The article deals with the problem of developing work time study systems based on unified methodological approaches needed to define the number standards of administrative and managerial personnel. The main goal of the article is to examine methodological and practical application of correlation-regression analysis for the standards in question, highlighting most significant conditions and criteria for assessing calculated models. The authors made a brief review of scientific and methodological support for the practical application of mathematical statistics methods, including the correlation-regression analysis, used for the analysis of a wide range of socio-economic phenomena, as well as the development of work time standards. The article presents steps for implementation of correlation-regression analysis to develop the number standards, providing the main indicators for assessing the obtained models. The authors note both positive and negative sides of the method, highlighting conditions for its successful use. Much attention is given to issues concerning its practical application, in particular, the need to develop a procedure for obtaining initial data. The article provides a list of application programs that facilitates the use of mathematical statistics methods. The findings suggest that despite the drawbacks inherent in mathematical and statistical methods, when used correctly, these methods are an effective tool for solving problems in the field of developing number standards of administrative and managerial personnel.

References

1. Bakhtizina A.R., Vorontsov S.A., Kesaev S.A., Malinin S.V., Framework of labor standards of interprise: Outlines for development (In Russ.), Transport i khranenie nefteproduktov i uglevodorodnogo syr’ya, 2020, no. 4, pp. 71–79, DOI: https://doi.org/10.24411/0131-4270-2020-10414

2. Venetskiy I.G., Venetskaya V.I., Osnovnye matematiko-statisticheskie ponyatiya i formuly v ekonomicheskom analize (Basic mathematical and statistical concepts and formulas in economic analysis), Moscow: Statistika Publ., 1979, 447 p.

3. Kobzar’ A.N., Prikladnaya matematicheskaya statistika. Dlya inzhenerov i nauchnykh rabotnikov (Applied mathematical statistics. For engineers and scientists), Moscow: FIZMATLIT Publ., 2006, 816 p.

4. Fürster E., Rünz B., Methoden Der Korrelations – Und Regressionsanalyse: Ein Leitfaden Für Ökonomen, Berlin: Die Wirtschaft, 1979.

5. Hahn G.J., Shapiro S.S., Statistical models in engineering, Wiley, 1967, 355 p.

6. Chetyrkin E.M., Kalikhman I.L., Veroyatnost’ i statistika (Probability and statistics), Moscow: Finansy i statistika Publ., 1982, 319 p.

7. Dikiy B.A., Mart’yanov A.V., Stachev A.A., Application of the correlation and regression method analysis at calculating the standard number of employees at the oil pumping organizations of the system “Transneft” (In Russ.), Nauka i tehnologii truboprovodnogo transporta nefti i nefteproduktov = Science & Technologies: Oil and Oil Products Pipeline Transportation, 2014, no. 4(16), pp. 108–113.

8. Pavlenko A.P., Determining the number of personnel and time costs: computer program options (In Russ.), Chelovek i trud, 2007, no. 10, pp. 53–56.

9. Pavlenko A.P., Sovershenstvovanie normirovaniya truda sluzhashchikh (Improving the labor standards of employees): thesis of doctor of economical science, 1976.

10. Mezhotraslevye metodicheskie rekomendatsii po razrabotke normativnykh materialov dlya normirovaniya truda v neproizvodstvennykh otraslyakh narodnogo khozyaystva (Intersectoral methodological recommendations for the development of regulatory materials for labor standards in non-production sectors of the national economy), Moscow: Ekonomika Publ., 1988.

11. Metodicheskie ukazaniya po razrabotke ukrupnennykh normativov chislennosti i tipovykh struktur apparata upravleniya promyshlennykh predpriyatiy (Guidelines for the development of consolidated standards for the number of personnel and standard structures of the management apparatus of industrial enterprises), Moscow: Publ. of NII Truda, 1965, 104 p.

12. Mosin V.N., Larin V.M., Belov B.Kh., Metodika sozdaniya normativnoy bazy trudovykh zatrat na tekhnicheskuyu podgotovku proizvodstva (Methodology for creating a regulatory framework for labor costs for technical preparation of production), Saratov: Publ. of Saratov University, 1988, 144 p.

13. Normirovanie truda ITR i sluzhashchikh. Metodicheskie ukazaniya. NII truda (Labor standardization for engineering and technical workers and office employees. Methodological guidelines. Research Institute of Labor), Moscow: Publ. of State Committee of the USSR for Labor and Social Issues, 1987, 168 p.

14. Opredelenie chislennosti sluzhashchikh proizvodstvennykh ob”edineniy (kombinatov) i predpriyatiy. Obshcheotraslevye metodicheskie rekomendatsii (Determining the number of employees in production associations (plants) and enterprises. General industry guidelines), Moscow: Publ. of NII truda, 1980.

15. Organizatsiya i normirovanie truda rukovoditeley, spetsialistov i sluzhashchikh v novykh usloviyakh khozyaystvovaniya: Metodicheskie i normativnye materialy (Organization and regulation of labor of managers, specialists and employees in new economic conditions: Methodological and regulatory materials), Moscow: Publ. of VNTsentr po organizatsii truda, 1989.

16. Bychin V.B., Malinin S.V., Shubenkova E.V., Organizatsiya i normirovanie truda (Organization and regulation of labor), edited by Odegov Yu.G., Moscow: Ruslayn Publ., 2017, 147 p.

Deposits of hydrocarbons composed of carbonate rocks are being increasingly involved in the development of the global resourse base. Carbonate rocks are characterized by complex geological and petrophysical properties, with the heterogeneous structure of the void space. In addition to intergranular pores, these deposits also exhibit secondary porosity such as fractures and caverns. These factors have a significant impact on the hydrodynamic characteristics of the reservoir. The modern expanded suites of well logging methods, along with standard methods, include electrical microimagers, borehole acoustic scanners, cross-dipole acoustic logging, waveform acoustic logging, nuclear magnetic resonance logging and other special methods. Such comprehensive logging suites enable almost complete determination of secondary changes in carbonate rocks. However, due to the high cost of special methods, they application is often limited. Moreover, in order to maintain the commonality of methods for assessing petrophysical properties, obtaining the maximum possible number of parameters, and the possibility of involving historical data in modeling, it is necessary to use a standard logging suites. This article analyzes the existing methods for determining pore space types of complex carbonate reservoirs. Based on total porosity, resistivity, and rock compressibility data, a four-component void space model was developed. The modeled parameters were compared with actual field data. The method was tested on a productive horizon stratigraphically assigned to the Bilir formation of the Lower Cambrian in Eastern Siberia.

References

1. Budylko L.V., Spivak V.B., Shcherbakov Yu.D., Izuchenie razrezov skvazhin po materialam registratsii dinamicheskikh parametrov uprugikh voln (Study of borehole sections based on recording of dynamic parameters of elastic waves), Moscow: Publ. of VIEMS, 1979, 35 p.

2. Knyazev A.R., Nekrasov A.N., An experience of identification of fractured reservoirs from standard logs and scans (In Russ.), Karotazhnik, 2019, no. 5, pp. 40–54.

3. Zelenov A.S., Tekhnologiya obrabotki yaderno-magnitnogo karotazha v iskusstvennom magnitnom pole (Technology for processing nuclear magnetic logging in an artificial magnetic field): thesis of candidate of technical science, Tver, 2016, 110 p.

4. Oks L.S., Braylovskaya A.A., Aleksandrov B.L., Possibilities of using the standard logs set for complex-structure carbonate reservoir surveys (In Russ.), Karotazhnik, 2021, no. 7, pp. 22–35.

5. Nazarov D.V., Loshkin D.A., Volkov V.G. et al., Defining the cavernosity level for the complex Vendian-Cambrian carbonates using the standard well logging methods (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2019, no. 11, pp. 18–22, DOI: https://doi.org/10.24887/0028-2448-2019-11-18-22

6. Chang D., Vinegar H.J., Morriss C., Straley C., Effective Porosity, producible fluid, and permeability in carbonates from NMR logging, The Log Analyst, 1997, V. 38, no. 2, pp. 60-72.

7. Aleksandrov B.L., Izuchenie karbonatnykh kollektorov geofizicheskimi metodami (Study of carbonate reservoirs by geophysical methods), Moscow: Nedra Publ., 1979, 200 p.

8. Goryunov I.I., Geofizicheskie issledovaniya treshchinovatosti gornykh porod (Geophysical studies of rock fracturing), Proceedings of VNIGRI, 1968, V. 264, pp. 134-150.

9. 4. Nechay A.M., Quantitative assessment of secondary porosity in fractured oil and gas reservoirs (In Russ.), Prikladnaya geofizika, 1964, no. 38, pp. 206–212

10. Serra O., Formation MicroScanner image interpretation: Schlumberger Educational Service, Houston: SMP-7028, 1989, 117 p.

11. Aguilera R.F., Aguilera R.A., Triple porosity model for petrophysical analysis of naturally fractured reservoirs, Petrophysics, 2004, V. 45, no. 2, pp. 157–166.

