Starting from 2020 Rosneft Oil Company has launched a unique program for stratigraphic drilling in the seas of the Russian Arctic – RoSDAr (Rosneft Stratigraphic Drilling in Arctic). The main objective of the project is to obtain direct data on the geological structure of insufficiently explored parts of the Arctic shelf, where there was no parametric drilling. For this purpose, key technological aspects of the implementation of the stratigraphic drilling program for all seas of the Russian Arctic were developed. Carrying out such works includes the integration of drilling methods, geophysical studies of wells and high-frequency seismoacoustic surveys based on domestic methodological approaches and innovative equipment designed specifically for the tasks of the project. The technologies used during the project make it possible to work in hard-to-reach Arctic regions. During the implementation of the project (2020-2023), large-scale works were carried out in the north of the Kara Sea, in the Laptev Sea, the East Siberian Sea and the Chukchi Sea, unique geological material was obtained. The obtained data make it possible to remove key geological uncertainties concerning the sedimentary rocks of the studied regions. A fundamentally important part of the project implementation is the integration of core analysis data from stratigraphic wells with the results of previous geological and geophysical work, which allows us to obtain the most reliable models of the studied regions for a reasonable forecast of their oil and gas potential and increase the efficiency of exploration works. The implemented program of shallow-depth stratigraphic drilling is one of the key milestones of geological research of the Arctic shelf, having not only a unique fundamental scientific, but also of primary applied importance for the further development of the Russian Arctic.
1. Malyshev N.A., Verzhbitskii V.E., Skaryatin M.V. et al., Stratigraphic drilling in the Northern Kara sea: First case and preliminary results, Russian Geology and Geophysics, 2022, V. 63, pp. 1–13, DOI: http://doi.org/10.2113/RGG20224459
2. Petrov O.V., Nikishin A.M., Petrov E.I. et al., First results of stratigraphic drilling in the East Siberian sea focused on geological studies of the suture zone of the continental shelf’s marginal structures and deep-water areas of the Arctic ocean (In Russ.), Doklady RAN. Nauki o Zemle = Doklady Earth sciences, 2023, V. 512, no. 2, pp. 261–271, DOI: http://doi.org/10.1134/S1028334X23601256
3. Kolyubakin A.A., Mironyuk S.G., Roslyakov A.G. et al., Using a complex of geophysical methods to reveal dangerous geological processes and phenomena on the shelf of the Laptev Sea (In Russ.), Inzhenernye izyskaniya, 2016, no. 10-11, pp. 38-47.
4. Tokarev M.Yu., Roslyakov A.G., Terekhina Ya.E. et al., Promising seismic technologies for engineering-geological surveys on the shallow shelf (In Russ.), Geofizika, 2021, Special issue, pp. 3-11.
5. Patent RU 2592739 C1, Method for seismic survey on water bodies and device therefor, Inventors: Tokarev M.Yu., Gaynanov V.G., Kul’nitskiy L.M., Kolyubakin A.A.
6. Sudakova M.S., Belov M.V., Ponimaskin A.O. et al., Features of processing vertical seismic profiling data of offshore shallow wells with fiber-optic distributed systems (In Russ.), Geofizika, 2021, no. 6, pp. 110-118.
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The development of Russian oil and gas complex is associated with maintaining the required level of oil and gas production. The main challenge of Russian oil and gas industry today are related to entry into the late stage of development of most of the large fields, when the main reserves have already been recovered, and residual reserves are difficult to recover. The other problem is exhaustion of the fund of large and medium-sized local uplifts in areas of greatest interest in terms of oil and gas content, and the reproduction of the mineral resource base is possible only with the discovery of new hydrocarbon deposits concentrated in unconventional geological objects and complexes. Russian oil and gas companies of the Federation solve the following main tasks: increasing the oil recovery factor at developed fields; bringing new deposits into development; search for promising lithological oil and gas traps, including in unconventional objects. An equally important task is to identify missed objects in previously discovered fields. The main reason for the “missing” deposits may be: the complex mineralogical composition of reservoirs, facies variability of deposits, when deposits are represented by thin lenses; “distortion” of the readings of logging methods due to deep zones of penetration of the flushing fluid; limited well logging complex. In case of hard-to-recover reserves and complex reservoirs the use of special well logging methods is justified. One of the most promising areas is nuclear physical methods, including nuclear magnetic logging and pulsed neutron gamma spectrometric logging (INGS). These methods allow to estimate with high accuracy the elemental composition of rocks and the main petrophysical parameters in both open and cased holes. Effective use of logging data involves their analysis in combination with core data. Increasing the informative value and reliability of laboratory core studies is an important task facing the Rosneft Oil Company. The authors considered the development of core study technologies in support of the interpretation of special well logging methods using the example of the Tyumen Petroleum Research Center.
11. Metodicheskie rekomendatsii po issledovaniyu porod-kollektorov nefti i gaza fizicheskimi i petrograficheskimi metodami (Guidelines for the research of oil and gas reservoir rocks by physical and petrographic methods), Moscow: Publ. of VNIGNI, 1978, 395 p.
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5. Arzhilovskiy A.V., Baburin A.N., Vakhrusheva I.A. et al., 20th anniversary of Tyumen Petroleum Research Center - From a team of like-minded persons to the industry leaders (In Russ.), Nauchnyy zhurnal Rossiyskogo gazovogo obshchestva, 2020, no. 4(27), pp. 54–58.
6. Gil’manov Ya.I., Vakhrusheva I.A., Digitalization of core studies today and tomorrow: TNNC’s point of view (In Russ.), Nedropol’zovanie XXI vek, 2019, no. 5(81), pp. 124–131.
7. Lazeev A.N., Timashev E.O., Vakhrusheva I.A. et al., Digital Core technology development in Rosneft Oil Company (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2018, no. 11, pp. 18–22, DOI: https://doi.org/10.24887/0028-2448-2018-11-18-22
8. Gil’manov Ya.I., Glushkov D.V., Kuznetsov E.G., Experience of TNNTs (Tyumen Oil Research Center) in the interlaboratory control of X-Ray computer tomography (RKT) (In Russ.), Karotazhnik, 2022, no. 6(320), pp. 132–140.
9. Gil’manov Ya.I., Shul’ga R.S., Zagidullin M.I., Experience of TNNTs (Tyumen Oil Research Center) in the interlaboratory control of core samples porosity measurements by nuclear magnetic resonance (In Russ.), Karotazhnik, 2022, no. 6(320), pp. 38–43.
10. Patent RU 2748894 C1, Method for determining effective hydrogen index of fluids that fully or partially saturate pore space of naturally saturated rock samples, Inventors: Potapov A.G., Zagidullin M.I.
11. Patent RU 2673959 C2. System and method for energy regeneration of wasted heat, Inventors: Gil’manov Ya.I., Zagidullin M.I., Kukarskikh M.S.
12. Zagidullin M.I., Potapov A.G., Abdrakhmanov E.S. et al., Experience of studying the capacitive properties and saturation of reservoirs containing superviscous oils applying the NMR method (In Russ.), Geologiya, geofizika i razrabotka neftyanykh i gazovykh mestorozhdeniy, 2020, no. 10(346), pp. 68–77,
13. Patent RU 2627988 C1, Method for determining total porosity of cavernous rock samples by nuclear magnetic resonance method, Inventors: Gil’manov Ya.I., Nikolaev M.Yu., Solomatin E.N. , Komisarenko A.S.
14. Basyrov M.A., Mitrofanov D.A., Makhmutov I.R. et al., The development of the technique for measuring mass fractions of chemical elements using AINK-PL logs (In Russ.), Karotazhnik, 2021, no. 8(314), pp. 121–130.
