The article considers the prediction of permeability of terrigenous-carbonate rocks based on well logging data. According to the lithological description of the core and the filtration and capacitive properties, the rocks are divided into lithological types (lithotypes). These lithotypes are divided into reservoirs and low permeability non-reservoirs. Non-reservoirs are represented by rocks with a high content of clay and anhydrite material, microcrystalline and micro-fractured dolomites. The reservoirs are represented by sandstones, aleurolites and dolomites. The permeability of terrigenous rocks, with the same values of porosity, decreases with a decrease of grain size and an increase of the content of minerals with high dispersion, sorption and ion exchange. Permeability of carbonate rocks depends on the structure of their void space. According to specific electrical resistance and nuclear-magnetic resonance studies of core samples, it was found that the presence of large cavities reduces the hydrodynamic connectivity of voids and the permeability of rocks. The considered features were taken into account when predicting permeability based on well logging data through a synthetic parameter – flow zone indicator (FZI). To determinate this parameter, a three-dimensional relationship is proposed that connects the FZI from core with geophysical parameters. The results of FZI calculation are consistent with core determinations. Calculating the permeability coefficient using the FZI more accurately reproduces core measurement than calculating using the standard dependence on the porosity coefficient. During well testing, the largest inflows of formation fluids were obtained from the most permeable intervals identified by this method.

References

1. Sergeev E.M., Golodkovskaya G.A., Ziangirov R.S. et al., Gruntovedenie (Soil science): edited by Sergeev E.M., Moscow: Publ. of MSU, 1983, 392 p.

2. Lucia F.J., Carbonate reservoir characterization: An integrated approach, Springer, Berlin Heidelberg New York, 2007, 333 p.

3. Metodicheskoe rukovodstvo po vydeleniyu i otsenke karbonatnykh kollektorov slozhnogo tipa po dannym promyslovoy geofiziki (Methodological guidelines for the identification and evaluation of complex carbonate reservoirs using field geophysics data): edited by Nechay A.M., Shnurman G.A., Boyarchuk A.F. – Groznyy: Publ. od KOVNIIneftepromgeofiziki, 1973, 154 p.

4. Metodicheskie rekomendatsii po podschetu zapasov nefti i gaza ob’emnym metodom. Otsenka kharaktera nasyshchennosti po dannym GIS (Guidelines for the calculation of reserves of oil and gas by volumetric method. Assessment of the nature of saturation according to well logging): edited by Petersil’e V.I., Poroskun V.I.,

Yatsenko G.G., Moscow – Tver: Publ. of VNIGNI, 2003, 262 p.

5. Rezvanov R.A., Smirnov O.A., Reservoirs typification as a means of improving the permeability determining accuracy (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2013, no. 2, pp. 42-49.

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

7. Shilov G.Ya., Main problems and possibilities of carbonate rocks facies using logging data (In Russ.),Trudy RGU nefti i gaza imeni I.M. Gubkina, 2010, no. 4(261),

pp. 7-16.

This article examines the historical aspects of the creation of positive displacement motors (PDM) in Russia for drilling oil and gas wells. The significant contribution of the PDM engineers to the development of domestic and world science and technology of well construction in the field of mechanical engineering of hydraulic downhole equipment is noted. A technical and technological assessment of existing PDM for various purposes is given; their classification, comparison and design are indicated. The analysis of the developed of the PDM for drilling directional and horizontal wells with a large deviation from the vertical, side shafts is given. Innovative technologies for the use of PDM at the facilities of Rosneft Oil Company, such as: «R-Force», MVO-176T, «Fluid Hammer», «Vortex» are being considered. The article provides a practical example of the use of PDM in the construction of a horizontal well with a discharge of up to 2000 m and a high drilling difficulty index (DDI) without using expensive imported rotary steerable system (RSS) technologies at the bush site of the Severo-Komsomolskoye field. The authors of the article note that the potential of using PDM has not yet been fully exhausted and work on improving this technology continues by leading scientific, production and oil and gas producing organizations. Russian developments in the field of hydraulic engineering provide the oil and gas industry with high-tech equipment for the efficient construction and repair of wells for various purposes.

References

1. Author’s certificate of the USSR no. 237596, Zaboynyy vintovoy gidravlicheskiy dvigatel’ (Downhole screw hydraulic motor), authors: M.T. Gusman, S.S. Nikomarov, N.D. Derkach, Yu.V. Zakharov, V.N. Men’shenin, zayavl.07.06.1966; opubl. 12.02.1969.

2. OST 39-164-84. Peredacha zubchataya rotor – stator vintovogo zaboynogo dvigatelya. Iskhodnyy kontur. Raschet geometrii (Rotor-stator gear transmission of a downhole motor. Initial contour. Geometry calculation).

3. Baldenko D.F., Baldenko F.D., Selivanov S.M., Teoriya i praktika primeneniya vintovykh zaboynykh dvigateley (Theory and practice of using screw downhole motors), Moscow: TsentLitNefteGaz Publ., 2020, 456 p.

4. Gusman M.T., Baldenko D.F., Vintovye zaboynye dvigateli (Screw downhole motors), Moscow: Publ. of VNIIOENG, 1972, 83 p.

5. Analiz rynka vintovykh zaboynykh dvigateley v Rossii. Pokazateli i prognozy (Analysis of the downhole motor market in Russia. Indicators and forecasts), Tebiz Group, 2023, URL: https://tebiz.ru/

6. Gusman M.T., Baldenko D.F., Kochnev A.M., Nikomarov S.S., Zaboynye vintovye dvigateli dlya bureniya skvazhin (Downhole screw motors for well drilling), Moscow: Nedra Publ., 1981, 232 p.

7. Baldenko D.F., Baldenko F.D., Russian positive displacement motors: Yesterday, today, tomorrow (In Russ.), Burenie i neft’, 2024, no. 1, pp. 46-53.

8. Lyagov I.A., Baldenko F.D., Lyagov A.V. et al., Methodology for calculating technical efficiency of power sections in small-sized screw downhole motors for the “Perfobur” system (In Russ.), Zapiski Gornogo instituta = Journal of Mining Institute, 2019, V. 240, pp. 694-700, DOI: https://doi.org/10.31897/pmi.2019.6.694, 2019, V. 240,

9. Utility patent RU170535U1, Bashmak s silovym privodom (Power drive shoe), Inventor: Selivanov S.M.

10. Patent RU227026U1, Non-retrievable downhole assembly for drilling, completing and operating oil and gas wells, Inventors: Baldenko D.F., Baldenko F.D., Ponomarenko M.N., Chaykovskiy G.P.

11. Korotaev Yu.A., Tekhnologicheskoe obespechenie dolgovechnosti mnogozakhodnykh vintovykh gerotornykh mekhanizmov gidravlicheskikh zaboynykh dvigateley (Technological support for the durability of multi-start screw gerotor mechanisms of hydraulic downhole motors), Moscow: Publ. of VNIIOENG, 2003, 259 p.

12. Chaykovskiy G.P., Popko V.V., Baldenko D.F., Sergeev I.S., New designs of downhole hydraulic motors and import-substituting hydromechanical BHA devices

(In Russ.), Proektirovanie i razrabotka neftegazovykh mestorozhdeniy, 2017, no. 1, pp. 20-23.

13. Umarov D.S., Farrakhov L.A., Baletinskikh D.I., Kavtas’kin A.N., Experience of using a downhole drilling motor with an innovative profile of working bodies manufactured by JSC Permneftemashremont at the facilities of PJSC Orenburgneft (In Russ.), Inzhenernaya praktika, 2017, no. 8, pp. 13-16.

14. Morozov V.A., Dvoynikov M.V., Rational choice of parameters of directional wells drilling mode when using screw downhole motor (In Russ.), Stroitel’stvo neftyanykh i gazovykh skvazhin na sushe i na more, 2019, no. 2, pp. 15-18, DOI: https://doi.org/10.30713/0130-3872-2019-2-15-18

15. Krutik E.N., Borisov M.S., Fufachev O.I. et al., Experience in using oscillators for drilling boreholes (In Russ.), Burenie i neft’, 2019, no. 5, 38-41.