12. Dobrynin V.M., Study of porosity of complex carbonate reservoirs (In Russ.), Geologiya nefti i gaza, 1991, no. 5, pp. 30–34.

In the last decade, there has been a significant increase in attention to hard-to-recover reserves. From the perspective of developing hard-to-recover reserves in unconventional deposits, particular interest is focused on the Khadum formation in the Eastern Ciscaucasia, which is the least studied, compared to the Bazhenov and Domanik productive deposits. The Khadum formation represents the main prospects for reserve growth and production increase. The formation attracts significant industrial interest among subsoil users. In order to stimulate the search for new approaches to the development of hard-to-recover reserves, the Khadum deposits are included in the list of objects for which a separate type of licensing is proposed - technological testing grounds for the search, testing and implementation of various development methods. Identifying the most promising areas for establishing such testing grounds is a crucial task in the industry. The study is based on geochemical research data and field well testing results. Through analytical and statistical processing of geochemical research data and core description information, the rocks were differentiated into two types with different hydrocarbon potential. Based on the test results, the potential productivity of the identified geochemical and lithological types was evaluated. Rocks of the second geochemical type were classified as industrially more promising objects. The most promising development interval was correlated with the lower part of the reservoir. A comprehensive approach was proposed for identifying the most promising zones for conducting pilot industrial operations.

References

1. Krotova A.G., Shpurov I.V., A review of the main trends in the development of the raw material base of hard-to-recover reserves of Oligocene deposits of the Khadum formation of the Eastern Pre-Caucasus region (In Russ.), Aktual’nye problemy nefti i gaza, 2024, V. 15, no. 4, pp. 430–444, DOI: https://doi.org/10.29222/ipng.2078-5712.2024-15-4.art8

2. Resolution of the Government of the Russian Federation of September 19, 2020 No. 1499 “Ob ustanovlenii vidov trudnoizvlekaemykh poleznykh iskopaemykh, v otnoshenii kotorykh pravo pol’zovaniya uchastkom nedr mozhet predostavlyat’sya dlya razrabotki tekhnologiy geologicheskogo izucheniya, razvedki i dobychi trudnoizvlekaemykh poleznykh iskopaemykh” (On the establishment of types of hard-to-recover minerals in relation to which the right to use a subsoil plot may be granted for the development of technologies for geological study, exploration and production of hard-to-recover minerals).

3. Stolyarov A.S., Ivleva E.I., Upper Oligocene sediments of the Ciscaucasus, Volga-Don, and Mangyshlak regions (Central Eastern Paratethys): Communication 1. Main compositional and structural features (In Russ.), Litologiya i poleznye iskopaemye = Lithology and Mineral Resources, 2004, no. 3, pp. 252-270.

4. Stolyarov A.S., Ivleva E.I., Upper Oligocene sediments in the Ciscaucasus, Volga-Don, and Mangyshlak Regions (Central part of the Eastern Paratethys): Communication 2. Facies-paleogeographic sedimentation settings (In Russ.), Litologiya i poleznye iskopaemye = Lithology and Mineral Resources, 2004, no. 4, pp. 359–368.

5. Goryagina T.A., Geologo-geokhimicheskie usloviya neftegazonosnosti oligotsenovykh otlozheniy Tsentral’nogo i Vostochnogo Predkavkaz’ya (Geological and geochemical conditions of oil and gas potential of Oligocene deposits of the Central and Eastern Ciscaucasia): thesis of candidate of geological and mineralogical science, Stavropol’, 2005.

6. Bazhenova O.K., Fadeeva N.P., Sen-Zhermes M.L. et al., Biomarkers of organic matter and oils of the Maikop series of the Caucasus-Scythian region (In Russ.), Geokhimiya, 2002, no. 9, pp. 993–1008.

7. Sharafutdinov V.F., Geologicheskoe stroenie i zakonomernosti razvitiya maykopskikh otlozheniy severo-vostochnogo Kavkaza v svyazi s neftegazonosnost’yu (Geological structure and patterns of development of Maikop deposits of the northeastern Caucasus in connection with oil and gas potential): thesis of doctor geological and mineralogical science, Moscow, 2003.

8. Chepak G.N., Shaposhnikov V.M., Features of oil-bearing capacity of the Oligocene clay layer of the Eastern Ciscaucasia (In Russ.), Geologiya nefti i gaza, 1983, no. 4, pp. 36–40.

9. Stafeev A.N., Stupakova A.V., Krasnova E.A. et al., Paleogeographic approach for the oil and gas potential assessment of the Khadum formation (Lower Oligocene) in Pre-Caucasus basin (In Russ.), Georesursy, 2023, V. 25, no. 2, pp. 89–104, DOI: https://doi.org/10.18599/grs.2023.2.7

10. Krasnova E.A., Stupakova A.V., Stafeev A.N. et al., Geological structure and paleogeographic zoning of the Khadum formation in Pre-Caucasus (In Russ.), Georesursy, 2021. V. 23, no. 2, pp. 99–109, DOI: https://doi.org/10.18599/grs.2021.2.9

11. Yandarbiev N.Sh., Fadeeva N.P., Kozlova E.V., Naumchev Yu.V., Khadum formation of Pre-Caucasus region as potential source of oil shales: Geology and geochemistry (In Russ.), Georesursy, 2017, no. S, pp. 208–226, DOI: http://doi.org/10.18599/grs.19.21

There are two main approaches to address well logs petrophysical interpretation challenges for seismic projects: standard which is performed using reserve estimation algorithms and inversion which is performed for the purpose of seismic inversion using three dimensional mineralogical models. Each method has its advantages and disadvantages. However, both approaches produce different results, which affect the quality of predictive models. The first method is commonly used for all carbon deposits and is applied in the most of Samara projects. Unfortunately, this method does not use the full range of well studies, especially sonic well. This leads to the fact that with the standard approach, it is impossible to obtain a stable separation of reservoirs and non-reservoirs based on impedance characteristics and perform a dynamic forecast. The second approach produces three-dimensional mineralogical model of reservoir rocks with a wide range of petrophysics. This method is assumed to use for seismic interpretation and based on seismic inversion technique. The obtained comparative assessments and results of petrophysical modeling at various fields indicate the feasibility of implementing this method. The authors' researches and tests were based on practical experience of geological exploration in the Samara region, Volga-Ural Petroleum and Gas Province. The target for geological exploration is the Paleozoic terrigenous-carbonate deposits located within the Buzuluk Basin.

References

1. Yagov I.E., Nekrosova T.V., Radchenko A.A., Instruktsiya po obrabotke, interpretatsii i analizu dannykh GIS dlya tseley seysmicheskoy inversii (Instructions for processing, interpreting and analyzing well logging data for the purposes of seismic inversion), Moscow: Publ. of Fugro-Geoscience GmbH branch, 2009.

2. Zalyaev N.Z., Metodika avtomatizirovannoy interpretatsii geofizicheskikh issledovaniy skvazhin (Methodology for automated interpretation of geophysical well surveys), Minsk: Universitetskoe Publ., 1990, 142 p.

3. Elanskiy M.M., Enikeev B.N., Ispol’zovanie mnogomernykh svyazey v neftegazovoy geologii (Use of multidimensional relationships in petroleum geology), Moscow: Nedra Publ., 1991, 205 p.

4. Aleksandrov B.L., Izuchenie karbonatnykh kollektorov geofizicheskimi metodami (Study of carbonate reservoirs by geophysical methods), Moscow: Nedra Publ., 1979, 200 p.

5. Dubrule O., Geostatistics for seismic data integration in Earth models, Tulsa, Society of Exploration Geophysicists; European Association of Geoscientists and Engineers, 2003, 281 p., DOI: https://doi.org/10.1190/1.9781560801962

The effectiveness of well drilling is determined by the design of the rock-breaking tool and the quality of bottom hole cleaning. This article analyzes technical solutions and proposes a new design for a two-stage drill bit. This design aims to improve the efficiency of drilling wells by providing more effective cleaning of the wellbore and preventing secondary grinding of the cuttings. A unique feature of this design is the integration of rock-breaking and stabilizing elements with helical ribs and channels with a variable pitch. It ensures an accelerated flow of drilling mud without the formation of mud rings. The stabilizing section eliminates local bends and ledges, stabilizes the wellbore, reduces lateral vibrations, and acts as a screw pump. This screw pump helps detach cuttings from the bottom, which prevents their secondary grinding and the formation of «cuttings beds». The absence of sharp bends in the blades creates favorable conditions for the operation of the two-stage bit, and the increase in the cross-section of the blades from bottom to top also helps increase its durability. There are following advantages of two-stage bit use: reduced possibility of sticking; reduced vibrations and increased tool life; increased penetration rate per bit; reduced number of tripping operations and contact time between casing and drill strings; reduced compressive loads, mechanical stresses and wear on drilling and intermediate casing strings. The advantages of this two-stage bit predetermine the improvement of the main indicators of the drilling process and enable to recommend it for practical use.