15. Makhmutov I.R., Rakaev I.M., Mitrofanov D.A. et al., Application of innovative instrumentation & methodic equipment complex AINK-PL for petrophysical modeling in Rosneft Oil Company (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2023, no. 2, pp. 66–71. DOI: https://doi.org/10.24887/0028-2448-2023-2-66-71
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In recent years, Rosneft Oil Company has been increasingly involved in the development and operation of reservoirs with significant heterogeneity of poroelastic properties, with significant uncertainty of mechanical properties associated with their low level of study. In the Rosneft laboratory complex approaches to the geomechanical study of rocks have been sufficiently standardized (historically) in order to study their deformation and strength properties. The data obtained using the applied techniques contribute to increasing the efficiency of scientific support for the development of oil and gas fields at all stages of their life cycle. The data obtained using the applied techniques contribute to increasing the efficiency of scientific support for the development of oil and gas fields at all stages of their life cycle. The most general and informative in domestic practice is a comprehensive method of constructing rock strength certificates based on determining the strength limits of rocks under various conditions, and giving the necessary minimum of information about the strength and deformation properties of rocks suitable for further use for geomechanical and hydrodynamic modeling. However, one of the most important parameters used both in modeling and in calculating the initial data for geomechanical laboratory studies, the poroelasticity coefficient (Biot), requires a series of long-term separate studies. In order to obtain the necessary calculated data, according to the above methods, it is necessary to determine the deformation characteristics of the core material in various load distribution conditions, which is associated with the complication of the hardware part of the experiment, as well as the presence of a subjective view of the operator processing experimental data. The article presents an overview of the poroelasticity coefficients obtained from laboratory studies to determine the strength properties of the core.
1. Churkov A.V., Rogozin A.A., Yatsenko V.M. et al., Aspects of calculating the poroelasticity coefficient for productive formations in the West Siberian oil and gas province (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2022, no. 10, pp. 10-13, DOI: https://doi.org/10.24887/0028-2448-2022-10-10-13
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The most important part of geological exploration work is to ensure a reliable assessment of hydrocarbon reserves, which is based on petrophysical core studies. In the case of unconventional reservoirs and reservoirs with hard-to-recover reserves, the determination of porosity is a basic, fundamental condition for their successful study, since a reliable determination of this parameter, the value of which is many times lower than in traditional reservoirs, critically affects the assessment of the resource base (the effect of small numbers). In the Russian Federation, the most widespread assessment of the porosity of core samples in laboratory conditions is carried out using the liquid saturation method (state standard GOST 26450.1-85) when core samples are saturated with formation water (model) or kerosene, as well as the gas-volumetric method (for helium) and the NMR method. These methods are well-proven for traditional reservoirs, with their relatively large porosity values; for reservoirs with hard-to-recover reserves the situation does not look so positive. Weak methodological basis for performing porosity measurements in the case of low values, lack of unification of measurement conditions and methods, insufficient qualifications of specialists, lithologic-mineralogical and petrophysical features of the objects of study, lead to a significant discrepancy in the results of porosity measurements both by different methods and by different laboratories. To correctly assess the results obtained and the reasons for their discrepancies, knowledge of both characteristics of the object being studied, and measurement techniques and features of the equipment, is required. The article discussed the Rosneft Oil Company experience in development of a technology for assessing void space using petrophysical methods on core samples for various reservoirs, including unconventional ones, as well as the complex structure of void space.
1. Volkov V.A. et al., Vremennoe metodicheskoe rukovodstvo po podschetu zapasov nefti v treshchinnykh i treshchinno-porovykh kollektorakh v otlozheniyakh bazhenovskoy tolshchi Zapadno-Sibirskoy neftegazonosnoy provintsii (Temporary methodological guidelines for calculating oil reserves in fractured and fractured-pore reservoirs in the Bazhenov strata of the West Siberian oil and gas province), Moscow: Publ. of GKZ, 2018, pp. 432–482.
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3. Gil’manov Ya.I., Experience of LLC «Tyumen Petroleum Research Center» (LLC «TPRC») in determining the porosity of core samples (In Russ.), Neftepromyslovoe delo, 2020, no. ¹ 9(621), pp. 35–41, DOI: https://doi.org/10.30713/0207-2351-2020-9(621)-35-41
4. Gil’manov Ya.I., Salomatin E.N., Abdrakhmanov E.S., Lessons learned from laboratory cores analysis for determination of storage capacity of unconventional Post-Cenomanian Upper Cretaceous reservoirs (In Russ.), Neftyanaya provintsiya, 2019, ¹ 4(20), DOI: https://doi.org/10.25689/NP.2019.4.86-104
5. Gil’manov Ya.I., Void space assessment with modern laboratory tests. A case of Berezovskaya series (In Russ.), Vesti Gazovoy Nauki, 2021, no. 1 (46), pp. 170-175.
6. Zagidullin M.I., Potapov A.G., Abdrakhmanov E.S. et al., Experience of studying the capacitive properties and saturation of reservoirs containing superviscous oils applying the NMR method (In Russ.), Geologiya, geofizika i razrabotka neftyanykh i gazovykh mestorozhdeniy, 2020, no. 10(346), pp. 68–77,
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8. Gil’manov Ya.I., Fadeev A.M., Vakhrusheva I.A., Petrofizicheskie issledovaniya kerna bazheno-abalakskogo kompleksa na standartnykh obraztsakh i obraztsakh droblenoy porody, opyt TNNTs (Petrophysical studies of core from the Bazheno-Abalak complex using standard samples and crushed rock samples, TPRC experience), Proceedings of TPRC LLC, 2017, no. 3, pp. 53–64.
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11. Patent RU 2780988 C1, Method for determining the total porosity of naturally saturated rock samples using the NMR method, Inventors: Gil’manov Ya.I., Zagidullin M.I., Kukarskiy M.S.
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Nowadays, increasing amount of horizontal drilling due to their greater economic efficiency pushes the participants of the horizontal well construction to maximize costs reduction of the such wells construction. In turn reduction of the wells construction costs allows to increase economical efficiency of field development. Since the well placement process by itself is oriented on increasing horizontal wells drilling efficiency by maximization borehole NTG, the reduction of time expenditures, that affect the construction time of horizontal wells, makes this process even more efficient. Currently, each relogging procedure is performed on each horizontal wells in Rosneft Oil Company. Since the importance and necessity of this procedure has been repeatedly proved by the results of its performance, there is a need to optimize the time spent on it. At this moment, the oil and gas industry is actively using technologies for real-time data transfer between process participants. The geosteering process is no exception in this case. Real-time transmission of LWD data directly from the rig to the geosteering engineer during the drilling process using the WITSML protocol is widely used. The article observes the technology of LWD relogging in process of drilling horizontal wells by using real-time data transmission via WITSML channel, as well as the main advantages of this approach over the «traditional» LWD reclogging, which are achieved by reducing the productive time for this operation. If during the horizontal wells drilling process this operation is performed on regular basis (at all pull out of hole operations), the relevance of this procedure is multiplied.
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In the territory of the Kuyumbinskoye field in Eastern Siberia the well stimulation is an important task due to the specifics of geological structure. Vuggy-fractured dolomite reservoir, block structure of reservoir, impermeable matrix, low porosity and permeability, characteristics of cracks development, formation temperature and other features impose many restrictions on the use of implemented technologies, in particular on hydraulic fracturing. Due to the non-distribution of carbonate vuggy-fractured reservoirs on the territory of Russia, hydraulic fracturing was not previously used on objects with similar conditions. In this connection, the application of this technology required not only theoretical, but also practical research. Pilot tests and research on various types of hydraulic fracturing using two interval isolation technologies were carried out at the Kuyumbinskoye field in 2017 and 2022. On the positive side, proppant hydraulic fracturing with the use of straddle packer assemblies and MSHF assembly has proven itself. Acid and acid-proppant fracturing, as well as proppant fracturing performed without isolation of injection intervals, proved to be ineffective. At one of the wells, microseismic monitoring studies were carried out during the work, which made it possible to carry out a detailed assessment of seismic events that occurred during hydraulic fracturing in the reservoir. Through the use of this technology, the fact of the development of two fracture systems was discovered, which explains the complication obtained during hydraulic fracturing. Microseismic hydraulic fracture mapping also allowed to confirm the correctness of the crack geometry constructed at the design stage. The features of the work performed will allow, when planning future programs for hydraulic fracturing, to minimize the possibility of failures, as well as to apply the technology in similar geological conditions with less uncertainty.
