on wellhead electrical parameters and production parameters, Systems Science & Control Engineering, 2018, V. 6, no. 3, pp. 253–261, DOI: https://doi.org/10.1080/21642583.2018.1548983

8. Bermudez F., Carvajal G.A., Moricca G. et al., Fuzzy logic application to monitor and predict unexpected behavior in electric submersible pumps (Part of KwIDF Project), SPE-167820-MS, 2014, DOI: https://doi.org/10.2118/167820-MS

9. Stone P., Introducing predictive analytics: Opportunities, SPE-106865-MS, 2007, DOI: https://doi.org/10.2118/106865-MS

10. R.A. Khabibullin, A.R. Shabonas, N.S. Gurbatov, Timonov A.V., Prediction of ESPs failure using ML at Western Siberia oilfields with large number of wells, SPE-201881-MS, 2020, DOI: https://doi.org/10.2118/201881-MS

11. Solomatine D., See L.M., Abrahart R.J., Data-driven modelling: Concepts, approaches and experiences, In: Water Science and Technology Library, V. 68, Berlin: Springer, 2008, DOI: https://doi.org/10.1007/978-3-540-79881-1_2

12. Abdalla R., Samara H., Perozo N. et al., Machine learning approach for predictive maintenance of the electrical submersible pumps (ESPs), ACS omega, 2022, V. 7(21), pp. 17641–17651, DOI: https://doi.org/10.1021/acsomega.1c05881

13. Sherif S., Adenike O., Obehi E. et al., Predictive data analytics for effective electric submersible pump management, SPE-198759-MS, 2019, DOI: https://doi.org/10.2118/198759-MS

14. Pilipenko O.G., Povyshenie vremeni prokata ustanovok elektrotsentrobezhnykh nasosov metodami mashinnogo obucheniya (Improving the production of electric centrifugal pump by machine learning methods), Collected papers “Nauchnyy forum: tekhnicheskie i fiziko-matematicheskie nauki” (Scientific forum: technical and physical and mathematical sciences), Proceedings of XXV international scientific and practical conference, Moscow: Publ. of OOO “Mezhdunarodnyy tsentr nauki i obrazovaniya”, 2019, V. 6(25), pp. 14-18.

15. Marin A.A., Busaidy S., Murad M. et al., ESP well and component failure prediction in advance using engineered analytics – A breakthrough in minimizing unscheduled subsurface deferments, SPE-197806-MS, 2019, DOI: https://doi.org/10.2118/197806-MS

16. Peng L., Han G., Sui X. et al., Predictive approach to perform fault detection in electrical submersible pump systems, ACS Omega, 2021, V. 6(12), pp. 8104–8111, DOI: https://doi.org/10.1021/acsomega.0c05808

17. Peng L., Han G., Landjobo P.A., Shu J., Electric submersible pump broken shaft fault diagnosis based on principal component analysis, Journal of Petroleum Science and Engineering, 2020, V. 191, Article No. 107154, DOI: https://doi.org/10.1016/j.petrol.2020.107154

18. Peng L., Han G., Pagou A.L., A predictive model to detect the impending electric submersible pump trips and failures, SPE-206150-MS, 2021, DOI: https://doi.org/10.2118/206150-MS

19. Gupta S., Saputelli L., Nikolaou M., Applying big data analytics to detect, diagnose, and prevent impending failures in electric submersible pumps, SPE-181510-MS, 2016, DOI: https://doi.org/10.2118/181510-MS

20. Bhardwaj A.S., Saraf R., Nair G.G., Vallabhaneni S., Real-time monitoring and predictive failure identification for electrical submersible pumps, SPE-197911-MS, 2019, DOI: https://doi.org/10.2118/197911-MS

21. Gupta S., Nikolaou M., Saputelli L., Bravo C., ESP health monitoring KPI: A real-time predictive analytics application, SPE-181009-MS, 2016, DOI: https://doi.org/10.2118/181009-MS

22. Al-Hajri N.M., Al-Ghamdi A., Tariq Z., Mahmoud M., Scale-prediction/inhibition design using machine-learning techniques and probabilistic approach, SPE-198646-PA, 2020, DOI: https://doi.org/10.2118/198646-PA

23. Adesanwo M., Bello O., Olorode O. et al., Advanced analytics for data-driven decision making in electrical submersible pump operations management, SPE-189119-MS, 2017, DOI: https://doi.org/10.2118/189119-MS