16. Budyanskiy V.S., Vlasov A.V., Krekin M.V., Mutovkin N.F., Development of the technology of directional and horizontal drilling based on direct components arrangement (In Russ.), Stroitel’stvo neftyanykh i gazovykh skvazhin na sushe i na more, 2019, no. 6, pp. 5-8, DOI: https://doi.org/10.30713/0130-3872-2019-6-5-8

17. Nigmatov L.G., Trubnikov V.V., Experience of controlling a drill string assembly hanging in a sliding mode at the Samara region fields when drilling directional wells

(In Russ.), Stroitel’stvo neftyanykh i gazovykh skvazhin na sushe i na more, 2021, no. 2, pp. 5-10, DOI: https://doi.org/10.33285/0130-3872-2021-2(338)-5-10

18. Tur D.Yu., Oveshnikov E.A., Khayvapin E.Sh., Ryabov A.V., Optimization of horizontal well drilling technologies at the Tazovskoye field: Experiences and achievements (In Russ.), Burenie i neft’, 2024, no. 12, pp. 52-61, DOI: https://doi.org/10.62994/2072-4799.2024.96.36.008

19. Bragin D.I., Kuznetsov A.V., Trofimova M.N., Sizov M.S., R-Force, are the engines for a maximum drilling modes (In Russ.), Burenie i neft’, 2017, no. 6, pp. 56-58.

20. Biktimirkin E.Yu., Dem’yanov E.A., Mozgovoy G.S., Use of screw downhole motors with hydro-impulsive section (In Russ.), Stroitel’stvo neftyanykh i gazovykh skvazhin na sushe i na more, 2021, no. 11, pp. 44-47, DOI: https://doi.org/10.33285/0130-3872-2021-11(347)-44-47

The global offshore drilling contracting market experienced a severe crisis in 2014-2021. Significant changes happened both in the structure of the global fleet of mobile offshore drilling units (MODUs) and in the operating companies working on this market. A number of companies became bankrupt; some underwent serious restructuring with the sale of their drilling capacities. Some companies, on the contrary, in the conditions of the "storm" increased their production capabilities by actively buying up MODUs put up for sale. However, improvements have been noted for the offshore drilling operators in the latest time. Daily rates for drilling rigs are rising, rig utilization is increasing, and oil and gas companies are ramping up their production plans. In this article, the authors tried to briefly but widely describe the current situation, show existing opinions of drilling contractors, their vision of prospects and expectations. There is an attempt to make possible short-term forecasts and prospects, including for the Southeast Asia region. The information shown in the article is based exclusively on open sources and does not claim to be absolutely reliable. It has been provided only for the purposes of possible discussion. There is only one indisputable fact in the article, based on the tenders held by the Zarubezhneft Group of Companies - daily rental rates for MODUs have increased significantly compared to the previous 3-5 year period, and this is certainly a positive trend for drilling operators and negative for oil and gas companies working on the shelf.

References

1. URL: https://www.westwoodenergy.com/riglogix

2. URL: https://investor.deepwater.com/presentations

3. URL: https://www.borrdrilling.com/reports-and-presentations

4. URL: https://investors.adesgroup.com/reports-and-presentations

5. URL: https://www.valaris.com/investors/events-and-presentations/default.aspx

6. URL: https://noblecorp.com/investors/events-and-presentations/default.aspx

7. URL: https://noblecorp.com/investors/events-and-presentations/default.aspx

8. URL: https://www.shelfdrilling.com/investor-relations/

9. URL: https://adnocdrilling.ae/en/investor-relations/reports-presentations-and-announcements/results-and-presentation

The article discusses the results of drilling new wells, taking into account the features of the geological structure of the Moscovian stage of the Arlanskoye field. The analysis of the drilled wells was carried out taking into account the additional study of the geological structure of the carbonate formations of the Kashiro-Podolsk deposits in order to search and substantiate the criteria for predicting the productive intervals of the target carbonate reservoir. In order to improve the efficiency of development of the target in conditions of its active drilling, a detailed geological model was built to select the optimal zones and intervals for drilling horizontal boreholes for the planned drilling targets. The geological and operational criteria for the success of drilling new wells and sidetracks were determined, and zones of localization of residual recoverable reserves were categorized according to prospects. A matrix was formed that combines geological and operational aspects that determine the success of drilling. On its basis, parameters were refined to assess the effectiveness of drilling wells with horizontal completion in the Moscovian stage. A better understanding of the geological structure of the Kashiro-Podolsk formation and the success criteria formed as a result of the analysis of drilling new wells will improve the efficiency of development drilling and sidetracking.

References

1. Lozin E.V., Razrabotka unikal’nogo Arlanskogo neftyanogo mestorozhdeniya vostoka Russkoy plity (Developing a unique Arlan oil field of the East of the Russian Plate), Ufa: Publ. of BashNIPIneft, 2012, 704 p.

2. Baymukhametov K.S., Enikeev V.R., Syrtlanov A.Sh., Yakupov F.M., Geologicheskoe stroenie i razrabotka Arlanskogo neftyanogo mestorozhdeniya (Geological structure and development of the Arlanskoye oilfield), Ufa: Publ. of Bashneft’, 1997, 368 p.

3. Shuvalov A.V., Lozin E.V., Half a century of Arlanskoye oil field development: progress and problems (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2009, no. 9, pp. 94-97.

4. Gareev A.T., Nurov S.R., Faizov I.A. et al., Production features and concept of further development of the unique Arlanskoye field (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2023, no. 4, pp. 40–45,

DOI: http://doi.org/10.24887/0028-2448-2023-4-40-45

5. Privalova O.R., Gadeleva D.D., Minigalieva G.I. et al., Well logging interpretation for Kashir and Podolsk deposits using neural networks (In Russ.), Neftegazovoe delo, 2021, no. 1, pp. 69-76, DOI: https://doi.org/10.17122/ngdelo-2021-1-69-76

6. Privalova O.R., Ganeeva A.I., Leont’evskiy A.V., Minigalieva G.I., Typification of carbonate rocks of the Middle Carbon by the structure of the void space to solve problems of oil fields development control (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2023, no. 8, pp. 30–35,

DOI: https://doi.org/10.24887/0028-2448-2023-8-30-35

7. Gareev A.T., Nurov S.R., Vagizov A.M., Sibaev T.V., Complex approaches to improving development system of unique Arlanskoye oilfield (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2018, no. 12, pp. 112–116,

DOI: https://doi.org/10.24887/0028-2448-2018-12-112-116

8. Erokhin G.S., Nurov S.R., Vagizov A.M. et al., Efficiency of reservoir pressure maintenance system and ways to improve it on carbonate sediments of the Arlanskoye oil field (In Russ.), Ekspozitsiya Neft’ Gaz, 2023, no. 7, pp. 44–48,

DOI: https://doi.org/10.24412/2076-6785-2023-7-44-48

9. Shaydullin V.A., Medvedev D.A., Vagizov A.M. et al., Experience of water inflow limitation after multi-stage hydraulic fracturing of the carbonate deposits at the Arlanskoye field (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2024,

no. 10, pp. 78–82, DOI: https://doi.org/10.24887/0028-2448-2024-10-78-82

10. Vagizov A.M., Bashirov I.R., Suleymanov Al.A. et al., Creation of integral map of drilling feasibility and risk assessment on Arlanskoye field (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2022, no. 7, pp. 82–86,

DOI: https://doi.org/10.24887/0028-2448-2022-7-82-86

11. Pozhitkov N.D., Stupak I.A., Denisov V.V. et al., Approaches to modeling the Kashiro-Podolsk deposits of the Arlanskoe field in the Republic of Bashkortostan (In Russ.), Neftegazovoe delo, 2022, V. 20, no. 5, pp. 45–54,

DOI: https://doi.org/10.17122/ngdelo-2022-5-45-54

12. Leont’evskiy A.V., Gareev A.T., Minigalieva G.I. et al., Features of the geological structure of the Kashir and Podolsk deposits of the unique Arlan field

(In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2024, no. 9, pp. 50–55,

DOI: https://doi.org/10.24887/0028-2448-2024-9-50-55

The article considers geological information obtained during the study of cuttings and cavings which is becoming increasingly important. Together with the mudlogging data the well bottom hole is tied to reference and seismic horizons, a sludge diagram and a lithological section of the well are constructed, the porosity and saturation of promising formations are determined. Field petrophysical study of clay cuttings enable to estimate the compaction gradient of clay rocks with depth and calculate abnormally high formation pressures. The use of X-ray fluorescence and X-ray diffraction methods makes it possible to determine the chemical and mineral composition of rocks directly at the fieldwork. Attempts are being made to automate cuttings flowmeter and automated research (RoboLogger), cavings analysis. Studying the size of cuttings and cavings during drilling wells, especially with high deviation angles and at horizontal completion, when passing boreholes in such geological conditions as zones of abnormally high formation pressures and tectonic faults, as well as when using various drilling mud systems, can greatly help in identifying the condition of the well. Together with the mudlogging data and geophysical analysis, it is possible to quickly detect the initial stages of well bore instability and collapse, and take targeted preventive measures for borehole stability.