1. Kulakov D.P., Khadimullin R.R., Specifics of geological and engineering operations in carbonate reservoirs with non-permeable matrix (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2023, no. 7, pp. 31–35, DOI: https://doi.org/10.24887/0028-2448-2023-7-31-35
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5. Grishchenko V.A., Bashirov I.R., Mukhametshin M.R., Bil’danov V.F., Features of application of proppant-acid fracturing technology o in the fields of the Republic of Bashkortostan (In Russ.), Neftyanoe khozyaystvo, 2018, no. 12, pp. 120–122, DOI: https://doi.org/10.24887/0028-2448-2018-12-120-122
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The article analyzes the well-known methods for analytical solution of the problem of unsteady fluid flow to a directional well. The first method is based on dividing the perforated interval of the well into a set of discrete linear elements with a uniform flux. This approach allows to accurately calculate the changes in downhole pressure. However, the duration of the calculation is unacceptable for engineering practice. The second method describes a directional perforated section with a single linear source with a uniform flux. In this case, the result is achieved due to the appropriate selection of equivalent point at which the pressure response in a borehole is calculated. This approach has high computational efficiency, but its accuracy is inferior to the first method. The authors proposed a modification of the second method to make calculations both fast and accurate. An equation for determining the coordinates of the equivalent pressure point is obtained by the method of the best combination of bottom-hole pressure curves calculated using both solutions. The required dependencies were obtained for all types of borders on the roof and bottom. It is established that calculations based on the proposed modification significantly reduce the calculation time. At the same time, the accuracy is within the limits sufficient for practical calculations. Pressure calculations were performed for the maximum values of the angle of inclination corresponding to the vertical and horizontal location of the well. The results are in good agreement with the data published in the literature and calculated in third-party commercial software. The proposed model of directional well completely solves the problem of efficient and high-speed calculation of unsteady pressure. This model is implemented by employees of RN-BashNIPIneft LLC (a subsidiary of Rosneft Oil Company) in the corporate software package RN-VEGA, designed for the analysis and interpretation of well tests.
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Currently, the design and scientific support of hydrocarbons reserves development is impossible without the application of up-to-date techniques, equipment, methods, and approaches to the storage and analysis of field information (digital wells, stationary monitoring, cross-well monitoring and accounting for the mutual influence of wells according to the material balance or deconvolution methods). To ensure the effectiveness of implemented field development system as a whole, it is necessary to regularly conduct survey by well testing and well logging. This survey allows to determine the current parameters of the wells, and to make optimization decisions during further wells operation. At the present state of the art effective development of hydrocarbons reserves can be ensured both by expanding the range of technical means and by combining research methods, minimizing unproductive wells shutdowns.
Since ruling document RD 153-39.0-109-01 "Complexation and stage-by-stage execution of geophysical, hydrodynamic and geochemical researches" has been established the range of wells testing methods has been significantly expanded due to the wide use of multilateral and multilateral wells, drilling of horizontal wells with multi-stage hydraulic fracturing in low-permeability formations, development of inland sea water and continental shelf reserves. All this influenced the choice of research tools, their integration, and clarification of the scope and frequency of monitoring methods, depending on the stage of field development. Methods and technologies for long-term stationary monitoring technological and geophysical parameters of the well operation mode (temperature, pressure, flow rate, product composition, etc.) have been created and continue to be developed using point, point-distributed or distributed stationary information systems installed in production wells for a long time. Updating RD 153-39.0-109-01 is an important step to improve the quality of survey and improve the efficiency of well operation.
1. Asalkhuzina G.F., Davletbaev A.Ya., Kuzin I.G. et al., Applying decline analysis for reservoir pressure determination (In Russ), Neftyanoe khozyaystvo = Oil Industry, 2022, no. 10, pp. 30–33, DOI: https://doi.org/10.24887/0028-2448-2022-10-30-33.
2. Davletbaev A.Ya., Makhota N.A., Nuriev A.Kh. et al., Design and analysis of injection tests during hydraulic fracturing in low-permeability reservoirs using RN-GRID software package (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2018, no. 10, pp. 77–83, DOI: https://doi.org/10.24887/0028-2448-2018-10-77-83
3. Stepanov S.V., Bekman A.D., Ruchkin A.A., Pospelova T.A., Soprovozhdenie razrabotki neftyanykh mestorozhdeniy s ispol'zovaniem modeley CRM (Support for oil field development using CRM models), Tyumen': Ekspress Publ., 2021, 300 p.
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Digital transformation and artificial intelligence (AI) play a special role in modern industry. They allow expanding the functional completeness of traditional methods, technologies and software tools, developing new methods based on intelligent computing technologies, and creating new data models designed for multidimensional data analysis, modeling and forecasting. Active application of these solutions is observed in the processes of monitoring, evaluating, making design and management decisions, performing time-consuming and multifunctional tasks and analyses. The AI introduction in the oil and gas industry improves the efficiency of design processes and increases the productivity of applied technologies.
The article discusses the possibilities of using AI methods for planning, design, development, forecasting and achieving high results in the field of oil and gas production. Such methods can significantly reduce costs during the design, construction and operation of oil and gas fields by increasing the productivity and speed of project work, improving the quality of work performed and significantly reducing the number of design errors and their timely correction. AI methods are able and allow to increase the level of safety and manage environmental research and natural resources more effectively by eliminating the human factor in monitoring and forecasting processes. AI tools make it possible to increase the efficiency of the use of labor and financial resources, reduce time costs, and optimize production processes during the hydrocarbons extraction. AI tools are used to interpret the results of 3D design and laser scanning, in engineering geology and geodesy, environmental surveys, designing highways and linear objects and solving organizational and managerial tasks in the design and construction of oil and gas facilities. The authors of the article systematized the AI capabilities, methods and in the field of oil and gas production, and showed the possibilities to improve design and survey work through AI use. The ways to further innovative development of AI tools are suggested as a key direction of digital transformation of the oil and gas industry.
1. Zoidov K.Kh., Ponomareva S.V., Serebryanskiy D.I., Strategic planning and prospects of using artificial neuron net-works in the domestic oil and gas industry (In Russ.), Regional’nye problemy preobrazovaniya ekonomiki, 2018, no. 9, pp. 15-24, DOI: https://doi.org/10.26726/1812-7096-2018-9-15-24
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5. Cheremisin D.G., Mkrtchan V.R., The relevance of the use of artificial intelligence in solving geodetic problems (In Russ.), Simvol nauki, 2022, no. 12, pp. 39-40.
6. Ovchinnikova N.G., Medvedkov D.A., The use of unmanned aerial vehicles for land management, cadastre and urban planning (In Russ.), Ekonomika i ekologiya territorial’nykh obrazovaniy, 2019, V. 3, no. 1, pp. 98-108, DOI: http://doi.org/10.23947/2413-1474-2019-3-1-98-108
7. Dmitrievskiy A.N., Eremin N.A., Chernikov A.D. et al., Automated system for preventing accidents during well construction (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2021, no. 1, pp. 72-76, DOI: https://doi.org/10.24887/0028-2448-2021-1-72-76
8. Dmitrievskiy A.N., Stolyarov V.E., Eremin N.A., Role of information in application of artificial intelligence technologies in construction of wells for oil and gas fields (In Russ.), Nauchnyy zhurnal Rossiyskogo Gazovogo Obshchestva = The scientific journal of the Russian Gas Society, 2020, no. 3(26), pp. 6-21.
9. Khamidulin T.G., Application of artificial neural networks in the transport industry (In Russ.), Ekonomika i sotsium, 2019, no. 4(59), pp. 851-858.
10. Babushkina N.E., Lyapin A.A., Solving the problem of determining the mechanical properties of road structure materials using neural network technologies (In Russ.), Advanced Engineering Research, 2022, V. 22, no. 3, pp. 285-292, DOI: https://doi.org/10.23947/2687-1653-2022-22-3-285-292
11. Kostyukova A. P., Kostyukova T. P., Saubanov V. S., Shayakhov O. F., Technological aspects of models construction for objects of oil and gas infrastructure (In Russ.), Mezhdunarodnyy nauchno-issledovatel’skiy zhurnal, 2018, no. 8(74), pp. 40-44, DOI: https://doi.org/10.23670/IRJ.2018.74.8.006
12. Gazarov A.R., The method of determining of video camera’s workspase displacement with using multi-element manipulator (In Russ.), Izvestiya Tul’skogo gosudarstvennogo universiteta. Tekhnicheskie nauki, 2020, no. 4, pp. 136-139.