References

1. Borisov K.A., Razrabotka metodicheskikh i tekhnologicheskikh rekomendatsiy po povysheniyu effektivnosti bureniya skvazhin putem preduprezhdeniya anomal’nogo iznosa rezhushchikh elementov dolot PDC (Development of methodological and technological recommendations for increasing the efficiency of well drilling by preventing abnormal wear of cutting elements of PDC bits): thesis of candidate of technical science, 2020.

2. Ishbaev G.G., Kovalevskiy E.A., Baluta A.G. et al., Efficiency evaluation of rock destruction by PDC cutters with different geometries of the diamond layer (In Russ.), Burenie i neft’, 2024, no. 11, pp. 18–21, DOI: https://doi.org/10.62994/2072-4799.2024.76.32.006

3. Khuzina L.B., Shaykhutdinova A.F., Technology solution for improvement of the PDC drill bits performance (In Russ.), Izvestiya vuzov. Neft’ i gaz, 2016, no. 4,

pp. 84–87, DOI: https://doi.org/10.31660/0445-0108-2016-4-84-87

4. Khabibullin M.Ya., Gilaev G.G., Bakhtizin R.N., Improvement of calculated strength indicators of cylindrical shells to reduce the metal consumption of equipment, SOCAR Proceedings, 2023, no. 2, pp. 111–117, DOI: https://doi.org/10.5510/ogp20230200853

5. Fedorova N.G., Kovrizhkin D.N., Kulaev E.V., O vliyanii konfiguratsii bokovoy tsilindricheskoy chasti dolota tipa ISM na snizhenie ego poperechnykh vibratsiy (On the influence of the configuration of the lateral cylindrical part of the ISM type bit on the reduction of its transverse vibrations), Proceedings of IV International scientific and practical conference “Innovatsionnye tekhnologii v neftegazovoy otrasli. Problemy ustoychivogo razvitiya territoriy” (Innovative technologies in the oil and gas industry. Problems of sustainable development of territories), dedicated to the 30th anniversary of the Faculty of Petroleum Engineering NCFU, 7–8 December 2023, Stavropol: Publ. of NCFU, 2023, pp. 357–362.

6. Mingazov R.R., Ishbaev G.G., Baluta A.G. et al., Reducing vibration while drilling by improving the design of PDC bits (In Russ.), Burenie i neft’, 2021, no. 4, pp. 14–17.

7. Tret’yak A.Ya., Krivosheev K.V., Donchenko D.S., Development of innovative bits reinforced with PDC cutters (In Russ.), Bulatovskie chteniya, 2023, V. 1, pp. 382–387.

8. Author’s certificate SU 817202 A1. Hole-bottom slime-disintegrating device, Authors: Kushnarenko N.A., Konrad F.F., Panov V.N., Proselkov Yu.M.

9. Zotov B.N., Calculation of characteristics of screws with constant and variable pitch (In Russ.), Mashiny i ustanovki: proektirovanie, razrabotka i ekspluatatsiya, 2015, no. 3, pp. 29–40.

10. Author’s certificate SU 1694849 A1. Calibrator-intensifier, Authors: Klimov V.V., Kushnarenko N.A., Marchenko R.N.

11. Patent RU 2841073 C1, Double-deck bit for drilling wells, Inventors: Klimov V.V., Gilaev G.G., Usov S.V., Al’-Idrisi M.S.A.Kh.

A numerical finite element model of a near-wellbore zone with a slotted perforation was created during the work, which includes a production casing, a cement stone and a reservoir rock section near the well. The model considers the dependence of changes in rock permeability on effective stresses, and defines contact elements at the cement stone – rock and cement stone – casing boundaries to exclude the occurrence of stress concentrators on the surface of the sections of these media. A multivariate numerical simulation of the stress-strain state of the near-wellbore zone was performed, regarding changes in the depression on the reservoir for the well that entered the terrigenous productive reservoir of one of the oil fields in the south of the Perm Region. It is shown that when creating slotted channels in the production casing, small areas of its destruction may occur in the upper and lower parts of the slots. The analysis of the stress state of the cement stone based on the Coulomb-Mohr criterion confirmed its stability even at a maximum depression of 9 MPa, the safety factor was 1,8. An analysis of the rock stability using the Coulomb-Mohr criterion showed that the reservoir should not be destroyed, and the safety factor was 1,1 with a depression of 9 MPa. The simulation results of slotted perforation show its effectiveness due to the appearance of rock discharge areas on the lateral surfaces of the cracks. The optimal operating mode of the well should be considered to ensure maximum productivity.

References

1. Fjær E., Holt R.M., Horsrud P. et al., Petroleum related rock mechanics, Amsterdam: Elsevier, 2008, 492 p.

2. Pavlov V.A., Kuleshov V.S., Korolev D.O. et al., Prakticheskoe rukovodstvo po geomekhanicheskomu modelirovaniyu (A practical guide to geomechanical modeling), Tyumen: Ekspress Publ., 2023, 440 p.

3. Lukin S.V., Esipov S.V., Zhukov V.V. et al., Borehole stability prediction to avoid drilling failures (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2016, no. 6, pp. 70–73.

4. Vashkevich A.A., Zhukov V.V., Ovcharenko Yu.V. et al., Development of integrated geomechanical modeling in Gazprom Neft PJSC (In Russ.), Neftyanoe

khozyaystvo = Oil Industry, 2016, no. 12, pp. 16–19.

5. Popov S.N., Chernyshov S.E., Development of a geomechanical model and determination of the drilling fluid “density window” in the interval of Famennian productive deposits (on the example of a site of one of the Timano-Pechora oil and gas province oilfield) (In Russ.), Geologiya, geofizika i razrabotka neftyanykh i gazovykh mestorozhdeniy, 2023, no. 11(383), pp. 32–39, DOI: https://doi.org/10.33285/2413-5011-2023-11(383)-32-39

6. Mostafa T., Reda M., Mosaad M.et al., Exploring hydrocarbon potential with 3D modeling techniques: Lower Cretaceous formations in Abu Sennan field, north Western Desert, Petroleum, 2025, V. 11, no. 2, pp. 158-173, DOI: https://doi.org/https://doi.org/10.1016/j.petlm.2025.03.004

7. Linsheng Wang, Xinpu Shen, Baocheng Wu et al., Integrated analysis of the 3D geostress and 1D geomechanics of an exploration well in a new gas field, Energies, 2023, no. 16(2), DOI: https://doi.org/10.3390/en16020806. – EDN: HSSWEZ

8. Popov S.N., Development of 3D geomechanical model of the Achimov deposits of one of the fields of the Far North (In Russ.), Aktual’nye problemy nefti i gaza, 2019, no. 2(25), pp. 1–17, DOI: https://doi.org/10.29222/ipng.2078-5712.2019-25.art3

9. Wei Li, Liang Chen, Xin Wang et al., Acid fracturing technology and effect evaluation of carbonate horizontal well in Fuman oilfield, Journal of Physics: Conference Series, 2024, V. 2679, DOI: https://doi.org/10.1088/1742-6596/2679/1/012010

10. Savel’ev V.V., Ognev I.N., Sensitivity analysis of the fracturing fluid rheology effect on the hydraulic fracture geometry in the terrigenous reservoirs (In Russ.), Georesursy, 2023, V. 25, no. 4, pp. 138–148, DOI: https://doi.org/10.18599/grs.2023.4.12

11. Astaf’ev V.N., Mitrofanov G.M., Integrated modeling of multi-stage hydraulic fracturing of low-permeable reservoirs (In Russ.), Georesursy, 2024, V. 26, no. 3,

pp. 116–125, DOI: https://doi.org/10.18599/grs.2024.3.13

12. Prismotrov K.V., Varavva A.I., Voroninskaya Ya.G., Multi-stage hydraulic fracturing simulation methodology at the wells of the gas condensate field X (In Russ.), Georesursy, 2023, V. 25, no. 4, pp. 82–91, DOI: https://doi.org/10.18599/grs.2023.4.5

13. Tananykhin D.S., Scientific and methodological support of sand management during operation of horizontal well, Internation journal of engineering, Transaction A: Basics, 2024, V. 37, no. 7, pp. 1395–1407, DOI: https://doi.org/10.5829/ije.2024.37.07a.17

14. Ermolaev A.I., Efimov S.I., Pyatibratov P.V. et al., Estimation of the maximum downhole pressure, excluding the destruction of the bottom-hole zone of the formation, based on geomechanical core studies (In Russ.), SOCAR Proceedings, 2023, no. 1, pp. 61–69, DOI: https://doi.org/10.5510/OGP2023SI100832

15. Chernyshov S.E., Popov S.N., Savich A.D., Derendyaev V.V., Analysis of wells cement sheath stability during shaped charge perforating based on geomechanical modeling (In Russ.), Georesursy, 2023, V. 25, no. 2, pp. 245–253, DOI: https://doi.org/10.18599/grs.2023.2.18