24. Antonic M., Solesa M., Thonhauser G. et al., Implementing the autonomous adaptive algorithm to manage ESP operation in harsh reservoir conditions, IOP Conference Series: Materials Science and Engineering, 2021, V. 1201(1), Article No. 012083, DOI: https://doi.org/10.1088/1757-899x/1201/1/012083

25. Turpin J.L., Lea J.F., Bearden J.L., Gas-liquid flow through centrifugal pumps – correlation of data, Proceedings of the 3rd International Pump Symposium, Texas A&M University, 1986, pp. 13-20, URL: https://www.911metallurgist.com/blog/wp-content/uploads/2016/01/Gas-Liquid-Flow-Through-Centrifugal-Pumps-Correlation-of-Data.pdf

The construction and active operation of technically complex and critical industrial facilities, the consequences of accidents on which are extremely significant, requires ensuring the maximum level of safety. At the same time, any commercial activity, including the activities of fuel and energy complex facilities, requires managing and limiting costs and ensuring a certain level of profitability. The article is aimed at setting the task of creating a parametric system for ensuring the integrated safety of tank farms at marine oil terminals, allowing to reduce the risk of an emergency or emergency situation to the minimum acceptable level, while the cost of such a parametric system should tend to the minimum. A marine terminal with a tank farm is a strategic facility, both from the point of view of the country’s energy security and from the point of view of the scale of damage that could potentially occur in the event of an accident or emergency situation there. In recent years, the concept of ‘integrated security’ has become actively used as a generalization of the entire set of measures that ensure the operational, reliable and safe condition of a particular object. The article proposes an approach to the formation of a parametric system for ensuring the integrated safety of tank farms at sea oil terminals. The proposed methodology is based on an integrated approach to the term ‘safety’, which is implemented in the legislation on technical regulation of Russia. For each security parameter, it is proposed to establish appropriate criteria that make it possible to quantify and compare the actual level of security for this parameter with the acceptable level of security. The article proposes such parametric criteria for the tank farm of a marine oil terminal.

References

1. Terentyev A.A., Gorbatyuk Ie.V., Serpinska O.I., Borodinya V.V., Increasing efficiency of information system of complex security of buildings protection, East European Scientific Journal, 2021, no. 3–1(67), pp. 24-28.

2. Bocharov B.V., Sokolov V.A., Struchalin V.G. et al., Kompleksnaya bezopasnost’ na zheleznodorozhnom transporte i metropolitene (Integrated security in railway transport and metro), Part 1. Transportnaya bezopasnost’ na zheleznykh dorogakh i metropolitene (Transport safety on railways and subways), Moscow: Publ. of Uchebno-metodicheskiy tsentr po obrazovaniyu na zheleznodorozhnom transporte, 2015, 287 p.

3. Medvedev A.P., Kompleksnaya sistema obespecheniya bezopasnosti promyslovykh truboprovodov Zapadnoy Sibiri (Integrated system for ensuring the safety of field pipelines in Western Siberia): thesis of doctor of technical science, Ufa, 2004.

4. Filyak P.Yu., Information security and integrated security system: analysis, approaches (In Russ.), Informatsiya i bezopasnost’, 2016, V. 19, no. 1, pp. 72-79.

5. Travush V.I., Volkov Yu.S., Safety of buildings and structures: changes are coming (In Russ.), Standarty i kachestvo, 2016, no. 1, pp. 62-64.

6. Gorban N.N., Vasil’ev G.G., Leonovich I.A., Application of a risk-based approach to the management of the technical state of the tanks of offshore oil terminals (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2019, no. 2, pp. 75-77, DOI: https://doi.org/10.24887/0028-2448-2019-2-75-77

7. Gorban N.N., Vasil’ev G.G., Lezhnev M.A., Normative security regulations for steel vertical cylindrical tanks for oil and oil products (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2018, no. 9, pp. 148-151, DOI: https://doi.org/10.24887/0028-2448-2018-9-148-151

8. RD 153-112-017-97. Instruktsiya po diagnostike i otsenke ostatochnogo resursa vertikal’nykh stal’nykh rezervuarov (Instructions for the diagnosis and evaluation of the residual life of vertical steel tanks), Ufa: Publ. of USPTU, 1997, 74 p.

9. Makarenko O.A., Upravlenie resursom bezopasnoy ekspluatatsii stal’nykh rezervuarov dlya khraneniya nefteproduktov (Resource management for safe operation of steel tanks for storing petroleum products): thesis of doctor of technical science, Ufa, 2010.