13. Dmitrievskiy A.N., Stolyarov V.E., Eremin N.A., Current issues and indicators of digital transformation of oil and gas production at the final stage of field operation (In Russ.), SOCAR Proceedings, 2021, Special Issue No. 2, DOI: http://doi.org/10.5510/OGP2021SI200543
14. Kostyukova A.P., Kostyukova T.P., Saubanov V.S., To the question of development of modern competences of professional activity of the specialist (In Russ.), Fundamental’nye issledovaniya, 2016, no. 7-2, pp. 241-246.
15. Sarychev D.S., Using of information modeling during preparing of the developed design and production documentation (In Russ.), SAPR i GIS avtomobil’nykh dorog, 2015, no. 2 (5), pp. 20-24, DOI: http://doi.org/10.17273/CADGIS.2015.2.316. Chebkasov D.S., Strokanev K.S., Sharipov T.R. et al., Development of a new tool to optimize the non-uniform placement of oil wells (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2023, No. 3, pp. 71-73, DOI: https://doi.org/10.24887/0028-2448-2023-3-71-73
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The article describes the emissions structure of greenhouse gases from oil and gas extraction companies. The contribution of stationary fuel combustion facilities to self-generated electricity generation is determined. An analysis of available greenhouse gas reduction technologies for prospective power plants has been conducted. An evaluation of the impact of alternative energy generation methods on the intensity of greenhouse gas emissions from power generation facilities has been carried out. The use of wind power plants has been considered as renewable energy sources. The efficiency of gas turbine installation with combined cycle has been evaluated. A techno-economic model of carbon capture and storage facilities has been developed to assess ways to reduce emissions from power generation facilities. The potential for emissions reduction using «conventional» carbon capture technology from power plants flue gases, with a shift from open cycle to combined cycle power generation, as well as the use of renewable energy sources and a combination of the listed methods, has been calculated. An increase in the effectiveness of emission reduction and a decrease in project decarbonization costs through the combination of carbon capture technology with alternative methods of reducing carbon dioxide emissions intensity have been noted. Based on the results of the analysis, a ranking of proposed methods has been compiled based on the potential for reducing greenhouse gas emissions and the costs of achieving the target emission level. Based on the ranking of technologies, an individual approach to choosing a method for reducing carbon dioxide emissions from prospective power plants has been developed, taking into account the location of power plants and the required emission reduction target.
2. Grushevenko E., Kapitonov S., Mel’nikov Yu. Et al., Dekarbonizatsiya v neftegazovoy otrasli: mezhdunarodnyy opyt i prioritety Rossii (Decarbonization in the oil and gas industry: international experience and Russian priorities): edited by Mitrova T., Gayda I., Moscow: Publ. of the Low-carbon and circular economy Lab, 2021, 158 p., URL: https://energy.skolkovo.ru/downloads/documents/SEneC/Research/SKOLKOVO_EneC_Decarbonization_of_oil_a...
3. Roshchin P.V., Zulpikarov A.A., Koshcheev I.V. et al., Application of specially designed flare tips to reduce methane emissions at oil and gas production facilities (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2023, no. 6, pp. 102-105, DOI: https://doi.org/10.24887/0028-2448-2023-6-102-105
4. Kolmogorova V.A., Smetanina L.A., Bulatov A.A., Yakovlev A.V., Applying a comprehensive approach to selection of the most effective option for reducing the intensity of carbon dioxide emissions (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2022, no. 9, pp. 132–136, DOI: https://doi.org/10.24887/0028-2448-2022-9-132-136
5. Technology overview “Ulavlivanie, ispol’zovanie i khranenie ugleroda (CCUS)” (Carbon capture, utilization and storage (CCUS)), URL: https://unece.org/sites/default/files/2021-02/CCUS%20brochure_RU_final.pdf
6. Tekhnologiya proizvodstva zhidkoy dvuokisi ugleroda (CO2) iz dymovykh gazov kotel’noy (Technology for the production of liquid carbon dioxide (CO2) from boiler house flue gases), URL: https://plamya-co2.ru/tech2.html
7. Golubev S.V., Technical and economic aspects of choosing power plants based on RES (In Russ.), Intellektual’naya elektrotekhnika, 2018, no. 3, pp. 102–113.
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“Rosneft-2030: Reliable Energy and Global Energy Transition” Strategy has been approved by the Board of Directors at the end of 2021. Rosneft Oil Company is the leader in the oil and gas industry of the Russian Federation and one of the largest companies in the global fuel and energy complex. The Company conducts its activities in strict accordance with the requirements of the country's legislation in the field of industrial safety, labor protection and the environment. Ensuring safe working conditions, Rosneft strives to trouble-free operation of the equipment, maintaining its performance and reliability, minimizing the impact on the environment in the course of its activities and complying with the requirements of the law. One of the type of environmental impact is stationary sources of emissions of pollutants into the atmospheric air, which include flare installations for burning associated petroleum gas at the facilities of oil and gas companies. To evaluate the effect of using soot-free flare tips in order to minimize the impact on the environment, a number of calculations were performed. It has been established that the reduction of pollutant emissions at oil and gas production facilities can be achieved by installing soot-free flare tips of various design options. It is noted that when installing the head of the flare for soot-free combustion, soot (smoke) emissions stop completely, hydrogen sulfide emissions are reduced by 97%, carbon monoxide by 92%, saturated hydrocarbons C1-C5 by 98%, a mixture of saturated hydrocarbons C6-C10 by 98%, benz(a)pyrene by 73%. The total mass of pollutant emission reduction when installing a soot-free combustion head can be reduced up to 80%, depending on the composition of the combusted gas. The possibility of reducing the financial burden for a legal entity in terms of payment for a negative impact on the environment is noted.
1. Sechin I.I., Novyy mirovoy energorynok: krestovyy pokhod protiv rossiyskoy nefti i gde “Noev kovcheg” (New world energy market: crusade against Russian oil and where is “Noah’s Ark”), URL: https://www.rosneft.ru/upload/site1/attach/spief_2022/REPORT_THE_NEW_WORLD_ENERGY_MARKET.pdf
2. Oil 2023. Analysis and forecast to 2028, IEA, URL: https://iea.blob.core.windows.net/assets/6ff5beb7-a9f9-489f-9d71-fd221b88c66e/Oil2023.pdf
3. Grushevenko E., Kapitonov S., Mel'nikov Yu. Et al., Dekarbonizatsiya v neftegazovoy otrasli: mezhdunarodnyy opyt i prioritety Rossii (Decarbonization in the oil and gas industry: international experience and Russian priorities): edited by Mitrova T., Gayda I., Moscow: Publ. of the Low-carbon and circular economy Lab, 2021, 158 p., URL: https://energy.skolkovo.ru/downloads/documents/SEneC/Research/SKOLKOVO_EneC_Decarbonization_of_oil_a...
4. 2022 Global Gas Flaring Tracker Report 2022, GGFR, World Bank Group, URL: https://thedocs.worldbank.org/en/doc/1692f2ba2bd6408db82db9eb3894a789-0400072022/original/2022-Globa...