16. Chernyshov S.E., Popov S.N., Varushkin S.V. et al., Scientific justification of the perforation methods for Famennian deposits in the southeast of the perm region based on geomechanical modelling (In Russ.), Zapiski Gornogo instituta, 2022, V. 257, pp. 732–743, DOI: https://doi.org/10.31897/PMI.2022.51

17. Chernyshov S.E., Popov S.N., Van K. et al., Analysis of changes in the stress-strain state and permeability of a terrigenous reservoir based on a numerical model of the near-well zone with casing and perforation channels (In Russ.), Georesursy, 2024, V. 26, no. 4, pp. 209–217, DOI: https://doi.org/10.18599/grs.2024.4.6

18. Hongxu Zhang, Huajie Liu, Ruochen Zheng et al., Application of ABAQUS Flow-Solid coupling model to evaluate sealing capability of sandstone formation interface based on the cracking behavior of cohesive force units, Construction and Building Materials, 2023, V. 409, DOI: https://doi.org/10.1016/j.conbuildmat.2023.133863

19. Ponikarov A., Modeling of heat exchangers in ANSYS CFX for the digital twins development, E3S Web of Conferences, 2024, V. 583, DOI: https://doi.org/10.1051/e3sconf/202458303021

20. Popov S. N., Chernyshov S.E., Krivoshchekov S.N., Comparative analysis of the analytical and numerical methods for calculating the stress-strain state of the near-wellbore zone based on the elastic model taking into account the main structural elements of the well (In Russ.), Izvestiya Tomskogo politekhnicheskogo universiteta. Inzhiniring georesursov, 2023, V. 334, no. 5, pp. 94–102, DOI: https://doi.org/10.18799/24131830/2023/5/3961

21. Zhang J., Moridis G., Blasingame Th.A., Message passing interface (MPI) parallelization of iteratively coupled fluid flow and geomechanics codes for the simulation of system behavior in hydrate-bearing geological media. Part 1: methodology and validation, SPE-206161-PA, 2022, DOI: https://doi.org/10.2118/206161-PA

22. Leiju Tian, Yuhuan Bu, Huajie Liu et al., Effects of the mechanical properties of a cement sheath and formation on the sealing integrity of the cement-formation interface in shallow water flow in deep water, Construction and Building Materials, 2023, V. 369, DOI: https://doi.org/10.1016/j.conbuildmat.2023.130496

23. Xiaobin Li, Wei Wei, Yuxuan Xia et al., Modeling and petrophysical properties of digital rock models with various pore structure types: An improved workflow,

Int J Coal Sci Technol., 2023, no. 10, DOI: https://doi.org/10.1007/s40789-023-00627-z

24. Karev V.I., Kovalenko Yu.F., Khimulya V.V., Shevtsov N.I., Physical modeling of directional unloading method (In Russ.), Gazovaya promyshlennost’, 2021, no. 7(819), pp. 66–73.

The paper presents an approach for the automatic determination of work-and-accumulation cycle durations in artificial production wells operating in automatic restart regimes. An algorithm based on convolutional neural network that uses field data on time-varying dynamic fluid level (pump intake pressure) in the well’s annular space was developed. The authors trained the neural network using data from operating regimes of wells in Western Siberia. The implemented algorithm demonstrated high effectiveness in determining the actual cycle durations of work and accumulation cycles. It also outperforms traditional rule-based and autocorrelation methods. During the testing of the algorithm on real field data, it identified moments of well-start and well-stop with sufficient accuracy for practical use. This enables engineers to monitor the current operating regimes of an artificial well in real time. The authors plan to use this algorithm for simulation of oil production by detecting current operating regime, adjusting work/stop durations and further optimizing the cycles. Engineers can also apply this approach to automate monitoring of operating regimes in artificial wells and to detect deviations from planned regimes in a timely manner. In addition, the proposed method scales easily and can be adapted to different conditions of production and oil field, making it applicable both to new and existing wells.

References

1. Pashali A.A., Khalfin R.S., Sil’nov D.V. et al., On the optimization of the periodic mode of well production, which is operated by submergible electric pumps in Rosneft Oil Company (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2021, no. 4, pp. 92-96, DOI: https://doi.org/10.24887/0028-2448-2021-4-92-96

2. Pityuk Yu.A., Kunafin A.F., Bayramgalin A.R. et al., Identification of unplanned shutdowns for buildup tests in real time (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2020, no. 2, pp. 32–35, DOI: https://doi.org/10.24887/0028-2448-2020-2-32-35

3. Ishkina Sh.Kh., Zakir’yanov I.I., Sagdeev E.I. et al., Approbation of the machine learning based approach to acoustic liquid level determination (In Russ.), Ekspozitsiya neft’ i gaz, 2024, no. 5, pp. 51–56, DOI: https://doi.org/10.24412/2076-6785-2024-5-51-56

4. Pashali A.A., Sil’nov D.V., Topol’nikov A.S. et al., Bringing the oil wells equipped by elictrical submersible and sucker rod pumps on to stable production based on complex approach using machine learning and digital twins (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2021, no. 7, pp. 112–117, DOI: https://doi.org/10.24887/0028-2448-2021-7-112-117.

5. Lovrić M., Milanović M., Stamenković M., Algoritmic methods for segmentation of time series: An overview, Journal of Contemporary Economic and Business Issues, 2014, V. 1, no. 1, pp. 31–53.

6. Perslev M. et al., U-time: A fully convolutional network for time series segmentation applied to sleep staging, Advances in Neural Information Processing Systems, 2019, V. 32.

7. Yuncong Yu et al., Segmentation of multivariate time series with convolutional neural networks, Proceedings of the International Conference on Calibration-Methods and Automotive Data Analytics, Berlin, Deutschland, 21.05.2019 – 22.05.2019.

The importance of research on selection of optimal acid treatments is related to the need for improved efficiency of oil and gas production stimulation in carbonate reservoirs. Mineralogy heterogeneity of such formations has a strong effect on dissolution mechanism, wormholes formation, and ultimate modification of reservoir properties; therefore, conducting laboratory coreflood tests enables to develop practical recommendations for field conditions. This paper presents the results of coreflood tests to select the optimal flow conditions of acid composition in carbonate reservoirs. Within the scope of coreflood experiments, pressure drop across the core was measured, permeabilities before and after acid treatment were estimated, the time required for a wormhole to break through the core was determined. For each research target, four injected pore volumes were obtained before breakthrough of acid composition with formation of highly conductive wormhole, corresponding to different desired injection rates of acid composition. Results of coreflood experiments were interpreted, model constants for acid composition in each target were estimated. It was found that the relationship between carbonate reservoirs mineralogy and the Damköhler number (Da) is not direct, but rather is established through the impact of mineralogy on reaction kinetics, which in turn determines the dynamics of channel (wormhole) formation during acid treatment. Relationship between Da and dissolution mechanisms was also established which, in future, would provide practical recommendations for design of acid treatment technology in terms of selection of optimal injection rates and composition.

References

1. Khuzin, R.A., Khizhnyak G.P., Laboratory research of acid concentration and injection rate on wormholing process under reservoir conditions (In Russ.), Vestnik Permskogo natsional’nogo issledovatel’skogo politekhnicheskogo universiteta. Geologiya. Neftegazovoe i gornoe delo = Perm Journal of Petroleum and Mining Engineering, 2019, V. 19, no. 4, pp. 356–372, DOI: https://doi.org/10.15593/2224-9923/2019.4.5

2. Mohammadi S., Mechanistic analysis of matrix-acid treatment of carbonate formations: An experimental core flooding study, Heliyon, 2024, V. 10, no. 3,

DOI: https://doi.org/10.1016/j.heliyon.2024.e24936

3. Ibragimov N.G., Musabirov M.Kh., Yartiev A.F., Tatneft’s experience in commercialization of import-substituting well stimulation technologies (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2015, no. 8, pp. 86–89.

4. Nasr-El-Din H.A., Al-Nakhli A., Al-Driweesh S. et al., Optimization of surfactant-based fluids for acid diversion, SPE-107687-MS, 2007,

DOI: https://doi.org/10.2118/107687-MS

5. Gomari K.A.R., Karoussi O., Hamouda A.A., Mechanistic study of interaction between water and carbonate rocks for enhancing oil recovery, SPE-99628-MS, 2006, DOI: https://doi.org/10.2118/99628-MS

6. Yartiev A.F., Musabirov M.H., Tufetulov A.M., Grigoryeva L.L., Enhancement of horizontal well oil recovery by means of chemical stimulation, Asian Social Science, 2015, V. 11, no. 11, pp. 346–356, DOI: https://doi.org/10.5539/ass.v11n11p346

7. Khisamov R.S., Musabirov M.Kh., Yartiev A.F., Uvelichenie produktivnosti karbonatnykh kollektorov neftyanykh mestorozhdeniy (Increase in productivity of carbonate reservoirs of oil fields), Kazan’: Ikhlas Publ., 2015, 192 p.