By measuring the resistance to electric current spreading into the ground from large-sized terminals as an example, we have presented our results when analyzing the possibility to perform measurements for various electrodes installation designs in field conditions. Specific features of performing work during the inspection of the existing on-site facilities of main oil and oil product pipelines we have described. Including taking into account the shape of large-area grounding devices, their location in close areas with various terrain features, in the presence of long pipelines, communication lines (CLs), power transmission lines (PTLs), forests, etc. For certain cases, e.g., for terminals of facilities with a size of about 100 m, that are located on loams, we have justified the parameters of a two-beam design for measuring the spreading resistance, which ensures the required measurement accuracy and the inspection efficiency in field conditions. Our theoretical assessment of the nature of changes in the measured ground resistance at different distances between the grounding terminal’s support point and the measuring electrodes qualitatively coincides with the results obtained in field conditions. We have described the cases that exemplify the possibility of expanding the application scope of the results obtained to facilities located in areas with a rugged topography. We have also demonstrated that the basic ratios between the distances, at which it is advisable to install the electrodes in case of a double-beam measurement design, can also be used under certain conditions when inspecting the state of grounding systems of main oil and oil product pipelines facilities with overall dimensions of several hundred meters.

References

1. Person R., Lonnermark A., Tank fires. Review of fire incidents 1951 – 2003, Brandforsk Project 513-012. SP Swedish National Testing and Research Institute, 2004.

2. Petrova N.V., Cheshko I.D., Analiz ekspertnoy praktiki po issledovaniyu pozharov, proisshedshikh na ob"ektakh khraneniya nefti i nefteproduktov (Analysis of expert practice in the study of fires that occurred at oil and petroleum products storage facilities), Collected papers “Problemy i perspektivy sudebnoy pozharno-tekhnicheskoy ekspertizy“ (Problems and prospects of forensic fire-technical examination), Proceedings of International scientific and practical conference, St. Petersburg: Publ. of Saint-Petersburg University of State Fire Service of Emercom of Russia, 2015, pp. 78–81.

3. Mogil'ner L.Yu., Skuridin N.N., Vlasov N.A., Khuzyaganiev I.A., Application of non-destructive testing methods for examining the lightning protection systems of fire-explosive objects (In Russ.), Defektoskopiya, 2020, no. 11, pp. 58–64, DOI: https://doi.org/10.31857/S0130308220110068

4. Mogil'ner L.Yu., Rudomanov A.V., Skuridin N.N. et al., Analysis of approaches to the organization of lightning protection and grounding systems according to PJSC "Transneft" standards and foreign standards (In Russ.), Nauka i tehnologii truboprovodnogo transporta nefti i nefteproduktov = Science & Technologies: Oil and Oil Products Pipeline Transportation, 2021, V. 11, no. 1, pp. 46-55, DOI: https://doi.org/10.28999/2541-9595-2021-11-1-46-55

5. Mogil'ner L.Yu., Neganov D.A., Skuridin N.N., Obsledovanie metallokonstruktsiy na ploshchadochnykh ob"ektakh magistral'nykh truboprovodov (Inspection of metal structures at on-site facilities of main pipelines), Moscow: Tekhnosfera Publ., 2023, 440 p.

6. RD RD 153-34.0-20.525-00. Metodicheskie ukazaniya po kontrolyu sostoyanie zazemlyayushchikh ustroystv elektroustanovok (Guidelines for monitoring the condition of grounding devices in electrical installations), Moscow: Publ. of ORGRES, 2000, 64 p.

7. Karyakin R.N., Zazemlyayushchie ustroystva elektroustanovok: spravochnik (Grounding devices for electrical installations: reference book), Moscow: Energoservis Publ., 2006, 519 p.

8. Kvyatkovskiy G.I., Metod soprotivleniya zazemleniya v inzhenernoy geofizike (Ground resistance method in engineering geophysics), Moscow: Nedra Publ., 1993, 88 p.

9. Basmanov V.G., Zazemlenie i molniezashchita (Grounding and lightning protection), Part 1. Zazemlenie (Grounding), Kirov: Publ. of VyatGU, 2009, 155 p.

10. Lur'e A.I., Ispytanie zazemlyayushchikh ustroystv elektricheskikh ustanovok (Testing of grounding devices of electrical installations), Moscow: Gosenergoizdat Publ., 1941, 100 p.