5. Rashevskaya Yu.A., Roshchin P.V., Guba A.S. et al., Methane and carbon dioxide in Russian legislation (In Russ.), Vestnik evraziyskoy nauki = The Eurasian Scientific Journal, 2023, V. 15, no. 2, URL: https://esj.today/PDF/15NZVN223.pdf
6. Zero Routine Flaring by 2030, The World Bank, URL: https://www.worldbank.org/en/programs/zero-routine-flaring-by-2030
7. Strategiya “Rosneft'-2030” (Strategy “Rosneft-2030”), URL: https://www.rosneft.ru/about/strategy
8. Roshchin P.V., Zulpikarov A.A., Koshcheev I.V. et al., Application of specially designed flare tips to reduce methane emissions at oil and gas production facilities (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2023, no. 6, pp. 102-105, DOI: https://doi.org/10.24887/0028-2448-2023-6-102-105
9. Agerton M., Gilbert B., Upton G., The economics of natural gas venting, flaring and leaking in US Shale: an agenda for research and policy, USAEE, 2020, Working Paper no. 20-460, DOI: http://doi.org/10.2139/ssrn.3655624
10. Ahsan A., Ahsan H., Olfert J.S., Kostiuk L.W., Quantifying the carbon conversion efficiency and emission indices of a lab-scale natural gas flare with internal coflows of air or steam, Experimental Thermal and Fluid Science, 2019, V. 103, pp. 133-142, DOI: https://doi.org/10.1016/j.expthermflusci.2019.01.013
11. Torres V.M., Herndon S., Allen D.T., Industrial flare performance at low flow conditions. 2. Steam- and air-assisted flares, Ind. Eng. Chem. Res., 2012, V. 51, no. 39, pp. 12569–12576, DOI: https://doi.org/10.1021/ie202675f
12. Zamani M., Effects of co-flow on jet diffusion flames: Flow field and emissions: PhD thesis, Alberta, 2023, 158 p., DOI: https://doi.org/10.7939/r3-xgn1-xp46
13. Zamani M., Abbasi-Atibeh E., Olfert J.S., Kostiuk L.W., Co-flow jet diffusion flames in a multi-slot burner: Flow field and emissions, Process Safety and Environmental Protection, 2022, V. 167, pp. 686-694, DOI: https://doi.org/10.1016/j.psep.2022.08.069
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One of the modern ecological approaches in the development of new methods and technologies in the field of drilling mud management is not only to reduce the environmental burden on nature, but also the rational use of drilling mud as an affordable raw material for obtaining practically important products. This practice allows to obtain not only environmental, but also economic effect. Rosneft Oil Company is applying a set of measures to develop and implement the best available waste-free technologies for the disposal and neutralization of drilling waste, including within the framework of accumulated damage. The bulk of drilling waste is drilling sludge, which is a mixture of drilled rock, reservoir fluids and partially spent drilling mud removed from the circulation system of the drilling rig by cleaning devices. Rosneft Oil Company has developed and patented a technology for the disposal of drilling waste, which allows to obtain a stable positive environmental effect, as well as a product suitable for use in the economic activities of the subsidiary company. The key feature of the technology is a new sorbent-destructor of own design. The use of a sorbent-destructor promotes the sorption of hydrocarbons, heavy metals, radionuclides and surfactants contained in drilling mud, which leads to a decrease in the total content of pollutants. The article discusses the efficiency of the technology of disposal of drilling mud using a sorbent-destructor. The scheme of the process of disposal of drilling waste using a sorbent-destructor is presented. The assessment of changes in the content of the main pollutants contained in the drilling mud was carried out. Conclusions are drawn about the main advantages of using the developed technology.
1. Guba A.S., Pletneva, N.I., Yavich M.Yu., Identification of drilling waste (In Russ.), Neft’. Gaz. Novatsii, 2019, no. 11(288), pp. 82–86.
2. Smagin A.V., Kol’tsov I.N., Pepelov I.L. et al., The physical state of finely dispersed soil-like systems with drilling sludge as an example (In Russ.), Pochvovedenie = Eurasian Soil Science, 2011, no. 2, pp. 179–189.
3. Rosneft'. Otchet v oblasti ustoychivogo razvitiya za 2022 god (Rosneft. Sustainability Report 2022), URL: https://www.rosneft.ru/upload/site1/document_file/Rosneft_CSR2022_RUS.pdf
4. Patent RU 2767535 C1. Method for treating drilling waste, Inventors: Kozhin V.N., Guba A.S., Ivanov A.S., Dmitrieva Ya.V., Bakhtizin R.N., Sukharev V.V.
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The article provides brief information on the prospects and features of clarifying the geological structure of the Vikulov deposits in one of the areas of the Krasnoleninsky arch of Western Siberia. Based on a comprehensive interpretation of 3D seismic survey materials, drilling together with analysis of well logging materials, the shape of well logging curves and core research data, the features of the facies structure of the VK1 horizon were identified. To map the facies conditions of the Vikulov deposits, reflections associated with the top and bottom of the target interval were traced, and isochrone maps and structural surfaces were obtained. Based on the analysis of isochore and isopach maps with the results of 3D seismic exploration, the planned position of anomalies such as «incision» and «channel» associated with paleo-river effects was identified. The most representative is the isochore map, which does not introduce «velocity» deformation, caused by the irregular drilled well stock. The most informative seismic attributes based on the results of the studies performed are the root-mean-square amplitude and maximum magnitude. The contoured areas of maximum values were used as trends when constructing the geological model. To establish correlations between dynamic attributes and reservoir properties in the interval of productive objects, the parameters of effective thickness and porosity coefficient were selected. To localize individual groups of wells based on the shape of intrinsic polarization curves (IP) and the values of effective thicknesses, geometrization of the shapes of channel bodies and bar deposits, the results of a comparison of maps of amplitude attributes and sedimentary sections in the Vikulov deposits interval were used. Areas of improved filtration and reservoir properties of the upper part of the Vikulov formation represent an extensive network of remains of destroyed bodies of channel and bar deposits, the forecast and mapping of which are taken into account when creating and refining of geological models, as shown using the example of the use of 3D seismic materials based on drilling results. The results of the work, taking into account the accumulated experience in the exploration and development of oil and gas fields, indicate the need to expand the geological and geophysical complex of research, not only at the prospecting and exploration stages of work, but also to increase the efficiency of field development, many of which have been in operation for a long time.
1. Bembel' S.R., Geologiya i kartirovanie osobennostey stroeniya mestorozhdeniy nefti i gaza Zapadnoy Sibiri (Geology and mapping of structural features of oil and gas fields in Western Siberia), Tyumen: Publ. of TIU, 2016, 216 p.
2. Bembel' S.R., Sovremennye tekhnologii neftyanoy seysmorazvedki pri poiske i prognoze produktivnosti zalezhey nefti i gaza v Zapadnoy Sibiri (Modern technologies of oil seismic exploration in the search and forecast of the productivity of oil and gas deposits in Western Siberia), Collected papers “Sovremennye tekhnologii neftegazovoy geofiziki” (Modern technologies of oil and gas geophysics), Proceedings of mezhdunarodnoy nauchno-prakticheskoy konferentsii, 17-18 May 2018, Tyumen': TIU, 2019, pp. 6–9.
3. Bembel' S.R., Geological models and hydrocarbon prospects of the eastern part of the Krasnoleninsky arch (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2022, no. 11, pp. 74-78, DOI: http://doi.org/10.24887/0028-2448-2022-11-74-78
4. Medvedev A.L., Lopatin A.Yu., Zverev K.V., Fatsial'naya model' plastov VK1-3 vikulovskoy svity Kamennogo mestorozhdeniya (Zapadnaya Sibir') (Facies model of the VK1-3 formations of the Vikulovsky formation of the Kamennoe field (Western Siberia)), Proceedings of Geomodel 2006 - 8th EAGE science and applied research conference on oil and gas geological exploration and development, Moscow: Geomodel' Konsalting Publ., 2006, pp. 150-152, DOI: https://doi.org/10.3997/2214-4609.201403985
5. Gol'din S.V., Interpretatsiya dannykh seysmicheskogo metoda otrazhennykh voln (Interpretation of seismic reflection data), Moscow: Nedra Publ., 1979, 344 p.
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The article considers oil and gas prospects of radioactive interlayers of poorly studied carbonate formations of the Artinskian age of the Volga-Ural province for the purpose to increase the resource base of the region. The authors used an integrated approach to obtain the most reliable results for discovering of sedimentational conditions of the P1ar formation, assessing the reservoir properties of potentially productive intervals with high radioactivity and analyzing their lateral extension. Petrophysical, geological and field information of the object were collecting. Detailed correlation and the search of interlayers with increased radioactivity were made based on the complex of integral and spectrometric gamma ray logging data. A compilation of the selected interlayers with the core data and well testing is carried out. Sedimentological characteristics of the P1ar formation were assessed through an analysis of logging information and core description. The authors carried out a research of the conditions of the P1ar formation, an identification of the reasons of the uranium presence in these rocks. The article presents the results of creating a conceptual geological model of the P1ar formation, taking into account the refined petrophysical basis which was obtained by combining the analysis of core material, spectrometric gamma ray logging, well testing and geological correlation. Based on the results of the work, the reservoir properties of radioactive interlayers were confirmed and further research was recommended.
1. Metodicheskie rekomendatsii po podschetu zapasov nefti i gaza ob’emnym metodom. Otsenka kharaktera nasyshchennosti po dannym GIS (Guidelines for the calculation of reserves of oil and gas by volumetric method. Assessment of the nature of saturation according to well logging): edited by Petersil’e V.I., Poroskun V.I., Yatsenko G.G., Moscow – Tver: Publ. of VNIGNI, 2003, 258 p.