8. Zakirov I.S., Zakharova E.F., Musabirov M.Kh., Ganiev D.I., Approaches to the estimate of chemical reagents efficiency on the domanic deposits core material

(In Russ.), Neftyanaya provintsiya, 2019, no. 3, pp. 141–155, DOI: https://doi.org/10.25689/NP.2019.3.141-155

9. Musabirov M.Kh., Dmitrieva A.Yu., Podbor kislotnykh kompozitsiy dlya obrabotki prizaboynoy zony plastov mestorozhdeniy NGDU “Bavlyneft’” (Selection of acid compositions for treatment of bottomhole formation zones of oil and gas production department “Bavlyneft”), Proceedings of TatNIPIneft’ / PAO “Tatneft’”, Naberezhnye Chelny: Ekspozitsiya Neft’ Gaz Publ., 2017, V. 85, pp. 217–228.

10. Glushchenko V.N., Ptashko O.A., Filtratrion research of novel acidic compounds for treatment of carbonate reservoirs (In Russ.), Vestnik Permskogo natsional’nogo issledovatel’skogo politekhnicheskogo universiteta. Geologiya. Neftegazovoe i gornoe delo = Perm Journal of Petroleum and Mining Engineering, 2014, no. 11,

pp. 46–56, DOI: https://doi.org/10.15593/2224-9923/2014.11.5

11. Salimov V.G., Ibatullin R.R., Nasybullin A.V. et al., Experimental study of carbonate rocks dissolution rate acid fracturing fluids (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2013, no. 1, pp. 68–71.

12. Ibatullin R.R., Salimov V.G., Nasybullin A.V., Salimov O.V., Experimental study of reaction rate constants of carbonate rocks in acid fracturing fluids (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2013, no. 2, pp. 66–69.

13. Mannanov I.I., Taipov K.S., Gilya-Zetinov A.G., Ganiev D.I., Optimizing approach to selecting acid systems and injection conditions based on core acidizing experiments (In Russ.), Neftyanaya provintsiya, 2022, no. 1, pp. 223–237, DOI: https://doi.org/10.25689/NP.2022.1.223-237

14. Glasbergen G., Kalia N., Talbot M.S., The optimum injection rate for wormhole propagation: Myth or reality, SPE-121464-MS, 2009,

DOI: https://doi.org/10.2118/121464-MS

The statistical parameters of the random permeability field have a significant impact on the nature of fluid flow in a porous medium and reservoir development indicators. These parameters have high uncertainty, and their values are in a wide range. With a strong heterogeneity of the permeability of the formation, the liquid flows through the formed channels of preferential filtration, which are not caused by the presence of extended geological inhomogeneities, but are a consequence of focusing the filtration flow by fluctuations in the permeability field. In this article, the issue of the possibility of determining the statistical parameters of the reservoir permeability field for subsequent use in analytical models for calculating the well flow rate dispersion is investigated. It is shown that the synthetic pressure recovery curves of a vertical well in an inhomogeneous reservoir with a lognormal random permeability distribution are characterized by the presence of a pronounced «ramp» effect. The radius of the study at which the pressure curves enters the «ramp» area is comparable to the correlation length of the permeability field. Analytical models are proposed that make it possible to calculate the well flow rate variance for various correlation lengths of the permeability field in a wide range of the coefficient of variation.

References

1. Gaydukov L.A., Posvyanskiy D.V., Features of liquid filtration in heterogeneous formations with random permeability. Part 1. The flow of liquid to individual well

(In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2024, no. 8, pp. 79–83, DOI: https://doi.org/10.24887/0028-2448-2024-8-79-83

2. Dagan G., Stochastic modeling of groundwater flow by unconditional and conditional probabilities: 1. Conditional simulation and the direct problem, Water resources research, 1982, V. 18(4), pp. 835-848, DOI: https://doi.org/10.1029/WR018i004p00835

3. Shvidler M.I., Statisticheskaya gidrodinamika poristykh sred (Statistical hydrodynamics of porous media), Moscow: Nedra Publ., 1985, 288 p.

4. Rytov S.M., Vvedenie v statisticheskuyu radiofiziku (Introduction to Statistical Radiophysics), Part. 1. Sluchaynye protsessy (Random processes), Moscow: Nauka Publ., 1966, 960 p.

5. Bjerg P.L., Hinsby K., Christensen T.H., Gravesen P.J., Spatial variability of hydraulic conductivity of an unconfined sandy aquifer determined by a mini slug test, Hydrol., 1992, V. 136, No. 1–4, pp. 107–122, DOI: https://doi.org/10.1016/0022-1694(92)90007-I

6. Hamdi H., Well-test response in stochastic permeable media, Journal of Petroleum Science and Engineering, 2014, V. 119, pp. 169–184,

DOI: https://doi.org/10.1016/j.petrol.2014.05.005

7. Novikov A.V. Posvyanskii D.V., The use of Feynman diagrammatic approach for well test analysis in stochastic porous media, J. Comp. Geoscience, 2020, V. 24,

pp. 921-931, DOI: https://doi.org/10.1007/s10596-019-09880-1

This paper discusses certain aspects of implementing a simultaneous water and gas injection (SWAG) technology at a pilot site within a terrigenous reservoir of the Romashkino oilfield in the Republic of Tatarstan. The injection was carried out using a pump–ejector system (PES). Operating parameters were monitored by wellhead pressure sensors, along with gas and water flowmeters. Fresh water from the reservoir pressure-maintenance system and associated petroleum gas collected from the annular space of 11 producing wells were used as injection agents. The gas was delivered to the ejector mixing chamber through a dedicated gas-gathering system. Three injection wells were selected as recipient wells, one of which operated under a simultaneous–separate injection. The initial pilot tests of SWAG injection revealed a gradual increase in discharge pressure of the booster pump during PES operation, due to a decline in injectivity of the well. To obtain additional downhole data, a high-resolution downhole logging tool was deployed in one of the injection wells. The analysis of the acquired data suggested the formation of gas hydrates and subsequent near-wellbore plugging. To test this hypothesis, associated gas and mineralized water with a density of 1180 kg/m³ were injected. The discharge pressure of the pump remained stable over a two-day period, confirming that hydrate formation can be prevented when mineralized saline water is used. Due to a reduction in annular pressure in one of the gas donor wells, its operating mode changed from intermittent to stable continuous production, thereby demonstrating the efficiency of the PES.

References

1. Suleymanov B.A., Teoriya i praktika uvelicheniya nefteotdachi plastov (Theory and practice of enhanced oil recovery), Moscow –Izhevsk: Publ. of Institut komp’yuternykh issledovaniy, 2022, 288 p.

2. Akhmadeyshin I.A., On the technological schemes wag with simultaneous injection gas and water (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2014, no. 6, pp. 104–105.

3. Drozdov A.N., Problems in wag implementation and prospects of their solutions (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2014, no. 8, pp. 100–104.

4. Vafin R.V., Razrabotka neftenasyshchennykh treshchinovato-porovykh kollektorov vodogazovym vozdeystviem na plast (Development of oil-saturated fractured-porous reservoirs using water-gas stimulation), St. Petersburg: Nedra Publ., 2007, 216 p.

5. Vafin T.R., Sovershenstvovanie tekhnologiy vodogazovogo vozdeystviya na plast na nestatsionarnom rezhime (Improvement of technologies for water-gas stimulation of the reservoir in a non-stationary mode): thesis of candidate of technical science, Bugul’ma, 2016.

6. Kalinnikov V.N., Razrabotka tekhnologii ispol’zovaniya zatrubnogo neftyanogo gaza dobyvayushchikh skvazhin dlya zakachki vodogazovykh smesey v nagnetatel’nye skvazhiny (Development of a technology for using annular oil gas from production wells to inject water-gas mixtures into injection wells): thesis of candidate of technical science, Moscow, 2022.

7. Drozdov A.N., Verbitskiy V.S., Shishulin V.A. et al., Study of the influence of foaming surfactants on the operation of a multistage centrifugal pump when pumping water-gas mixtures created by an ejector (In Russ.), SOCAR Proceedings Special Issue, 2022, no. 2, pp. 037–044, DOI: http://doi.org/10.5510/OGP2022SI200744

8. Makogon Yu.F., Gidraty prirodnykh gazov (Natural gas hydrates), Moscow: Nedra Publ., 1974, 208 p.

9. Troynikova A.A., Istomin V.A., Semenov A.P. et al., Outlooks for application of electrolytes as inhibitors of hydrating (In Russ.), Vesti gazovoy nauki, 2022, no. 3(52), pp. 90–100.