References

1. Luk»yanov E.E., Operativnaya otsenka anomal’no vysokikh plastovykh davleniy v protsesse bureniya (Rapid assessment of abnormally high formation pressures during drilling), Novosibirsk: Istoricheskoe nasledie Sibiri Publ., 2012, 424 p.

2. Valitov D.B., Mel’nikov A.A., X-ray diffraction and X-ray fluorescence methods in geologic and technological surveys (mud logging) (In Russ.), Karotazhnik, 2022,

no. 4(318), pp. 25–36.

3. Neskoromnykh V.V., Razrushenie gornykh porod pri provedenii geologorazvedochnykh rabot (Destruction of rocks during geological exploration), Krasnoyarsk: Publ. of SFU, 2015, 396 p.

4. Austin J.A., Cannon S.J., Ellis D., Hydrocarbon exploration and exploitation West of Shetlands, Geological Society Special Publication, 2014, V. 397, pp. 1–10

5. Reyes R., Kyzym I., Rana P.S., Molgaard J. et al., Cuttings analysis for rotary drilling penetration mechanisms and performance evaluation, Proceedings of 49th

US Rock Mechanics / Geomechanics Symposium, 2015.

6. Skea C., Rezagholilou A., Behnoudfar P. et al., An approach for wellbore failure analysis using rock cavings and image processing, Journal of Rock Mechanics and Geotechnical Engineering, 2018, V. 10(5), pp. 865–878, DOI: http://doi.org/10.1016/j.jrmge.2018.04.011

7. RD 39-0147716-102-87. Geologo-tekhnologicheskie issledovaniya v protsesse bureniya (Geological and technological research during drilling), Moscow: Publ. of Minnefteprom, 1987.

8. Kocharyan G.G., Geomekhanika razlomov (Geomechanics of faults), Moscow: GEOS Publ., 2016, 424 p.

9. Sustavov V.S., Gundorin D.Yu., Zheleznikov A.V., Borehole instability while drilling through faults at the fields of Vietsovpetro JV (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2024, no. 7, pp. 79–82, DOI: http://doi.org/10.24887/0028-2448-2024-7-79-82

The article discusses methods for modeling the stress-strain state of rocks to address the problem of wellbore instability during drilling. Special attention is given to triaxial independent loading of rocks using a laboratory setup, as well as the modeling of uniaxial and triaxial compression using the ANSYS Workbench software. These methods enable to precisely analyze rock behavior under load, simulating real drilling conditions. Experiments showed that in areas with dolomite inclusions in argillite, stress levels significantly increase, which can lead to the formation of fractures, drilling fluid loss and rock collapse in inclined wellbores. The application of these methods helps identify and predict potential complications during the design phase, enhancing wellbore stability and reducing the risk of failures. As a result of the modeling, an integrated solution was developed, providing recommendations for selecting drilling fluid components based on the analysis of the physical and mechanical properties of rocks, such as Poisson’s ratio and Young’s modulus. This comprehensive approach significantly improves the efficiency and safety of drilling operations, particularly in wells with complex trajectories or deep formations, where preventing complications during the design phase proves to be more cost-effective than addressing them during the construction process. This technical approach contributes to optimizing wellbore design and mitigating risks, ensuring more reliable and economically feasible drilling projects.

References

1. Lapinskaya T.A., Proshlyakov B.K., Osnovy petrografii (Fundamentals of petrography), Moscow: Nedra Publ., 1981, 232 p.

2. Cook D., Frederiksen R., Hasbo K., On the importance of rock mechanical properties: a laboratory verification of geomechanical data (In Russ.), Oil Gas Rev., 2007, Autumn, pp. 44–69.

3. Parfenov K.V., Nechaeva O.A., Parfenova S.N., Triaxial compression study of clay samples (In Russ.), Neftegazovoe delo, 2023, V. 21, no. 6, pp. 96–102,

DOI: https://doi.org/10.17122/ngdelo-2023-6-96-102

4. Bukin P.N., Kazzyan M.G., Parfenov K.V., Kargin B.V., Stages of development of installations used for rocks triaxial compression testing (In Russ.), Stroitel’stvo neftyanykh i gazovykh skvazhin na sushe i na more, 2022, no. 11(359), pp. 28–32, DOI: https://doi.org/10.33285/0130-3872-2022-11(359)-28-32

5. Pod»yachev A.A., Bukin P.N., Parfenov K.V., Physical modeling of rock strain (In Russ.), Stroitel’stvo neftyanykh i gazovykh skvazhin na sushe i na more, 2021,

no. 1 (337), pp. 5–9, DOI: https://doi.org/10.33285/0130-3872-2021-1(337)-5-9

6. Khryanina O.V., Eksperimental’no-teoreticheskaya otsenka sovmestnoy raboty konstruktsii gibkogo fundamenta s armirovannym osnovaniem (Experimental and theoretical assessment of the joint work of a flexible foundation structure with a reinforced base): thesis of candidate of technical science, Penza, 2005.

7. Kovalenko Yu.F., Geomekhanika neftyanykh i gazovykh skvazhin (Geomechanics of oil and gas wells): thesis of doctor of technical science, Moscow, 2012.

The paper describes the results of pilot field tests in the conditions of AV1(1-2) formation of the Samotlor field testing an enhanced oil recovery (EOR) technology (SPA-Well technology) with the use of the domestic polymer gel AC-CSE-1313. This formation has a «Ryabchik» structure; it also has a complex geological structure, high compartmentalization and layered heterogeneity, as well as high current water cuts of wells. The paper highlights key points of the new SPA-Well treatment technology. The polymer-gel used in this technology was developed as a part of an import substitution to replace the expensive imported polymers which are widely used in the physical-chemical EOR. The pilot treatment results are presented and are the following: the water cuts of production wells actually decreased down by 1,1 to 4,9 %, the effect time for individual wells is from 2 to 18 months, incremental oil production due to increased oil recovery amounted to 985 t/well job. The technology which was tested in complex geological structures of the pilot area proved to be cost-effective. The actual incremental oil production exceeded the expected volume by more than 2,5 times. The technology can be recommended for replication and further implementation in the studied reservoir and in similar ones.

References

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

2. Emel’yanov E.V., Zemtsov Yu.V., Dubrovin A.V., Experience of flow-diverting technologies application under conditions of sharp heterogeneity of productive horizons of Ust-Tegussky field (In Russ.), Neftepromyslovoe delo, 2019, no. 11, pp. 76–82, DOI: https://doi.org/10.30713/0207-2351-2019-11(611)-76-82

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

4. Emel’yanov E.V., Zemtsov Yu.V., Integrated approach to designing physical and chemical EOR methods at «RN-Uvatneftegas» LLC (In Russ.), Neft’ Gaz Novatsii, 2021, no. 7, pp. 42–47.

5. Tagirov K.D., Morozovskiy N.A., EOR technologies in ESG strategy. Real prospects (In Russ.), Neft’ Gaz Novatsii, 2022, no. 8, pp. 73–76.

6. Fakhretdinov R.N., Fatkullin A.A., Selimov D.F. et al., Laboratory and field tests of AC-CSE-1313-A reagent as the basis of water control technologies (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2020, no. 6, pp. 68–71, DOI: https://doi.org/10.24887/0028-2448-2020-6-68-71

7. Fakhretdinov R.N., Pavlishin R.L., Yakimenko G.Kh. et al., Successful practical experience and application potential of AC-CSE-1313 flow-diverting procedure with various options in working solution volume at the fields with late stage of their development (In Russ.), Neft’. Gaz. Novatsii, 2020, no. 2, pp. 39-45.