2. Urmanov E.G., Frolov A.M., Spectrometric gamma-logging data use for study of oil and gas prospecting wells sections (In Russ.), 1993, no. 8.
3. Fertl V.Kh., Spectrometry of natural gamma radiation in a well (In Russ.), Neft’, gaz i neftekhimiya za rubezhom, 1983, no. 3–6, 8, 10, 11.
4. Izotova T.S., Denisov S.B., Vendel’shteyn B.Yu., Sedimentologicheskiy analiz dannykh promyslovoy geofiziki (Sedimentological analysis of logging data), Moscow: Nedra Publ., 1993, 176 p.
5. Falk R.L., Petrology of sedimentary rocks, Hemphill Publishing Company, 1974, 176 p.
6. Dunsmore H.E., Origin of lead-zinc ores in carbonate rocks: a sedimentary-diagenetic model: Thesis submitted for the degree of Doctor of Philosophy of the University of London and for the Diploma of Imperial College, London, 1975.
7. Raddadi M.C., Vanneau A.A., Poupeau G. et al., Directly dating geologic events: U-Pb dating of carbonates, Reviews of Geophysics, 2009, V. 47, no. 3, pp. 9–21,
8. Raddadi M.C. et al., Interpretation of gamma-ray logs: The distribution of uranium in carbonate platform, Comptes Rendus Geoscience, 2005, V. 337(16), pp. 1457-1461, DOI: http://doi.org/10.1016/j.crte.2005.08.009
9. Dean W.E., Davies G.R., Anderson R.Y., Sedimentological significance of nodular and laminated anhydrite, Geology, 1975, no. 3(7), pp. 367–372,
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Interest in putting Achimov deposits into development creates new challenges in terms of geological modeling. The experience of appraisal and exploitation drilling in these reservoirs has shown that one of the key risks is associated with the complex distribution of fluids across productive horizons. This distribution indicates the presence of isolated lenses, the scale of which is often lower than seismic resolution. Applying most common modeling algorithms for high net-to-gross reservoirs leads to creation of models with very high connectivity, which is usually not typical for turbidite deposits owning to the features of sedimentary processes. The authors analyze the most common 3D modeling algorithms in the context of applicability for the probabilistic assessment of Achimov deposits using the example of Ach0-Ach4 formations of Zapadno-Pestsovoye Field. For each of the methods considered advantages and limitations are given. It is concluded that to solve the problem at the current stage of the project for the studied reservoirs the object method is optimal. It allowed considering many alternative options regarding the size of isolated sandbodies and their saturation with oil, gas and water. Based on the results of the assessment it was revealed that the P10/P90 ratio for oil-in-place in each lens penetrated by wells ranges from 6 to 8 and only about 20% of potentially productive sandbodies is discovered, which indicates a very low exploration maturity and high operational drilling risks. The use of a similar approach for probabilistic geological assessment at appraisal stage is also possible for reservoirs formed in other sedimentary processes, characterized with low connectivity and risks of fluid saturation of isolated sandbodies.
1. Bukatov M.V., Peskova D.N., Nenasheva M.G. et al., Key problems of Achimov deposits development on the different scales of studying (In Russ.), Proneft'. Professional'no o nefti, 2018, no. 2, pp. 16–21, DOI: https://doi.org/10.24887/2587-7399-2018-2-16-21
2. Pleshanov N.N., Peskova D.N., Zaboeva A.A. et al., Complex analysis of factors that influenced on water saturation forecast of Achimov formation at Gazpromneft licence blocks (In Russ.), PROneft'. Professional'no o nefti, 2020, no. 3(17), pp. 16–25, DOI: https://doi.org/10.7868/S2587739920030027
3. Manzocchi T., Walsh D.A., López-Cabrera J. et al., Compression-based modelling honouring facies connectivity in diverse geological systems, Springer Proceedings in Earth and Environmental Sciences: Geostatistics Toronto 2021 – Quantitative Geology and Geostatistics, 2023, pp. 111–117, DOI: http://doi.org/10.1007/978-3-031-19845-8_8
4. Natchuk N.Yu., Monakhova V.O., Pakhomov S.I. et al., Methodology and practice of analysis of geological models uncertainty of Achimov deposits on the example of the Urengoi field (In Russ.), Íåôòåïðîìûñëîâîå äåëî, 2019, no. 11(611), pp. 15–25, DOI: https://doi.org/10.30713/0207-2351-2019-11(611)-15-25
5. Prélat A., Covault J.A., Hodgson D.M. et al., Intrinsic controls on the range of volumes, morphologies, and dimensions of submarine lobes, Sedimentary Geology, 2010, no. 1–2(232), pp. 66–76, DOI: https://doi.org/10.1016/J.SEDGEO.2010.09.010
6. Deutsch C., Geostatistical reservoir modeling, Oxford: Oxford University Press, 2002, 392 p.
7. Kovalevskiy E.V., Geologicheskoe modelirovanie na osnove geostatistiki (Geological modeling based on geostatistics), Moscow: Publ. of EAGE, 2011, 117 p.
8. Zhang L., Pan M., Li Z., 3D modeling of deepwater turbidite lobes: a review of the research status and progress, Petroleum Science, 2020, no. 17, pp. 317–333,
9. Pyrcz M.J., Sech R.P., Covault J.A. et al., Stratigraphic rule-based reservoir modeling, Bulletin of Canadian Petroleum Geology, 2015, no. 4(63), pp. 287–303,
10. Walsh D.A., Manzocchi T., A method for generating geomodels conditioned to well data with high net:gross ratios but low connectivity, Marine and Petroleum Geology, 2021, V.129, DOI: https://doi.org/10.1016/J.MARPETGEO.2021.105104
11. Rose P.R., Risk analysis and management of petroleum exploration ventures, Tulsa: American Association of Petroleum Geologists, 2001, 164 p.
12. Popova O.A., Influence of correlations on results of probabilistic geological modelling (In Russ.), Íåôòåãàçîâàÿ ãåîëîãèÿ. Òåîðèÿ è ïðàêòèêà, 2020, no. 3. –
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The article presents the results of testing the previously unused type of well completion at the Bashkirian target of Chutyrsko-Kiengopskoye field. The reservoir is represented by limestones and dolomitized limestones, characterized by high fragmentation and the presence of a nitrogen gas cap both at the overlying Vereiskian deposits and directly in the target object. Until now, the object is being developed by directional and single horizontal wells. Taking into account the features of the geological section, as well as the proximity to the water-oil contact of the marginal part of the field, the criteria for choosing the drilling zone were formed. The analysis of early drilled wells using the technology of multilateral wells at the fields of Udmurtneft named after V.I. Kudinov was carried out. Based on the experience gained, criteria for selecting the optimal well drilling zone using Fishbone technology at the fields of Udmurtneft named after V.I. Kudinov were formed. An approach is applied to determine the optimal well profile and the number of boreholes using a sector geological and hydrodynamic model and the obtained economic models. Drilling of the well was carried out on two layers of the Bashkirian target (drilling of the main hole along the A42 layer with access to the A40 layer). The results of drilling multilateral horizontal wells using Fishbone technology in a highly fragmented carbonate section make it possible to increase the flow rate in comparison with horizontal and directional wells due to a significant increase in the effective penetration through the productive reservoir. Based on the positive results of technology testing, its further replication is planned. Also, to date, testing of the Dovetail multilateral well technology is underway at the Vereiskian rim of the Chutyrsko-Kiengopskoye field.