The paper considers an approach to thermal flow simulation of thermal recovery technology. The technology entails steam injection in heavy oil reservoir to heat it up and thereby reduce oil viscosity. The paper presents a modeling method based on finite element pressure estimation with flow balancing and explicit phase transition allowing for local time stepping for a separate group of elements to enable consistent estimation of phase saturations. The method considers energy release/consumption during changes in physical state of water, while temperature estimation is coupled with finite-element pressure analysis. Temperature changes resulting from fluid transfer and heat flows associated with thermal conductivity of the medium are also considered. Heat flows are estimated using finite-difference approximation enabling local balance of heat energy. The grid is generated in such a way that well design is defined by grid lines. Comparison of simulated and actual oil production data over the period of 3,5 years is presented for one of heavy oil fields in the Republic of Tatarstan. A good match between simulated and field data is demonstrated for various well pairs located within the field area of interest. Well interference study suggests significant potential effects from offset wells. Hence, optimization of field development necessitates that simulation studies be conducted with account of offset wells, rather than for individual well pair.

References

1. Liu P. et al., Experimental and numerical investigation on extra-heavy oil recovery by steam injection using vertical injector – horizontal producer, Journal of Petroleum Science and Engineering, 2021, V. 205, DOI: https://doi.org/10.1016/j.petrol.2021.108945

2. Mokheimer E.M.A. et al., A comprehensive review of thermal enhanced oil recovery: Techniques evaluation, Journal of Energy Resources Technology, 2019, V. 141, no. 3, DOI: https://doi.org/10.1115/1.4041096

3. Mozaffari S. et al., Numerical modeling of steam injection in heavy oil reservoirs, Fuel, 2013, V. 112, pp. 185–192, DOI: https://doi.org/10.1016/j.fuel.2013.04.084

4. Lawal K.A., Olamigoke O., On the optimum operating temperature for steam floods, SN Applied Sciences, 2021, V. 3, DOI: https://doi.org/10.1007/s42452-020-04082-2

5. Mir H., Siavashi M., Whole-time scenario optimization of steam-assisted gravity drainage (SAGD) with temperature, pressure, and rate control using an efficient hybrid optimization technique, Energy, 2022, V. 239, DOI: https://doi.org/10.1016/j.energy.2021.122149

6. Siavashi M., Garusi H., Derakhshan S., Numerical simulation and optimization of steam-assisted gravity drainage with temperature, rate, and well distance control using an efficient hybrid optimization technique, Numerical Heat Transfer, Part A: Applications, 2017, V. 72, no. 9, pp. 721–744,

DOI: https://doi.org/10.1080/10407782.2017.1400330

7. Khisamov R.S., Nazimov N.A., Khairullin M.Kh. et al., Estimation of the inflow profile to the horizontal wellbore based on the results of thermohydrodynamic research (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2021, no. 12, pp. 114–116, DOI: https://doi.org/10.24887/0028-2448-2021-12-114-116

8. Khisamov R.S., Morozov P.E., Khairullin M.Kh. et al., Simulation of the SAGD process taking into account the threshold pressure gradient (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2018, no. 8, pp. 48-51, DOI: https://doi.org/10.24887/0028-2448-2018-8-48-51

9. Soloveichik Y.G. et al., A method of FE modeling multiphase compressible flow in hydrocarbon reservoirs, Computer Methods in Applied Mechanics and Engineering, 2022, V. 390, DOI: https://doi.org/10.1016/j.cma.2021.114468

10. Persova M.G., Soloveichik Yu.G., Ovchinnikova A.S. et al., On the approach to oil production optimization using chemical stimulation methods (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2023, no. 3, pp. 42–47, DOI: https://doi.org/10.24887/0028-2448-2023-3-42-47

11. Persova M.G., Soloveychik Yu.G., Grif A.M., Flow balancing in modeling of multi-phase flow using non-conformal finite element meshes (In Russ.), Programmnaya inzheneriya, 2021, V. 12, no. 9, pp. 450–458, DOI: https://doi.org/10.17587/prin.12.450-458

12. Persova M.G., Soloveychik Yu.G., Patrushev I.I., Ovchinnikova A.S., Application of the finite element grouping procedure to improve the efficiency of unsteady multiphase flow simulation in high-heterogeneous 3D porous media (In Russ.), Vestnik Tomskogo gosudarstvennogo universiteta. Upravlenie, vychislitel’naya tekhnika i informatika, 2021, V. 57, pp. 34–44, DOI: https://doi.org/10.17223/19988605/57/4

13. Rivkin S.L., Aleksandrov A.A., Termodinamicheskie svoystva vody i vodyanogo para: spravochnik (Thermodynamic properties of water and water vapor), Moscow: Energoatomizdat Publ., 1984, 80 p.

The article discusses the geological and technological causes of premature flooding of oil wells in Iraq fields after hydraulic fracturing. Special attention is paid to the role of natural fracturing, tectonic disturbances and weak isolation of aquifers in the formation of water inflow. Modern approaches to reducing waterlogging are the following: the use of deflecting agents, microseismic monitoring, geomechanical modeling, multi-stage hydraulic fracturing and isolation of aquifers using heat-resistant and polymeric materials. The relevance of the integrated design of hydraulic fracturing operations, taking into account the geological features of Iraq, is presented. The article may be useful for engineering and technical specialists involved in optimizing production in fractured reservoirs. The study also addresses precise selection of perforation intervals, accounting for the proximity of the oil–water contact, and evaluation of sealing barriers between layers. Approaches to selecting fracturing fluids and proppants with isolating (water-blocking) properties are systematized. The expected effects of the integrated measures are reduced water cut and stabilized production rate. The proposed solutions can be applied to clastic and carbonate reservoirs and can serve as a basis for a hydraulic fracturing design workflow that accounts for regional specifics. In addition, the paper outlines pre-job diagnostic requirements, control during pumping, and post-job surveillance to detect early water breakthrough. It summarizes field experience from different Iraqi regions.

References

1. TotalEnergies. GGIP: A Multi-Energy Project to Support Iraq Towards Its Energy Independence, 2023, URL: https://totalenergies.com/company/projects/gas/ggip-multi-energy-project-Irak

2. Mavlyutov L.I., Vasil’ev V.I., Criteria for selecting a well for hydraulic fracturing (In Russ.), Molodoy uchenyy, 2022, no. 42(437), pp. 57–61.

3. IEA. Iraq Energy Outlook. International Energy Agency, 2022, URL: https://www.iea.org/reports/iraq-energy-outlook-2022

4. Nurmammadli F.A., Akhadov M.A., Review of oil and gas fields in the Near and Middle East (In Russ.), Molodoy uchenyy, 2017, no. 11(145), pp. 169–173.

5. Valeev A.S., Dulkarnaev M.R., Kotenev Yu.A. et al., Reasons of water volume increasing in wells after hydraulic gap in homogeneous plates (In Russ.), Izvestiya TPU, 2018, no. 6, pp. 140–147.

6. Kudrin G.M., Iraq’s oil and gas complex: State and development factors (In Russ.), Skif, 2020, no. 1(41), pp. 347–352.

7. Sysolyatin A.A., Technology of hydraulic fracturing (In Russ.), Simvol nauki, 2016, no. 7–1, pp. 14–16.

8. Vorob’ev E.S., Research and improvement of hydraulic fracturing technology for well completion in the Priobye fields (In Russ.), Molodoy uchenyy, 2020, no. 25(315), pp. 17–21.

The article presents the results of a work on organizing the production of a hydrocarbon base for drilling fluids (HBDF) based on highly refined petroleum products of primary and secondary oil refining at Angarsk Petrochemical Company, and the results of studying the possibility of increasing its production and expanding the company's product range. From 2018 to 2019 the specialists of Angarsk Petrochemical Company (subsidiary of Rosneft Oil Company) and RN-LUBRICANTS LLC carried out work for organizing the production of a HBDF, which included: searching for the most suitable materials in terms of quality and technologies of origin; obtaining and testing laboratory samples of the product; development of engineering models of product production in the AspenHYSYS environment; conducting pilot tests with obtaining pilot batches of the HBDF and their qualification and operational tests. This enabled in 2020 to start industrial production of HBDF at Angarsk Petrochemical Company to meet the domestic demand of oil production enterprises of Rosneft Oil Company in this product and reduce the share of using imported bases. A further stage in the development of the production of domestic HBDF at Angarsk Petrochemical Company was the study of the possibility of increasing the volume of its production, within which several directions were chosen. This is both the involvement of other highly purified components in the composition of the product, and the search for new material flows. These activities identified the potential ways to increase the annual production of HBDF and ways to expand the range of viscosity characteristics.

References

1. Ryazanov Ya.A., Entsiklopediya po burovym rastvoram (Encyclopedia of drilling fluids), Orenburg: Letopis’ Publ., 2005, 664 p.

2. Aksenova N.A., Rozhkova O.V., Burovye promyvochnye zhidkosti i promyvka skvazhin (Drilling fluids and well cleaning), Tyumen’: Publ. of Industrial University of Tyumen, 2016, 390 p.