8. Fatkullin A.A., The results of the field application of the EOR technology based on the reagent AC-SE-1313 mark B (hydrophobic polymer gel SPA-Well) (In Russ.), URL: https://burneft.ru/archive/issues/2023-01sp/18

9. SPA-Well – al’ternativa PAA v tekhnologiyakh povysheniya nefteotdachi plastov (SPA-Well – an alternative to PAA in enhanced oil recovery technologies),

URL: http:/www.cse-inc.ru/technologies/vpp/spa-well-pnp

10. Fakhretdinov R.N., Fatkullin A.A., Yakimenko G.Kh. et al., Increase in oil production by application pseudoplastic hydrophobic polymer system SPA-Well (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2021, no. 11, pp. 120–123, DOI: https://doi.org/10.24887/0028-2448-2021-11-120-123

11. Zemtsov Yu.V., Emel’yanov E.V., Mazaev V.V., Chusovitin A.A., Engineering designing of small volume chemical EOR methods in view of geological and field conditions of the reservoir (In Russ.), Neft’ Gaz Novatsii, 2019, no. 7, pp. 38–43.

The current state of oil reserves development is associated with problems of low oil recovery factor and high water cut. When searching for solutions to increase oil recovery, it is necessary to consider a whole range of factors affecting the displacement characteristics. Taking into account these factors involves working with large sets of reservoir data. The success of decisions made in selecting the management scenario for the development of the studied field is directly dependent not only on the quality of the available reservoir data but also on the computational tools used to guide these decisions during specific hydrodynamic stimulation operations. Therefore, critical importance is placed on enhancing the performance of software products used for reservoir forecasting and improving input data quality by identifying and removing «bad» data. Concurrent fulfilment of these conditions significantly boosts the effectiveness of decision-making during the forecasting phase. This paper outlines the technology for optimizing management decisions for field development based on the TEICS ONE suite. The core architecture of the computational suite is described, along with the sequential stages of the technology. The application results at the field, operated by Belkamneft JSC demonstrate the potential to maximize the recovery of reserves in late-stage fields and achieve the target oil recovery factor by effectively utilizing historical development data and making rational decisions for field management.

References

1. Gladkov E.A., Geologicheskoe i gidrodinamicheskoe modelirovanie mestorozhdeniy nefti i gaza (Geological and hydrodynamic modeling of oil and gas fields), Tomsk: Publ. of TPU, 2012, 99 p.

2. Volodin E.M., Zakharova A.A., The use of supercomputers for acceleration filtration process based on 3D geological and hydrodynamic models of oil and gas fields

(In Russ.), Doklady TUSUR, 2010, no. 2-2(22), pp. 241–244.

3. Dieva N.N., Aminev D.A., Kravchenko M.N. et al., Overview of the application of physically informed neural networks to the problems of nonlinear fluid flow in porous media, Computation, 2024, V. 12(4), no. 69, DOI: http://doi.org/10.3390/computation12040069

4. Vol’pin S.G. et al., Verifikatsiya gidrodinamicheskikh modeley po dannym promyslovykh issledovaniy skvazhin dlya poiska tselikov nefti (Verification of hydrodynamic models based on field well survey data for oil exploration), Moscow: Publ. of Scientific Research Institute of System Analysis, 2020, 132 p.

5. Muslimov R.Kh., History and prospects of hydrodynamic methods for oil fields development in Russia (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2020, no. 12, pp. 96–100, DOI: http://doi.org/10.24887/0028-2448-2020-12-96-100

6. Hui Zhao, Lingfei Xu, Zhenyu Guo et al., Flow-path tracking strategy in a data-driven interwell numerical simulation model for waterflooding history matching and performance prediction with infill wells, SPE-199361-PA, 2019, DOI: http://doi.org/10.2118/199361-PA

7. Yousef A.A., Gentil P.H., Jensen J.L., Lake L.W., A capacitance model to infer interwell connectivity from production and injection rate fluctuations, SPE-95322-MS, 2006, DOI: http://doi.org/10.2118/95322-PA

8. Zhao H., Kang Z., Zhang X. et al., INSIM: A data-driven model for history matching and prediction for waterflooding monitoring and management with a field application, SPE-173213-MS, 2015, DOI: http://doi.org/10.2118/173213-MS

9. Albertoni A., Lake L.W., Inferring connectivity only from well-rate fluctuations in water floods, SPE-83381-PA, 2003, DOI: http://doi.org/10.2118/83381-PA

10. Guo Z., Reynolds A.C. A physics-based data-driven model for history-matching, prediction and characterization of waterflooding performance, SPE-182660-MS, 2017, DOI: https://doi.org/10.2118/182660-PA

11. Zhao H., Liu W., Rao X. et al., INSIM-FPT-3D: a data-driven model for history matching,water-breakthrough prediction and well-connectivity characterization in three-dimensional reservoirs, SPE-203931-MS, 2021, DOI: http://doi.org/10.2118/203931-MS

12. Ovsepian M., Lys E., Cheremisin A. et al., Testing the INSIM-FT proxy simulation method, Energies, 2023, V. 16, no. 4, DOI: http://doi.org/10.3390/en16041648

13. Klimova E.G., A stochastic ensemble Kalman filter with perturbation ensemble transformation (In Russ.), Sibirskiy zhurnal vychislitel’noy matematiki = Numerical Analysis and Applications, 2019, V. 22, no. 1, pp. 27–40, DOI: https://doi.org/10.15372/SJNM20190103

14. Bakhitov R.R., Application of machine learning algorithms in tasks of well productivity index forecasting for carbonate oil fields (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2019, no. 9, pp. 82–85, DOI: http://doi.org/10.24887/0028-2448-2019-9-82-85

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

For the operating conditions of the Romashkinskoye field, a comprehensive technology of simultaneous water and gas (SWAG) injection with the extraction of associated gas from the annular spaces of producing wells was proposed. Fresh and salty highly mineralized water was used when pumping water-gas mixtures (WGM) by the pump-ejector system. Experiments on WGM injection started using fresh water from the reservoir pressure maintenance (RPM) system and associated petroleum gas (APG) from producing wells. The pump-ejector system operated stably, without supply disruptions, and provided a WGM injection pressure of at least 20 MPa. But in the case of APG injection with fresh water, the injection pressure of the mixture steadily increased over time and reached limiting values for the ground equipment of the RPM system and injection wells, then it was necessary to turn off the pump-ejector system. When using salt water, the injection pressure of the mixture first increased, then, having passed through a maximum (10,7-10,8 MPa), 40 hours after the start of the pump-ejector system it was about 9 MPa. Field tests confirmed the operability and stable operation of the pump-ejector system at WGM injection pressures of up to 20 MPa and a decrease in the annular pressure from 3 MPa to atmospheric, revealed the problem of hydrate formation when using fresh water with Devonian associated petroleum gas, and enabled to establish that the use of salty highly mineralized water completely solves the problem of hydrate formation and a decrease in the injectivity of injection wells during SWAG treatment of the formation.

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., Utilization of associated petroleum gas with using of existing field infrastructure (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2014, no. 4,

pp. 74-77.

4. Apasov G.T., Mukhametshin V.G., Apasov T.G., Sakhipov D.M., Justification of water-gas impact technology using wellhead ejectors at the Samotlor field (In Russ.), Nauka i TEK, 2011, no. 7, pp. 47–50.

5. Nurgaliev A.A., Khabibullin L.T., Solution to the problem of utilization of associated gas from producing oil wells (In Russ.), Fundamental’nye i prikladnye voprosy gornykh nauk, 2014, V. 1, no. 1, pp. 249–257.

6. Agrawal G., Verma V., Gupta S. et al., Novel approach for evaluation of simultaneous water and gas injection pilot project in a Western offshore field, India,

SPE-178122, 2015, DOI: http://doi.org/10.2118/178122-MS

7. Abutalipov U.M., Kitabov A.N., Esipov P.K., Ivanov A.V., Analysis of design and technological parameters of gas-water ejector for associated gas utilization (In Russ.), Ekspozitsiya Neft’ Gaz, 2017, no. 4(57), pp. 54–58.