1. Zernin A.A., Zyuzev E.S., Sergeev A.S. et al., Recommendations for the multilateral wells design selection in various geological conditions based on lessons learned (In Russ.), Izvestiya vuzov. Neft' i gaz. – 2021. – ¹ 5. – S. 159–167. – DOI: https://doi.org/10.31660/0445-0108-2021-5-159-167
2. Levanov I.V., Sirotin D.N., Levin I.A. et al., 15 in 1. Experience utilization to construct multilateral well with 15 lateral branches (In Russ.), SPE-201865-MS, 2020,
3. Grinchenko V.A., Makhmutov D.Z., Bliznyukov V.Yu. et al., Efficiency of drilling and completion of directional oil-producing wells in the Eastern Siberia through a horizontal section evolution - From single wellbores to the "Birch-Leaf" design due to detailing of hydrocarbon deposits geological structure (In Russ.), Stroitel'stvo neftyanykh i gazovykh skvazhin na sushe i na more, 2020, no. 5 (329), pp. 8–15, DOI: https://doi.org/10.33285/0130-3872-2020-5(329)-8-15
4. Sokolyanskaya E.V., Fedorova A.A., Experience of drilling multilateral wells in carbonate deposits of the Osinsky horizon (In Russ.), Ekspozitsiya Neft' gaz, 2023, no. 2, pp. 38–42, DOI: https://doi.org/10.24412/2076-6785-2023-2-38-42
5. Zaikin I.P., Kempf K.V., Gotlib O.L. et al., Multibranch horizontal well drilling at Udmurtneft OJSC (In Russ.), ROGTEC, 2014, no. 9, pp. 46-54, URL: https://www.rogtecmagazine.com/wp-content/uploads/2014/09/04_Rosneft_EOR_Udmumeft.pdf
6. Fishbone. Technologies of the future on Messoyakha (In Russ.), Neftegaz, 2017, no. 3, URL: https://magazine.neftegaz.ru/articles/tekhnologii/541043-fishbone-tekhnologii-budushchego-na-messoyakhe/
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A study of the state of residual oil and mobile water in the process of oil displacement by water from core samples was carried out. The structure of residual oil at the micro level was studied. Analysis of available experimental approaches to the study of residual oil in core samples has shown that existing methods do not provide information on the structure of residual oil saturation. There are no reliable ways to study the structure of residual oil and the relationships of residual oil with the microstructure of the pore space. To solve the problems of structuring residual oil, it is proposed to use an innovative technology of diffusion-relaxation spectroscopy of nuclear magnetic resonance (2D NMR). Diffusion-relaxation two-dimensional spectroscopy uses differences in the values of the diffusion coefficients of oil and water. Relaxation spectra are used to distinguish oil from water. The analysis of the microdistribution of oil and water is carried out regardless of the viscosity of the oil. 2D NMR spectroscopy allows to study microscopic state of residual oil in an undisturbed core. The data can serve as a basis for creating effective methods for enhanced oil recovery. The principles of measurement and interpretation of 2D NMR spectra are described. With the help of the proposed methodology, a core study of the Shengli deposit (China) was carried out. The oil of this field has a high viscosity, and standard NMR technologies do not allow obtaining high-quality results. Using the proposed innovative technology, two-dimensional spectra for different stages of flooding were obtained and the state of residual oil at different stages was determined. The research results demonstrate a stable relationship between the NMR parameters of residual oil with the structure of the pore space and wettability. Differentiation of the mechanisms of formation of residual oil and its structure under the dominance of hydrodynamic and interphase forces is carried out. The role of the mobility of injected and residual water in the formation of residual oil is investigated.
1. Mikhaylov N.N., Ostatochnoe neftenasyshchenie razrabatyvaemykh plastov (Residual oil saturation of developed reservoirs), Moscow: Nedra Publ., 1992, 240 p.
2. Mikhaylov N.N., Petrophysical support for novel technologies for the re-extraction of residual oil from man-modified pools (In Russ.), Karotazhnik, 2011, no. 7(205), pp. 126–137.
3. Petrova L.M., Foss T.R., Abbakumova N.A., Romanov G.V., Regularities of formation of the composition of residual oils (In Russ.), Georesursy = Georesources, 2007, no. 3(22), pp. 43–45.
4. Dinariev O.Yu., Abashkin V.V., Evseev N.V. et al., Digital core analysis in problems of designing the development of oil and gas fields (In Russ.), Neftegaz.RU, 2021, no. 5(113), pp. 50–58.
5. Savitskiy Ya.V., Current features of x-ray tomography in examination of core samples from oil and gas deposits (In Russ.), Vestnik Permskogo natsional’nogo issledovatel’skogo politekhnicheskogo universiteta. Geologiya. Neftegazovoe i gornoe delo = Perm Journal of Petroleum and Mining Engineering, 2015, V. 14, no. 15, pp. 28–37, DOI: http://doi.org/10.15593/2224-9923/2015.15.4
6. Prusov E.S., Computed tomography for tasks of 3D materials science (In Russ.), Fundamental’nye issledovaniya, 2015, no. 5–2, pp. 318–323.
7. Emel’yanycheva E.A., Abdullin A.I., Study of petroleum modified bitumens using atomic force microscopy (In Russ.), Vestnik Kazanskogo tekhnologicheskogo universiteta, 2012, V. 15, no. 12, pp. 172–174.
8. Rudenko M.F., Surkov M.I., Nadirov N.K., Studies in fluorescence analysis of oil products (In Russ.), Vestnik Astrakhanskogo gosudarstvennogo tekhnicheskogo universiteta, 2008, no. 6(47), pp. 153–157.
9. Tugarova M.A., Balmasov E.L., Nesterov A.R., Petrova V.I., Application of confocal fluorescence microscopy in the examination of oil-and-gas bearing sedimentary rocks (In Russ.) Neftegazovaya geologiya. Teoriya i praktika, 2012, no. 1, pp. 1–20.
10. Zielinski L., Ramamoorthy R., Minh C.C. et al., Restricted diffusion effects in saturation estimates from 2D diffusion-relaxation NMR maps, SPE-134841-MS, 2010, DOI: http://doi.org/10.2118/134841-MS
11. Skvortsov B.V., Skvortsov D.B., Malysheva-Stroykova A.N., Theoretical bases of complex measurements of indicators of quality of oil products the method of the nuclear magnetic resonance (In Russ.), Izvestiya Samarskogo nauchnogo tsentra Rossiyskoy akademii nauk, 2011, V. 13, no. 6, pp. 252–258.
12. Toumelin E., Torres-Verdín S., Sun V., Keh-Jim D., Limits of 2D NMR interpretation techniques to quantify pore size, wettability, and fluid type: A numerical sensitivity study, SPE-90539-PA, 2006, DOI: http://doi.org/10.2118/90539-PA
13. Mikhaylov N.N., Motorova K.A., Sechina L.S., Geological factors of wettability of oil and gas reservoir rocks (In Russ.), Neftegaz.RU, 2016, no. 3(51), pp. 80–90.
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The article considers the possibility to apply a gas-volumetric porometer for determining pore volume compressibility coefficient of low-permeability rocks. The proposed method is an alternative to the existing time consuming laboratory research tests. The core used in the experiments was from one of the fields in Western Siberia. The proportion of samples drilled parallel to the bedding planes was 80%. Maximum coverage of lithotypes was provided (from medium-fine-grained sandstone to fine-grained siltstone with different carbonate and clay content). Experimental studies were carried out both with a gradual increasing of confining pressure (ascending branch) and with a gradual decreasing of confining pressure (descending branch). Exponential and linear dependence for porosity and power-law dependence for pore volume were used to approximate the experimental data. It was shown that there is practically no difference between different models. The behavior of some samples was not described with the proposed dependencies. Pore volume compressibility coefficient may be estimated as 10·10-4 MPa-1 when the porosity is over 10 %. Its maximum value was 286·10-4 MPa-1. The obtained values are consistent with the results of other researchers. According to the results of researches it was concluded that the determination of pore volume compressibility coefficient for low-permeability rocks by a gas-volumetric method is an acceptable alternative to traditional methods. But it should be kept in mind that the results obtained when performing such studies should be considered only as an express upper bound, because in the case of low-permeability rocks, the compressibility values determined by other methods will be lower due to the fluid-rock interactions.
1. Unalmiser S., Swalwell T.J., Routine determination of pore compressibility at any pressure based on two point measurements, SCA Conference, 1993, paper no. 9317.