3. Bulatov A.I., Makarenko P.P., Prostrelov Yu.M., Burovye promyvochnye i tamponazhnye rastvory (Drilling flushing and cementing solutions), Moscow: Nedra Publ., 1999, 424 p.

4. Ryabchenko V.I., Upravlenie svoystvami burovykh rastvorov (Managing the properties of drilling fluids), Moscow: Nedra Publ., 1990, 230 p.

5. Karpov N.V., Vakhromov N.N., Dutlov E.V. et al., Import substitution. Development and introduction of production technology of hydrocarbon bases for drilling muds in JSC “Slavneft-Janos” (In Russ.), Neftepererabotka i neftekhimiya, 2018, no. 11, pp. 3–6.

6. Dubrovskiy D.A., Kuzora I.E., Leymeter T.D. et al., Development of hydrocarbon basis production technology for drilling muds based on capacities of JSC “ANHK” (In Russ.), Neftepererabotka i neftekhimiya, 2019, no. 12, pp. 9–15.

7. Kuzora I.E., Dubrovskiy D.A., Stadnik A.V., Development of technology and organization of the production of a hydrocarbon base for drilling fluids as part of import substitution for oil production enterprises (In Russ.), Sovremennye tekhnologii i nauchno-tekhnicheskiy progress, 2020, no. 7, pp. 45–46,

DOI: https://doi.org/10.36629/2686-9896-2020-1-47-48

8. Patent RU 2762672 C1. Method for producing a hydrocarbon base of drilling fluids, Inventors: Zelenskiy K.V., Dubrovskiy D.A., Leymeter T.D., Kuzora I.E.,

Semenov I.A., Stadnik A.V., Marushchenko I.Yu., Sergeev V.A.

The aim of this work is to develop an oil-free method for controlled aging of carbonate core to achieve a target wettability. Aging cores without crude oil is important when the oil contains a significant fraction of asphaltene-resin-paraffin deposits, which creates a risk of core plugging during oil-based aging. It helps to reduce time and cost of the aging procedure and enables building a library of samples with uniform properties (for screening chemical formulations). The method was validated for conditions of a hydrophobic carbonate reservoir at the West-Khosedayusskoe oil field (contact angle θ ≈ 110–120°). The authors used 0,01 M monobasic carboxylic acids (C12–C18) in a low-molecular alcohol with 5–15 % water added. Both static (≈ 24 h, 25 °C) and dynamic aging were implemented. Rock  model Indiana Limestone core. Metrics: static contact angle θ and displacement efficiency for water  oil and water  crude oil tests. Adding water is critical for the rate and degree of hydrophobization; increasing alkyl chain length raises θ (C18 > C16 > C14 > C12); a parameter «window» was identified that yields the target θ ≈ 110–120°; the displacement efficiency with crude oil decreases to about 57% versus 67% without aging, which integrally reflects hydrophobization. A reproducible, scalable, and operationally convenient carbonate core-aging method was proposed that provides controlled wettability, enabling the creation of a representative sample library.

References

1. Kumar S., Burukhin A.A., Cheremisin A.N., Grishin P.A., Wettability of carbonate reservoirs: effects of fluid and aging, SPE-201834-MS, 2020,

DOI: https://doi.org/10.2118/201834-MS

2. Thomas M.M. еt al., Adsorption of organic compounds on carbonate minerals: 1. Model compounds and their influence on mineral wettability, Chemical Geology, 1993, V. 109, pp. 201–213, DOI: https://doi.org/10.1016/0009-2541(93)90070-Y

3. Hopkins P.A., Strand S., Puntervold T. et al., The adsorption of polar components onto carbonate surfaces and the effect on wetting, Journal of Petroleum Science and Engineering, 2016, V. 147, pp. 381–387, DOI: https://doi.org/10.1016/j.petrol.2016.08.028

4. Sachdeva J.S., Sripal E.A., Nermoen A. et al., A laboratory scale approach to wettability restoration in chalk core samples, E3S Web of Conferences, 2019, V. 89,

DOI: https://doi.org/10.1051/e3sconf/20198903003

5. Al-Mahrooqi S.H., Grattoni C.A., Muggeridge A.H., Jing X.D., Wettability alteration during aging: the application of Nmr to monitor fluid redistribution, Proceedings of Symposium of the Society of Core Analysts, Toronto, Canada, 2005, pp. 1–12, URL: https://jgmaas.com/SCA/2005/SCA2005-10.pdf

6. Fernø M.A., Torsvik M., Haugland S., Graue A., Dynamic laboratory wettability alteration, Energy & Fuels, 2010, V. 24(7), pp. 3950–3958,

DOI: https://doi.org/10.1021/ef1001716

7. Gomari S.R., Hamouda A.A., Effect of fatty acids, water composition and pH on the wettability alteration of calcite surface, Journal of Petroleum Science and Engineering, 2006, V. 50, pp. 140–150, DOI: https://doi.org/10.1016/j.petrol.2005.10.007

8. Cao Z., Daly M., Clémence L., Luke M. еt al., Chemical surface modification of calcium carbonate particles with stearic acid using different treating methods, Applied Surface Science, 2016, V. 378, pp. 320–329, DOI: https://doi.org/10.1016/j.apsusc.2016.03.205

9. Tokareva E.V., Tkachev I.V., Sansiev G.V. еt al., Study of the process of hydrophobization of carbonate rock with organic acids (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2021, no. 3, pp. 73–76, DOI: https://doi.org/10.24887/0028-2448-2022-3-73-76

10. Ivanova A., Cheremisin A.N., Khayrullin M., Sansiev G., Microstructural imaging and characterization of organic matter presented in carbonate oil reservoirs,

SPE-195466-MS, 2019, DOI: https://doi.org/10.2118/195456-ms

11. Mihajlović S., Sekulić Ž., Daković A. et al., Surface properties of natural calcite filler treated with stearic acid, Ceramics-Silikaty, 2009, V. 53, pp. 268–275,

URL: https://www.ceramics-silikaty.cz/2009/pdf/2009_04_268.pdf

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13. Karimi M., Al-Maamari R.S., Ayatollahi S., Mehranbod N., Mechanistic study of wettability alteration of oil-wet calcite: the effect of magnesium ions in the presence and absence of cationicsurfactant, Colloids and Surfaces A: Physicochem. Eng. Aspects, 2015, V. 482, pp. 403–415, DOI: https://doi.org/10.1016/j.colsurfa.2015.07.001

14. API Recommended Practice 40: Recommended Practices for Core Analysis. – 2nd ed., 1998. – https://energistics.org/sites/default/files/2022-10/rp40.pdf

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16. Vakhmistrov V.E., Lobova Yu.A., Petrakov A.M., Fomkin A.V., Densimetric method of oil measurement in flow experiment products (In Russ.), Neftyanoe khozyaystvo, 2023, no. 2, pp. 38–42, DOI: https://doi.org/10.24887/0028-2448-2023-2-38-41

This paper presents a methodological approach to studying and comparatively characteristics of chemical reagents used in flow-diverting technologies, illustrated by laboratory evaluation of various water shut-off compositions under conditions of two Western Siberian oil fields (OF-1 and OF-2). Twenty compositions from seven categories were evaluated: curing, gelling (polymer and inorganic), suspension systems, inverted emulsions, water-swelling and precipitation-gelling systems. The comprehensive methodology comprised six research stages: assessment of physical-chemical properties, gelation behavior, thermal stability, degradation resistance, rheological properties, and coreflood experiments on reservoir rock models. Given the diverse physical-chemical nature of the compositions, key selection criteria included: thermal stability (only 47 % of compositions remained stable for 30 days at OF-1 and 37 % at OF-2), gelation time of at least 3 hours to ensure safe injectivity (only four compositions met this criterion), and degradability (more than 90 % breakdown to minimize formation damage was achieved by seven compositions). Coreflood experiments enabled evaluation of selected compositions under near-reservoir conditions. Quantitative selectivity criteria were established based on the ratio of resistance factors measured in water- and oil-saturated core samples. The proposed approach enables systematic evaluation of water shut-off agent performance and identification of optimal compositions for specific geological and petrophysical field conditions.

References

1. Dolgikh Y.V., Nuriev D.V., Kinzibaev D.R. et al., Flow-diverting technologies for Western Siberian fields (In Russ.), Neftegaz.RU, 2025, no. 10, URL: https://magazine.neftegaz.ru/articles/nefteservis/903065-potokootklonyayushchiesya-tekhnologii-dlya-...