8. Shevchenko A.K., Chizhov S.I., Tarasov A.V., Preliminary results of fine-dispersed water-gas mixture injection into the reservoir at a late stage of Kotovskoye field development (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2011, no. 10, pp. 100-102.

9. Drozdov A.N., Drozdov N.A., Bunkin N.F., Kozlov V.A., Study of suppression of gas bubbles coalescence in the liquid for use in technologies of oil production and associated gas utilization, SPE-187741, 2017, DOI: http://doi.org/10.2118/187741-MS

10. Drozdov A.N., Gorelkina E.I., Operating parameters of the pump-ejector system under SWAG injection at the Samodurovskoye field (In Russ.), SOCAR Proceedings, 2022, no. S2, pp. 009–018, DOI: http://doi.org/10.5510/OGP2022SI200734

11. Knyazeva N.A., Beregovoy A.N., Khisametdinov M.R. et al., Preparation for the introduction of SWAG at the fields of PJSC “Tatneft” (In Russ.), SOCAR Proceedings, 2022, no. S2, pp. 19–27, DOI: http://doi.org/10.5510/OGP2022SI200737

12. Drozdov A.N., Gorelkina E.I., Kalinnikov V.N., Pasyuta A.A., An integrated approach to improving the efficiency of pumping oil production at high linear and annular pressures (In Russ.), Burenie i neft’, 2023, no. 2, pp. 48–52.

13. 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, 2022, no. S2, pp. 037–044, DOI: http://doi.org/10.5510/OGP2022SI200744

14. Trebin G.F., Charygin N.V., Obukhova T.M., Nefti mestorozhdeniy Sovetskogo Soyuza (Oil from the fields of the Soviet Union), Moscow: Nedra Publ., 1980, 583 p.

15. Kaptelinin N.D., Malyshev A.G., Malysheva G.N., Phase relationships of gas-water hydrate mixtures when pumping them into injection wells (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 1978, no. 5, pp. 44–47.

16. Stanevich V.D., Evaluation of the possibility of hydrate formation in the injected water-gas mixture at the field of the Republic of Tatarstan (In Russ.), Nauchnyy aspekt, 2023, V. 26, no. 5, pp. 3333–3338.

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

18. 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.

In the conditions of the producing well stock of the X field, the main sediment-forming substance is calcium carbonate in the allotropic modification represented by calcite. The prevailing method of protection used at Oil Company against this complicating factor is chemical protection. However, during implementation of this protection, failures of downhole pumping equipment occur both due to scale deposition and to other reasons, but with the presence of a significant content of calcium carbonate in solid deposits found during dismantling of underground equipment. All this indicates the insufficient effectiveness of chemical protection from the scale deposition. During the analysis of field data, laboratory and pilot field work, it was revealed that the inefficiency of the applied chemical protection technologies is due to their inoperability: the scale inhibitor did not reach the pumping equipment. The main technology that has proven its effectiveness is the technology of periodic well treatments with a scale inhibitor through the annular space of the wells with its subsequent squeezing before the pump intake with water (the volume of water for squeezing was determined experimentally) with mandatory compliance with the required frequency of treatments. The results obtained made it possible to develop and implement an effective technology for chemical protection of wells with the scale deposition as the complicating factor and to optimize it for the conditions of Oil Company.

References

1. Demenin T.A., Experience of using electric wave emitters in the complicated well stock of PJSC NK Rosneft (In Russ.), Inzhenernaya praktika, 2020, no. 9, pp. 6-13.

2. Valekzhanin I.V., Rafikov V.N., Sinitsyna T.I. et al., Testing a scale inhibitor squeeze technology into a bottomhole formation zone under the conditions of the Sorovskoye field (In Russ.), Ekspozitsiya Neft’ Gaz, 2023, no. 3, pp. 61–66, DOI: https://doi.org/10.24412/2076-6785-2023-3-61-66

3. Brikov A.V., Markin A.N., Nizamov R.E., Technologies of scale inhibitors injection into production wells (In Russ.), Neftepromyslovoe delo, 2017, no. 9, pp. 54–59.

4. Brikov A.V., Markin A.N., Arrangement of scaling management system by the example of the Western Siberia oil field (In Russ.), Neftepromyslovoe delo, 2018, no. 4, pp. 56–61, DOI: https://doi.org/10.30713/0207-2351-2018-4-56-61

5. Vysotskikh A.M., Leonov Yu.K., Lushnikov A.V., Myasnikov I.Yu., Dosing of chemical reagents into the annular space of wells. Critical factors reducing the efficiency of the technology (In Russ.), Inzhenernaya praktika, 2023, no. 10, pp. 22–27.

6. RD 39-1-219-79. Tekhnologiya primeneniya novykh ingibitorov otlozheniya soley importnogo proizvodstva (SP-181, SP-191, SP-203, KOREKSIT 7647) (Technology of application of new imported scale inhibitors (SP-181, SP-191, SP-203, KOREKSIT 7647)).

7. Brikov A.V., Markin A.N., Neftepromyslovaya khimiya: prakticheskoe rukovodstvo po bor’be s obrazovaniem soley (Oilfield chemistry: A practical guide to salt control), Moscow: De Libri Publ., 2018, 335 p.

8. Markin A.N., Sukhoverkhov S.V., Brikov A.V., Neftepromyslovaya khimiya: analiticheskie metody (Oilfield chemistry: Analytical methods), Yuzhno-Sakhalinsk: Sakhalin Regional Printing House, 2016, 212 p. 

During periodic operation of oil wells using electric submersible pump (ESP) systems there were revealed cases when the temperature sensors installed on the motor casing fix higher temperature than the temperature sensors inside it. This fact indicates the presence of a heat source outside the motor. This source can only be the pump. During the pumping phase, the ESP heats up by drawing fluid from the annulus above and below the pump. In the accumulation phase, new fluid from the reservoir enters the annulus above the pump, where it is heated by heat exchange with the ESP casing and tubing. In the next cycle, during the pumping phase, more heated fluid enters the pump. With each new cycle, the fluid temperature increases, but at the same time the heat transfer to the formation surrounding the casing increases. The temperature rise ends when thermal equilibrium is reached. A mathematical model of this phenomenon is proposed, calculations are made showing that heating will be higher, the higher the pumping rate, the shorter the pumping time and the higher the concentration of undissolved gas. Hot liquid from the pump will get on the motor housing if the check valve does not close completely when the pump is switched off. Calculations showed that the gas-liquid mixture can be heated to temperatures exceeding the critical temperature (200-250 °C) for elastomers used in ESPs. The obtained results can be used in the selection of ESP and periodic operation mode of the selected system in the well.

References

1. Ageev Sh.R., Grigoryan E.E., Makienko G.P., Rossiyskie ustanovki lopastnykh nasosov dlya dobychi nefti i ikh primenenie (Russian vane pumping systems for oil recovery and their use), In “Entsiklopedicheskiy spravochnik” (Encyclopedic reference book), Perm’: Press-master Publ., 2007, 645 p.

2. Kuz’michev N.P., Short-term well operation [STWO] is unique approach to reduction of effects of complicating factors [in petroleum production] (In Russ.), Ekspozitsiya Neft’ Gaz, 2014, no. 4, pp. 56–59.

3. Yudin E.V., Piotrovskiy G.A., Smirnov N.A. et al., Methods and algorithms for modeling and optimizing periodic operation modes of wells equipped with electric submersible pumps (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2023, no. 5, pp. 116–122, DOI: http://doi.org/10.24887/0028-2448-2023-5-116-122

4. 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: http://doi.org/10.24887/0028-2448-2021-4-92-96

5. Erka B.A., Osobennosti tekhnologii ekspluatatsii elektrotsentrobezhnymi nasosami skvazhin s neustanovivshimisya rezhimami raboty (Features of the technology of operation of electric centrifugal pumps of wells with unsteady operating modes): thesis of candidate of technical science, Tyumen, 2006.

6. Mikheev M.A., Mikheeva I.M., Osnovy teploperedachi (Fundamentals of heat transfer), Moscow: Energiya Publ., 1977, 344 p.