11. Oslon A.B., About measuring ground resistance (In Russ.), Elektrichestvo, 1957, no. 2, pp. 56–59.

12. Kostruba S.I., Izmerenie elektricheskikh parametrov zemli i zazemlyayushchikh ustroystv (Measuring electrical parameters of the earth and grounding devices), Moscow: Energoatomizdat Publ., 1983, 168 p.

13. Zaborovskiy A.I., Elektrorazvedka (Electrical prospecting), Moscow: Gostoptekhizdat Publ., 1963, 424 p.

14. Oslon A.B., Kostruba S.I., Measuring the resistance of large ground electrodes (In Russ.), Elektrichestvo, 2006, no. 8, pp. 49–56.

15. Gossen MetraWatt GEOHM C Operating Instruction Manual, URL: www.manualslib.com/manual/1498457/Gossen-Metrawatt-Geohm-C.html

16. Nizhevskiy I.V., Nizhevskiy V.I., A technique of measuring of resistance of a grounding device (In Russ.), Elektrotekhnika i elektromekhanika, 2016, no. 3, pp. 50–57, DOI: http://doi.org/10.20998/2074-272X.2016.3.08

The perennial cryolithozone is unique and one of the most complex environmental conditions on the Earth. This phenomenon is of global importance for the study of natural processes, as well as for the development and application of technologies in various industries, including oil production. Permafrost conditions are of significant interest to the oil industry due to their potential impact on a variety of activities, including infrastructure development, resource exploration and environmental management. The oil production industry is actively developing in areas of perennial cryolithozone, since proven oil and gas reserves are located precisely in such regions. However, one of the important factors that must be taken into account is the release of radon-222 gas in these areas. One of the aspects that require special attention in the field of oil production in the permafrost zone is related to the measurement of radon-222 flux density. In permafrost areas, measuring radon-222 flux provides a valuable tool for assessing potential risks and mitigating their impacts. Long-term exposure to radon-222 can lead to an increased risk of developing cancer in oil industry workers, especially those who are closer to sources of radon radiation. Radon-222 is released from the ground and can penetrate buildings, potentially exposing employee to increased levels of radiation. The article discusses the results of determining the flux density of radon-222 in order to ensure safe working conditions and health protection for employees of NK Rosneft - NTC LLC.

References

1. Gulabyants L.A., Zabolotskiy B.Yu., Radon flux density as a criterion of radon hazard (In Russ.), ANRI, 2004, no. 3, pp. 16-20.

2. Miklyaev P.S., Zakonomernosti migratsii i ekskhalyatsii radona iz gruntov v atmosferu (Patterns of migration and exhalation of radon from soils into the atmosphere): thesis of candidate of geological and mineralogical sciences, Moscow, 2002.

3. Miklyaev P.S., PetrovaT.B., Tsapalov A.A., Principles for assessing the potential radon hazard of territories (In Russ.), ANRI, 2008, no. 4, pp. 14–19.

4. Sources and effects of ionizing radiation, UNCEAR (United Nations Scientific Committee on the Effects of Atomic Radiation), 2000, United Nations: New York. Annex B., 156 p.

5. Li Chenhua, Su Hejun, Zhang Hui, Zhou Huiling, Correlation between the spatial distribution of radon anomalies and fault activity in the northern margin of West Qinling Fault Zone, Central China, J. Radioanal Nucl. Chem., 2016, V. 308, pp. 679–686, DOI: http://doi.org/10.1007/s10967-015-4504-8

6. Froňka A., Indoor and soil gas radon simultaneous measurements for the purpose of detail analysis of radon entry pathways into houses, Radiat. Prot. Dosim., 2011, no. 145(2-3), pp. 117–122, DOI: http://doi.org/10.1093/rpd/ncr052

7. Khorzova L.I., Bykadorova O.A., Reduction of exhalation of radon daughter products from construction materials into the indoor air of residential buildings (In Russ.), Inzhenernyy vestnik Dona, 2018, no. 1, URL: http://www.ivdon.ru/ru/magazine/archive/n1y2018/4787

8. Sidyakin P.A., Sidel’nikova O.P., Mikhnev I.P., Osushchestvlenie radonovoy bezopasnosti pri stroitel’stve zdaniy i sooruzheniy (Implementation of radon safety during the construction of buildings and structures), Collected papers “Ekologicheskaya bezopasnost’ i ekonomika gorodskikh i teploenergeticheskikh kompleksov” (Environmental safety and economics of urban and thermal power complexes), Proceedings of international scientific and practical conference, Volgograd, 1999, pp. 12–14.