2. GOST 27025-86. Reagents. General test requirements.

At any stage of an oil or gas field's life cycle, subsoil users need to address a range of production challenges, such as designing and optimizing the gathering and production system, analyzing and optimizing the operating conditions of the existing system, identifying bottlenecks in the production system, as well as ensuring safe operation and maximum economic efficiency. To solve such tasks, specialized engineering software is used, which simulates the flow of multiphase fluid while calculating hydraulic losses, volumetric and mass flow rates of oil, gas, and water, velocities, and other phase properties under both linear and standard conditions. The software takes into account all physical characteristics of the pipeline system, as well as the downhole and surface equipment. The d-Flow simulator, developed by the authors of this paper, enables the calculation of multiphase flow characteristics in a complex production system and designs infrastructure facilities to meet specific operational requirements. This paper presents the simulation results of a section of a real oil field in the d-Flow hydraulic simulator compared with Schlumberger’s (France) PIPESIM software, which has been considered the industry standard for the past few decades. Deviations in key parameters do not exceed 5%, even under conditions of high water cut and a sharp increase in the gas-oil ratio. This enables the d-Flow simulator to be used for solving oil industry problems.

References

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

3. Al-Marhoun M., PVT correlations for middle east crude oils, Journal of Petroleum Technology, 1988, V. 40, pp. 650–666, DOI: https://doi.org/10.2118/13718-PA

4. Ghetto G.D., Paone F., Villa M., Pressure-volume-temperature correlations for heavy and extra heavy oils, SPE-30316-MS, 1995,

DOI: https://doi.org/10.2118/30316-MS

5. Glaso O., Generalized pressure-volume-temperature correlations, J Pet Technol., 1980, V. 32(05), pp. 785–795, DOI: https://doi.org/10.2118/8016-PA

6. Petrosky J.G.E., Farshad F.F., Pressure-volume-temperature correlations for Gulf of Mexico crude oils, SPE-26644-MS, 1993, DOI: https://doi.org/10.2118/26644-MS

7. Standing M.B., Katz D.L., Density of natural gases, Trans. AIME, 1942, V. 146, pp. 140–149, DOI: https://doi.org/10.2118/942140-G

8. Vasquez M., Beggs H., Correlations for fluid physical property prediction, J Pet Technol., 1980, V. 32(06), pp. 968–970, DOI: https://doi.org/10.2118/6719-PA

9. El-Banbi A.H., Fattah K.A., Sayyouh M.H., New modified black-oil correlations for gas condensate and volatile oil fluids, SPE-102240-MS, 2006,

DOI: https://doi.org/10.2118/102240-MS

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This article reviews the application of flexible reinforced thermoplastic pipes in oil field gathering systems, from the first attempts to use such pipes to the present day. The following article provides results of an economic analysis which compared flexible reinforced thermoplastic pipes and steel pipes on the example of a specific project. It is demonstrated, that the use of flexible reinforced thermoplastic pipes can be feasible under certain conditions. When making a decision, the technical parameters and the cost of pipe should be considered as well as the installation method (underground/above ground/on ground filled with earth), the costs for insulation and heating (if there are any), the installation costs and other factors affecting capital expenditures. Furthermore, operational expenditures may also differ due to different approaches to diagnostics of flexible reinforced thermoplastic pipes and steel pipelines, different frequency and cost of repair works, and other factors related to differences between flexible reinforced thermoplastic pipes and steel pipes, which should also be taken into account for a high-quality economic comparison. Based on past experience, economic analysis, and current industry trends, the prospects for the use of flexible reinforced thermoplastic pipes in oil field gathering systems in the foreseeable future are outlined in the article.

References

1. Kovyrshin R.V., Gibkie polimerno-armirovannye truby v sisteme sbora neftyanykh mestorozhdeniy: analiz problem i puti ikh resheniya (Flexible polymer-reinforced pipes in oil field gathering systems: analysis of problems and solutions), Collected papers “Aktual’nye voprosy nauki, obshchestva i obrazovaniya” (Current issues in science, society and education), Proceedings of V International scientific and practical conference, Penza, 25 May 2025, Penza: Nauka i Prosveshchenie Publ., 2025, pp. 19–22.

2. Kovyrshin R.V., Gibkie polimerno-armirovannye truby v sisteme sbora nefti: snizhenie CAPEX i OPEX cherez innovatsionnyy sposob protivokorrozionoy zashchity (Flexible polymer-reinforced pipes in oil gathering systems: reducing CAPEX and OPEX through an innovative method of anti-corrosion protection), Collected papers “Molodezh’ i nauka XXI veka: aktual’nye teoreticheskie issledovaniya” (Youth and Science in the 21st Century: Current Theoretical Research), Proceedings of III International scientific and practical conference, Penza, 25 May 2025, Penza: Nauka i Prosveshchenie Publ., 2025, pp. 36–40.

The article describes software developed at Rosneft Oil Company, which controls a complex of robotic tape libraries, that form part of the Seismic Data Storage Center's hardware and software, and the seismic data stored therein. The software operates within KBD Geobank-Seismorazvedka information system, which is designed to automate the Seismic Data Storage Center's operations and provide authorized access to seismic data for the specialists of Rosneft Oil Company. The software's structure, functionality, and purpose are described. The following software components are highlighted: file control, storage media control, storage system statistical data generation, and data integrity maintenance. In addition, the article provides a brief description of the structure and hardware of the KBD Geobank-Seismorazvedka information system. Particular attention is given to the storage architecture of information system, specifically a multi-tiered large-scale data storage system. The use of the developed tools enabled to optimize the work of information system administrators, to eliminate the need for a console on the application server for interactions with the system's technical devices and eliminating direct access to databases via query language. Future development of the information system includes plans to expand the use of the robotic tape library system to other types of information, develop automation tools, and enhance data integrity monitoring.

In modern practice of designing and operating industrial facilities, especially in the complex engineering and geological conditions of the Arctic and areas of permafrost soils, geotechnical monitoring has transformed from an auxiliary procedure into a key element of the safety system. The article presents detailed methodological recommendations, developed by specialists of Rosneft Oil Company, for substantiating the necessity and duration of geotechnical monitoring for buildings and structures operating in complex engineering-geological conditions, including permafrost regions. The methodology's core is a risk-based approach that integrates the assessment of two key criteria: the complexity category of engineering-geological conditions (determined by factors such as geological processes, permafrost properties, technogenic impacts, geomorphology, geological structure, and hydrogeological conditions) and the severity of potential consequences of facility failure or accident (classified from critical to extremely low). A priority matrix is proposed for practical application, which differentially determines not only the necessity of geotechnical monitoring but also its priority level (high, medium, low) and required scope based on the combination of these criteria. The methodology also establishes clear rules for determining monitoring duration: continuous throughout the entire lifecycle for high-priority facilities; until parameter stabilization (not less than 2 years) for medium priority; primarily visual control for low priority. A significant aspect of the work is the consideration of practical aspects of the methodology's implementation, including an algorithm for its application, from initial data collection to the development and execution of a monitoring program. Special attention is paid to the economic efficiency of this approach, which optimizes resource allocation towards the highest-risk facilities, thereby preventing significant financial losses and environmental damage.

References

1. Tretiy otsenochnyy doklad ob izmeneniyakh klimata i ikh posledstviyakh na territorii Rossiyskoy Federatsii. Obshchee rezyume (The third assessment report on climate change and its impacts in the Russian Federation. General summary), St. Petersburg: Naukoemkie tekhnologii Publ., 2022, 124 p., URL: https://www.meteorf.gov.ru/upload/pdf_download/compressed.pdf

2. Mel’nikov V.P., Osipov V.I., Brushkov A.V. et al., Development of geocryological monitoring of natural and technical facilities in the regions of the Russian Federation based on geotechnical monitoring systems of fuel and energy sector (In Russ.), Kriosfera Zemli, 2022, V. XXVI, no. 4, pp. 3–18,

DOI: https://doi.org/10.15372/KZ20220401, EDN: TMLZFZ

3. Russian Federal Law No. 384-FZ “Technical regulations on the safety of buildings and facilities” of December 30th, 2009.

4. SP 22.13330.2016. Osnovaniya zdaniy i sooruzheniy (Foundations of buildings and structures).

5. SP 25.13330.2020. Osnovaniya i fundamenty na vechnomerzlykh gruntakh (Foundations and foundations on permafrost soils).

6. SP 305.1325800.2017. Zdaniya i sooruzheniya. Pravila provedeniya geotekhnicheskogo monitoringa pri stroitel’stve (Buildings and Structures. Rules for Geotechnical Monitoring during Construction).

7. SP 497.1325800.2020. Osnovaniya i fundamenty zdaniy i sooruzheniy na mnogoletnemerzlykh gruntakh. Pravila ekspluatatsii (Foundations and foundations of buildings and structures on permafrost soils. Operating rules).

8. Zarya L.V., Pavlov V.A., Kanaev R.Yu. et al., Development of geotechnical monitoring of oil and gas fields construction facilities in the permafrost zone of Russia

(In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2022, no. 11, pp. 59–63, DOI: https://doi.org/10.24887/0028-2448-2022-11-59-63

9. SP 47.13330.2016. Inzhenernye izyskaniya dlya stroitel’stva. Osnovnye polozheniya (Engineering surveys for construction. Basic provisions).

10. GOST 25358-2020. Soils. Field method of determining the temperature.