The article presents the main approaches to evaluating the reliability of newly designed technical devices using virtual and full-scale tests. As a rule, when starting the development of new complicated objects, a small number of objects are tested and in this case there is no sufficiently substantiated possibility of static evaluation of the reliability results using a classical approach, when the selected theoretical distribution is checked for compliance with experimental data, distribution parameters are determined, etc. The article proposes to conduct an evaluation of the reliability of the designed technical systems in two stages. The first stage involves conducting virtual tests of 3D models of a pilot sample using numerical methods and techniques for constructing mathematical models using ANSYS software as a part of the CFD computational fluid dynamics and Mechanical Enterprise strength calculation packages (including the Logos software product). The second stage is the determination of the probability of failure-free operation based on a small number of tests without determining the distribution function, using the nonparametric statistical Mann criterion; and it also provides the possibility, with a small number of failures, of using an estimated probability of failure-free operation, taking into account the accumulation of information. To establish the causes of failures of pilot samples, a set of measures is proposed to establish and prevent the causes of failure and ensure the stable operation of the product.

References

1. Frolov K.V., Metody sovershenstvovaniya mashin i sovremennye problemy mashinostroeniya (Methods of improving machines and modern problems of mechanical engineering), Moscow: Mashinostroenie Publ., 1984, 224 p.

2. Viktorova V.S., Agregirovanie modeley analiza nadezhnosti i bezopasnosti tekhnicheskikh sistem slozhnoy struktury (Aggregation of models for the analysis of reliability and safety of technical systems of complex structure): thesis of doctor of technical science, Moscow, 2009.

3. Gorbunova E.B., Metod statisticheskoy obrabotki malykh vyborok dannykh v zadachakh prognozirovaniya i kontrolya sostoyaniya slozhnykh sistem (Method of statistical processing of small data samples in problems of forecasting and monitoring the state of complex systems): thesis of candidate of technical science, 2018.

4. Voynov K.N., Prognozirovanie nadezhnosti mekhanicheskikh sistem (Predicting the reliability of mechanical systems), Leningrad: Mashinostroenie Publ., 1978, 208 p.

5. Burumkulov F.Kh., Lezin P.P., Rabotosposobnost’ i dolgovechnost’ vosstanavlivaemykh detaley i sborochnykh edinits mashin (Performance and durability of restored parts and assembly units of machines), Saransk: Publ. of Mordovian University, 1993, 119 p.

6. Gaskarov D.V., Shapovalov V.I., Malaya vyborka (Small sampling), Moscow: Statistika Publ., 1978, 248 p.

7. Zarenin Yu.G, Stoyanova I.I., Opredelenie ispytaniy na nadezhnost’ (Definition of reliability testing), Moscow: Publishing house of standards, 1978, 168 p.

8. Chavchanidze V.V., Kumsishvili V.A., Primenenie vychislitel’noy tekhniki dlya avtomatizatsii proizvodstva (Application of computer technology for automation of production), Moscow: Mashgiz Publ., 2001.

9. Hastings N.A.J., Peacock J.B., Statistical distributions: A handbook for students and practitioners, Wiley, 1975, 130 p.

10. Aralov O.V., Buyanov I.V., Analysis of methods and approaches to reliability assessment in the prediction of main pipeline transport equipment failures (In Russ.), Nauka i tehnologii truboprovodnogo transporta nefti i nefteproduktov = Science & Technologies: Oil and Oil Products Pipeline Transportation, 2017, V. 7, no. 6, pp. 104–114.

11. Bogomolov M.V., Virtual testing of products (In Russ.), Trudy MAI, 2010, V. 38, URL: https://trudymai.ru/upload/iblock/552/virtualnye-ispytaniya-izdeliy.pdf

12. Tkachenko A.Yu., Rybakov V.N., Krupenich I.N. et al., Computer-aided system of virtual gas turbine engine testing (In Russ.), Vestnik SGAU = VESTNIK of Samara University Aerospace and Mechanical Engineering, 2014, no. 5-3 (47), DOI: http://doi.org/10.18287/1998-6629-2014-0-5-3(47)-113-119

13. Abdullaev M.U., Kishkin A.A., Technologies of numerical and virtual experiments in engineering (In Russ.), Aktual’nye problemy aviatsii i kosmonavtiki, 2022, V. 1,

pp. 240-241.

14. Golovkova Yu.S., Numerical modeling in ANSYS program (In Russ.), Problemy nauki, 2020, no. 6 (54), pp. 43-44.

15. Garipov A.A., Konstantinov S.Yu., Tuk D.E., Tselishchev D.V., Computational fluid flow modeling in filter (In Russ.), Vestnik UGATU, 2013, no. 3(56), pp. 153-158.

16. Buyanov I.V., The main approaches to predicting the reliability of machines during development (In Russ.), Nauka i tehnologii truboprovodnogo transporta nefti i nefteproduktov = Science & Technologies: Oil and Oil Products Pipeline Transportation, 2024, V. 14, no. 5, pp. 440–449, DOI: https://doi.org/10.28999/2541-9595-2024-14-5-440-449

17. Lloyd D.K., Lipow M., Reliability: Management, methods, and mathematics, Prentice Hall, 1962, 528 p.

18. Barlow R.E., Proschan F., Mathematical theory of reliability, John Wiley and Sons, 1965, 261 p.

19. Pronikov A.S., Parametricheskaya nadezhnost’ mashin (Parametric reliability of machines), Moscow: Publ. of Moscow State Technical University N.E. Bauman,

2002, 560 p.

20. Lipkin I.A., Statisticheskaya radiotekhnika. Teoriya informatsii i kodirovaniya (Statistical radio engineering. Information and coding theory), Moscow: Vuzovskaya kniga Publ., 2002, 216 p.

The construction of wells under conditions of abnormally low reservoir pressures (ALRP) requires the use of low-density process fluids. In ALRP conditions with anomaly coefficient of 0,6-0,8 drilling fluids with a density of 1,00 g/cm3 or less are typically used. The use of low-density drilling fluids is especially important when drilling wells in old fields at a late stage of development, in conditions of loss of circulation, when drilling in underbalanced conditions, etc. The practice of using light flushing agents - hydrocarbon liquids, aerated and foam systems - revealed their significant disadvantages, and therefore their use is limited. Gazprom VNIIGAZ LLC developed a technology for increasing the resistance of a surfactant emulsifier to temperature, which consists of condensing a polyelectrolyte complex (PEC) on the interface. The developed emulsion drilling fluid is a Pickering emulsion, with the difference that the protective layer, instead of solid particles, is represented by condensed PEC with viscoelastic properties from oppositely charged emulsifier and polymer. Emulsion solutions showed exceptional stability during testing and are recommended for drilling sidetracks in the Astrakhan gas condensate field. The developed technology makes it possible to create a line of emulsion drilling fluids with condensable PEC. Having in an arsenal a sufficiently number of oppositely charged surfactant emulsifiers and polyelectrolytes of polymers, it is possible to use various combinations of them to carry out PEC condensation reactions at the interfacial surface.

References

1. Kister E.G., Emul’sionnye glinistye rastvory (Emulsion clay solutions), Moscow: Publ. of GOSINTI, 1958, 60 p.

2. Kister E.G., Khimicheskaya obrabotka burovykh rastvorov (Chemical treatment of drilling fluids), Moscow: Nedra Publ., 1972, 392 p.

3. Kurbanov Ya.M., Gaydarov M.M.-R., Lightened process liquids (In Russ.), Izvestiya vuzov. Neft’ i gaz, 2008, no. 4, pp. 15-21.

4. Gaydarov A.M., Khubbatov A.A., Norov A.D. et al., Development and preparation of lightweight clathrate emulsions for well completions at Astrakhan gas-condensate field (In Russ.), Stroitel’stvo neftyanykh i gazovykh skvazhin na sushe i na more, 2015, no. 6, pp. 25-32.

5. Gaydarov A.M., Khubbatov A.A., Khrabrov D.V. et al., Comparative tests of polycationic drill fluid at wells No. 915 and 629 of Astrakhan gas condensate field (In Russ.), Gazovaya promyshlennost’, 2020, no. 1, pp. 36–44.

6. Gaydarov M.M-R., Khubbatov A.A., Gaydarov A.M. et al., “Katburr» polycationic drilling fluids and prospects for their use (In Russ.), Stroitel’stvo neftyanykh i gazovykh skvazhin na sushe i na more, 2019, no. 7, pp. 19–25.

The modern organization of field and laboratory researches at the hydrocarbon fields of Western Siberia is distinguished by the need to take into account numerous factors. In order to achieve a comprehensive balanced result, appropriate digital support is required, which is designed to significantly reduce time and material costs at the preparatory stages and obtain a scientific and practical discovery, as the quintessence of the totality of ongoing monitoring and research of subsoil use. The main practical results for the organizer of field and laboratory researches, as well as for the consumer of these services, appear in a digital format of various types. For the effective implementation of this digital support for scientific research, premature thematic target study is important, which can be expressed in the format of a specific algorithm. The stability of procedures and their organizational flexibility enable to make a cyclical form of action, when the results of one research work become the starting point for the next, or the corresponding horizontal complementary information unit. After determining the territorial, thematic, organizational issues, it is possible to form and implement a digital twin of the field research process. The authors summarized the results of applying the algorithm for digital support of field and laboratory researches in the corporation, proposed algorithms for organizing digitalization for similar processes, and systematized the functions of the digital twin and geoinformation management. The findings may be of interest to subsoil users who have to process field and related data.

References

1. Pavlov P.N., Drobyshevskiy S.M., Structure of GDP growth rates in Russia up to 2024 (In Russ.), Voprosy ekonomiki, 2022, no. 3, pp. 29–51,

DOI: https://doi.org/10.32609/0042-8736-2022-3-29-51

2. Nefedova A.I., Volkova G.L., D’yachenko E.L. et al., International mobility and publication activity of early-career-researchers: What do statistics, bibliometrics and scientists themselves say (In Russ.), Zhurnal Novoy ekonomicheskoy assotsiatsii, 2021, no. 4, pp. 98–121, DOI: https://doi.org/10.31737/2221-2264-2021-52-4-4

3. Kirpotin S.N., Polishchuk Yu.M., Bryksina N.A., Thermokarst lakes square dynamics of West Siberian continuous and discontinuous permafrost under impact of global warming (In Russ.), Vestnik Tomskogo gosudarstvennogo universiteta, 2008, no. 311, pp. 185–190.

4. Popova V.V., Polyakova I.A., Change of stable snow cover destruction dates in Northern Eurasia, 1936–2008: impact of global warming and the role of large-scale atmospheric circulation (In Russ.), Led i sneg, 2013, V. 53, no. 2, pp. 29–39, DOI: https://doi.org/10.15356/2076-6734-2013-2-29-39

5. Kryukov V.A., Milyaev D.V., Savel’eva A.D., et al., Challenges and responses of the economy of the Republic of Tatarstan to decarbonization processes (In Russ.), Georesursy, 2021, no. 23, pp. 17–23, DOI: https://doi.org/10.18599/grs.2021.3.3

6. Kryukov V.A., Suslov N.I., Kryukov Ya.V., Asian Russia’s energy complex in a changing world (In Russ.), Mirovaya ekonomika i mezhdunarodnye otnosheniya, 2021,

V. 65, no. 12, pp. 101–108, DOI: https://doi.org/10.20542/0131-2227-2021-65-12-101-108

7. Danilov Yu.A., The concept of sustainable finance and the prospects for its implementation in Russia (In Russ.), Voprosy ekonomiki, 2021, no. 5, pp. 5–25,

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8. Medzhidova D.D., Energy transition and asset specificity transformation of the European gas market, International Organisations Research Journal, 2021, V. 16, no. 3, pp. 161–182, DOI: https://doi.org/10.17323/1996-7845-2021-03-07

9. Barinova V., Devyatova A., Lomov D., The role of digitalization in the global energy transition, International Organisations Research Journal, 2021, V. 17, no. 4,

pp. 126–145, DOI: https://doi.org/10.17323/1996-7845-2021-04-06

10. Basyrov M.A., Kunafin R.N., Akchurin A.A. et al., Digital service for hydrodynamic and geophysical well test (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2021,

no. 9, pp. 86–89, DOI: https://doi.org/10.24887/0028-2448-2021-9-86-89

11. Zeybot R.R., Zaedinov R.V., Korogodin A.Yu., New vision of datacenter’s implementation in oil and gas industry (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2007, no. 12, pp. 112–115.

12. Dichenko S.A., A model of information security threats of protected special-purpose information and analytical systems (In Russ.), Voprosy oboronnoy tekhniki. Ser. 16. Tekhnicheskie sredstva protivodeystviya terrorizmu, 2022, no. 1–2, pp. 64–71.

13. Mikhaylov V., Runge Y., Identification of individual. Territorial communities and social Space: an attempt of conceptualisation (In Russ.), Sotsiologicheskie issledovaniya, 2019, no. 1, pp. 52–62, DOI: https://doi.org/10.31857/S013216250003747-4

14. Shishkin A.N., Timashev E.O., Solovykh V.I. et al., Bashneft digital transformation: from concept design to implementation (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2019, no. 3, pp. 7–12, DOI: https://doi.org/10.24887/0028-2448-2019-3-7-12

15. Vorob’ev A.V., The concept of information packet interaction in a multilevel system of digital twins (In Russ.), Izvestiya Saratovskogo universiteta. Novaya seriya.

Ser.: Matematika. Mekhanika. Informatika = Izvestiya of Saratov University. Mathematics. Mechanics. Informatics, 2021, V. 21, no. 4, pp. 532–543,

DOI: https://doi.org/10.18500/1816-9791-2021-21-4-532-543

To protect the anticorrosive coatings of pipelines from external mechanical influences, a significant number of different variants of protective coatings of the pipeline surface are currently used. When choosing the protective coating required for the laying conditions of a particular project, developers take into account a large number of variable factors that affect the safety of the pipeline and ensure the reliability of the protective structure at all stages of its construction and operation. The alternative protective structures used in practice are made of various materials and, in terms of their strength characteristics, are designed to solve both local problems of protecting part of the pipeline and protecting the pipeline as a whole, including butt joint zones. To obtain the design characteristics, such structures require the use of specialized application technologies and have, accordingly, various protective properties. At the same time, the industry does not systematize the required characteristics of protective coatings, which they must have in order to reliably compensate for external influences on the pipeline. The article provides the analysis of the factors affecting the effectiveness of pipeline corrosion protection and suggests an algorithm for analyzing various pipeline protection options based on a factorial comparison of protection effectiveness parameters using the Ishikawa diagram. To systematize the characteristics of protective coatings the most significant problems in the pipeline protection system from mechanical influences were identified.

References

1. Patent RU2345267C2, Method for application of ballast coating on pipe surface, Inventor: Svechkopalov A.P.

2. Patent RU2735884C1, Coating for protection of concrete-coated pipes, Inventor: Shaporin I.I.

3. Mayants Yu.A., Elfimov A.V., Kuz’bozhev A.S. et al., Substantiation of the acceptable soil fraction size, used during construction of the gas pipeline with mechanical damage protection equipment (In Russ.), Gazovaya promyshlennost’, 2020, no. 1(797), pp. 40–46.

4. Shaporin I.I., Vasil’ev G.G., Leonovich I.A., Methods for determining the strength characteristics of pipeline protective coatings (In Russ.), Nauka i tehnologii truboprovodnogo transporta nefti i nefteproduktov = Science & Technologies: Oil and Oil Products Pipeline Transportation, 2024, V. 14, no. 6, pp. 526-535,

DOI: https://doi.org/10.28999/2541-9595-2024-14-6-526-535

5. ISO 21809-5:2017. Petroleum and natural gas industries - External coatings for buried or submerged pipelines used in pipeline transportation systems - Part 5: External concrete coatings

6. Shaporin I.I., Analysis of some specific features of mechanical damage to onshore oil and gas pipelines (In Russ.), Zashchita okruzhayushchey sredy v neftegazovom komplekse, 2024, no. 5(320), pp. 67-72.

7. SP 86.13330.2022. SNiP III. Magistral’nye truboprovody (Main pipelines).

8. Utility patent RU192391U1, Konstruktsiya styka trub s naruzhnym betonnym pokrytiem (Construction of a pipe joint with an external concrete coating), Inventor:

Shaporin I.I.

9. Vasil’ev G.G., Sentsov S.I., Kovaleva S.O., Ecological problems at land allotment at main pipeline construction (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2007, no. 10, pp. 139–141.

10. SP 341.1325800.2017. Podzemnye inzhenernye kommunikatsii. Prokladka gorizontal’nym napravlennym bureniem (Underground utility lines. Laying by horizontal directional drilling).

11. STO Gazprom 2-2.2-382-2009. Magistral’nye gazoprovody. Pravila proizvodstva i priemki rabot pri stroitel’stve sukhoputnykh uchastkov gazoprovodov, v tom chisle v usloviyakh Kraynego Severa (Main gas pipelines. Rules for the production and acceptance of works during the construction of land sections of gas pipelines, including in the conditions of the Far North).

Nowadays, steel pipelines are mainly used in field pipelines of the fuel and energy complex of Russia. Despite their high strength characteristics, their use is associated with the risk of emergency situations, mainly due to corrosion. This article presents an assessment of the impact of in-line cleaning on the accident rate of field pipelines. The factors influencing high corrosion rate and pipeline accident rate are analyzed. The authors noted that one of the main reasons for the increase of corrosion rate and reduction of operational reliability of pipelines is the impact of aggressive medium on the metal. The influence of such factors as corrosion products, asphalt-salt-paraffin deposits, inorganic salts, water accumulations and mechanical impurities on corrosion processes is considered. The statistics of field pipeline accidents at three Rosneft Group companies was analyzed. Grouping was carried out on the basis of field data. The division of the data sample into groups of similar indicators allowed analyzing the existence of a relationship between cleaning and accident rate in order to subsequently assess the efficiency of in-line cleaning in each company of Rosneft Group. The results of laboratory research in the framework of studying the influence of corrosion products on the overall corrosion rate of metal are presented. In the course of the study, experiments were conducted with samples of two grades of steel for the efficiency of their cleaning from corrosion products, and a general assessment of the impact of in-line cleaning on the corrosion rate and accident rate of field pipelines was given.

References

1. Tkacheva V.E., Valekzhanin I.V., Kshnyakin D.V. et al., Serovodorod (H2S): lokal’nye i korrozionno-mekhanicheskie razrusheniya v neftedobyche (Hydrogen sulfide (H2S): local and corrosion-mechanical destruction in oil production), Ufa: Publ. of RN-BashNIPIneft, 2024, 240 p.

2. Khasanov I.I., Shakirov R.A., Bikbulatov R.V., Safina O.R., Modeling and characterization of the waxing process of main oil pipelines (In Russ.), Proektirovanie, sooruzhenie i ekspluatatsii gazonefteprovodov i gazoneftekhranilishch, 2023, no. 2, pp. 16-23, DOI: https://doi.org/10.24412/0131-4270-2023-2-16-23

3. Valiakhmetov R.I., Approaches to solving problems in the operation of industrial pipelines (In Russ.), Inzhenernaya praktika, 2021, no. 6, pp. 48-52.

4. Kats N.G., Starikov V.P., Parfenov S.N., Khimicheskoe soprotivlenie materialov i zashchita oborudovaniya neftegazopererabotki ot korrozii (Chemical resistance of materials and protection of oil and gas processing equipment from corrosion), Moscow: Mashinostroenie Publ., 2011, 436 p.

5. Kalandarov. N.O., Goyibova D.F., The effect of corrosion on the strength of equipment (In Russ.), Molodoy uchenyy, 2016, no. 9(113), pp. 171–173.

6. Ioffe A.V., Vyboyshchik M.A., Trifonova E.A., Suvorov P.V., Effect of chemical composition and structure on the resistance of oil line pipes to carbon dioxide corrosion (In Russ.), Metallovedenie i termicheskaya obrabotka metallov, 2010, no. 2, pp. 9–14.

7. Ivanovskiy V.N., Theoretical foundations of the corrosion process of oilfield equipment (In Russ.), Inzhenernaya praktika, 2010, no. 6, pp. 4–14.

8. Khasanov I.I., Application of heavy oil depostits as thermal insulating layer in major pipelines (In Russ.), Transport i khranenie nefteproduktov i uglevodorodnogo syr’ya, 2018, no. 4, pp. 32–38, DOI: https://doi.org/10.24411/0131-4270-2018-10405

It is a common knowledge that soil is an important natural resource and plays a key role in climate change and food security. Petroleum products have a negative impact on soil properties, and are difficult to decompose. Prolonged contamination by oil and petroleum products can lead to soil degradation and reduced productivity, therefore, it is becoming increasingly necessary to apply effective measures to control oil contamination. This article presents an assessment of the state of light gray forest soils with long-term oil contamination (starting from the 60-70s of the XX century) in the northern forest-steppe zone of the Republic of Bashkortostan. It is shown that small concentrations of petroleum products are present in the studied areas, as a result of which the hydrophobic properties of the soil are manifested. The processing of multispectral satellite images showed a low NDVI (Normalized Difference Vegetation Index) index in contaminated areas. The concentrations of heavy metals (Zn, Cu, Pb, Cd, As, Hg, Ni) contained in the soil do not exceed the permissible values of MPC (maximum permissible concentrations). The results of the research expand knowledge about monitoring soils with long-term oil contamination and complement existing research methods, as well as enable additional measures for soil remediation.

References

1. Shoba S.A., Alyabina I.O., Stolbovoy V.S., Yakovlev A.S., Soils in the system of natural resources of Russia (In Russ.), Ispol’zovanie i okhrana prirodnykh resursov v Rossii, 2005, no. 1, pp. 56–62.

2. Vadakkan K., Sathishkumar K., Raphael R. et al., Review on biochar as a sustainable green resource for the rehabilitation of petroleum hydrocarbon-contaminated soil, Science of The Total Environment, 2024, V. 941, DOI: https://doi.org/10.1016/j.scitotenv.2024.173679

3. Helmy Q., Kardena E., Enhancing field-scale bioremediation of weathered petroleum oil-contaminated soil with biocompost as a bulking agent, Case Studies in Chemical and Environmental Engineering, 2024, V. 9, DOI: https://doi.org/10.1016/j.cscee.2024.100735

4. Bretherton M., Horne D., Sumanasena H.A. et al., Repellency-induced runoff from New Zealand hill country under pasture: A plot study, Agricultural Water Management, 2018, V. 201, pp. 83–90, DOI: https://doi.org/10.1016/j.agwat.2018.01.013

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V. 51, no. 1–4, pp. 33–65, DOI: https://doi.org/10.1016/S0 012-8252(00)00011-8

6. Timofeeva E.A., Molodtsova A.S., The content of mobile forms of heavy metals in oil polluted typical chernozem in field experiment conditions (In Russ.), Vestnik Moskovskogo universiteta. Ser. 17. Pochvovedenie, 2023, V. 78, no. 3, pp. 93–102, DOI: https://doi.org/10.55959/MSU0137-0944-17-2023-78-3-93-102

7. Garshin M.V., Suleymanov R.R., Polyakova N.G., Assessment of the content of heavy metals in the soils of oilfield areas of the Republic of Bashkortostan (In Russ.), AgroEkoInfo, 2024, no. 6, DOI: https://doi.org/10.51419/202146601.

8. Gabbasova I.M., Suleymanov R.R., Khaziev F.Kh. et al., Recultivation of forest ground, polluted by oil sludge (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2001, no. 7, pp. 81–84.

9. Gabbasova I.M., Khaziev F.Kh., Suleymanov R.R., Estimating the status of soils contaminated long ago by crude oil after biological remediation (In Russ.), Pochvovedenie = Eurasian Soil Science, 2002, no. 10, pp. 1259–1273.

10. Bondur V.G., Aerospace methods and technologies for monitoring oil and gas areas and facilities (In Russ.), Issledovanie Zemli iz kosmosa = Izvestiya, Atmospheric and Oceanic Physics, 2010, no. 6, pp. 3–17.

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12. URL: https://onesoil.ai/ru

13. URL: https://earthengine.google.com