2. De Oliveira G.L.P. et al., Pore volume compressibilities of sandstones and carbonates from Helium porosimetry measurements, Journal of Petroleum Science and Engineering, 2016, V. 137, pp. 185–201, DOI: https://doi.org/10.1016/j.petrol.2015.11.022
3. Vavilin V. et al., Strength properties, elastic modules and compressibility factors of rocks from oil fields OOO LUKOIL–Western Siberia, SPE-182028-MS, 2016, DOI: https://doi.org/10.2118/182028-MS
4. Khashper A.L. et al., Research of dependence of rock permeability on its stress-strain state (In Russ.), Geologicheskiy vestnik, 2019, no. 1, pp. 133–140, DOI: http://doi.org/10.31084/2619-0087/2019-1-10
5. McPhee C., Reed J., Zubizarreta I., Core analysis: A best practice guide, Elsevier, 2015, 852 p.
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10. Zhu S. et al., An analytical model for pore volume compressibility of reservoir rock, Fuel, 2018, V. 232, pp. 543–549, DOI: http://doi.org/10.1016/j.fuel.2018.05.165
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The article presents the results of laboratory studies on active acoustic and deformation monitoring of hydraulic fracturing crack opening in a model porous material based on gypsum. For comparison, the results of numerical modeling of the attenuation of elastic waves when passing through a model sample, based on the obtained experimental data, are presented. The work directly measures the fracture opening in comparison with the change in the amplitude of the ultrasonic pulse passing through the fracture during its formation and opening. The model sample has a cylindrical shape, and there is a tube with seedings inside the model to the middle of the sample's height to create a hydraulic fracturing crack up. The sample is placed between two aluminum disks, on the surface of which piezoelectric converters are mounted, that operate in the receiver and transmitter mode. With the help of a pumping system, hydraulic fracturing fluid (silicone oil) is injected into the sample through a tube, which leads to the formation of a circular crack perpendicular to the axis of the sample. As the fluid flow rate increased, the crack opening value was measured using induction displacement meters. According to the results of the study, dependences were constructed linking the injection pressure of the hydraulic fracturing fluid and the magnitude of the fracture crack opening with the magnitude of the amplitude of the signal of ultrasonic pulses that passed through the crack. The numerical simulation has shown that the results of the estimated normalized amplitudes of the ultrasonic pulse, depending on the size of the crack opening, differ from the experimental results with an error of up to 7%. The obtained results of the study allow us to estimate the magnitude of the hydraulic fracturing crack opening using active acoustic monitoring.
1. Hattori G., Trevelyan J., Augarde C.E. et al., 1, Arch Computat Methods Eng, 2017, V. 24, pp. 281–317, DOI: https://doi.org/10.1007/s11831-016-9169-0
2. Savenkov E.B., Borisov V.E., A mathematical model for hydraulic fracture propagation in three dimensional poroelastic medium (In Russ.), Vestnik Permskogo natsional'nogo issledovatel'skogo politekhnicheskogo universiteta. Mekhanika = PNRPU Mechanics Bulletin, 2018, no. 1, pp. 5–17, DOI: https://doi.org/10.15593/perm.mech/2018.1.01
3. Furong Wu, Yuanyuan Yan, Chen Yin, Real-time microseismic monitoring technology for hydraulic fracturing in shale gas reservoirs: A case study from the Southern Sichuan Basin, Natural Gas Industry B, 2017, V. 4, no. 1, pp. 68-71, DOI: https://doi.org/10.1016/j.ngib.2017.07.010
4. De Pater C.J., Cleary M.P., Quinn T.S. et al., Experimental verification of dimensional analysis for hydraulic fracturing, SPE-24994-PA, 1994,
5. Groenenboom J., Fokkema J.T., Monitoring the width of hydraulic fractures with acoustic waves, Geophysics, 1998, V. 63, no. 1, pp. 139–140,
6. Groenenboom J., van Dam D.B, de Pater C.J., Time-lapse ultrasonic measurements of laboratory hydraulic-fracture growth: Tip behavior and width profile, SPE-68882-PA, 2001, DOI: https://doi.org/10.2118/68882-PA
7. Medlin W.L., Massé L., Laboratory experiments in fracture propagation, SPE-10377-PA, 1984, DOI: https://doi.org/10.2118/10377-PA
8. Stanchits S., Surdi A., Edelman E., Suarez-Rivera R., Acoustic emission and ultrasonic transmission monitoring of hydraulic fracture initiation and growth in rock samples, Proceedings of 30th European Conference on Acoustic Emission Testing & 7th International Conference on Acoustic Emission, University of Granada, 12-15 September, 2012, https://www.ndt.net/article/ewgae2012/content/papers/52_Stanchits.pdf
9. Stanchits S., Surdi A., Gathogo P. et al., Onset of hydraulic fracture initiation monitored by acoustic emission and volumetric deformation measurements, Rock Mech Rock Eng, 2014, V. 47, pp. 1521–1532, DOI: https://doi.org/10.1007/s00603-014-0584-y
10. Stanchits S., Burghard J., Surdi A., Hydraulic fracturing of heterogeneous rock monitored by acoustic emission, Rock Mech Rock Eng, 2015, V. 48, pp. 2513–2527, DOI: https://doi.org/10.1007/s00603-015-0848-1
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12. Turuntaev S.B., Zenchenko E.V., Zenchenko P.E. et al., Hydraulic crack growth dynamics from ultrasound transmission monitoring in laboratory experiments (In Russ.), Fizika Zemli = Izvestiya, Physics of the Solid Earth, 2021, no. 5, pp. 104–119, DOI: http://doi.org/10.31857/S0002333721050215
13. Zenchenko E.V., Zenchenko P.E., Lukina A.A., Turuntaev S.B., Studying the dynamics of propagation and opening of hydraulic fracturing cracks in a laboratory experiment using acoustic methods (In Russ.), Dinamicheskie protsessy v geosferakh, 2019, no. 11, pp. 26–34, DOI: http://doi.org/10.26006/IDG.2019.11.38613
14. Zenchenko E.V., Zenchenko P.E., Nachev V.A. et al., Concurrent active acoustic and deformation monitoring of hydraulic fracture in laboratory experiments (In Russ.), Fizika Zemli = Izvestiya, Physics of the Solid Earth, 2023, no. 3, pp. 148–157, DOI: https://doi.org/10.31857/S0002333723030134
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The share of idle well stock at mature fields of the Krasnodar territory requires the implementation of effective measures for off-stream well reactivation. The most successful geological and technical measures (GTM) are recognized as the treatment of bottom-hole zones in order to remove clay-sand plugs, clean up from colmatant, as well as to intensify production, with direct impact on the productive horizon. The cleaning of the borehole must also be carried out before all other GTMs planned by subsurface users (pump change, fishing work, repair and insulation works). Ensuring the patency of production columns is also carried out at the initial stage wells liquidation. The authors propose device and technology for borehole treatment using jet cavitation effects. The device is lowered on a string of tubing or drill pipes into a well 2-2.5 m above the plug. Pumping unit is turned on, and well flushing is provided. It is possible to use direct and reverse flushing. The working fluid flows into the wellbore through the central profiled hole, as well as through the nozzles of the upper and lower tiers. If there is a sealed plug in the well not destroyed by a jet of flushing liquid (it is controlled by reducing the weight of the pipes during descent, i.e. after unloading to the current face), the flushing is stopped, a fitting (with a cavitation or hydrodynamic profile) is thrown into the column, a flow is formed to destroy the plug and clean the perforation intervals in the well. This technology has been commercially tested in wells of Vostochno-Severskoye and Klyuchevoye gas and oil fields of the Krasnodar region.
1. Patent RU 2796409 C1, Method for flushing clay-sand or proppant plug out of a well, Inventors: Omel'yanyuk M.V., Pakhlyan I.A.
2. Ibragimov L.Kh., Mishchenko I.T., Cheloyants D.K., Intensifikatsiya dobychi nefti (Oil well stimulation), Moscow: Nauka Publ., 2000, 414 p.
3. Omel'yanyuk M.V., Ukolov A.I., Pakhlyan I.A., Numerical simulation of turbulent submerged jets hitting a dead end when processing bottom-hole zones (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2020, no. 5, pp. 72–76, DOI: https://doi.org/10.24887/0028-2448-2020-5-72-76
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The choice of a development system for new oil fields is made by carrying out a series of calculations of predictive indicators on a hydrodynamic model, followed by an economic evaluation of the proposed options. A large number of varying development parameters (well placement scheme, distance between wells, completion method, horizontal well length, presence and number of hydraulic fractures, time of oil injection well development, etc.), as well as a large range of variation of these parameters values, require considerable time to select optimal values under the existing macroeconomic parameters. The developed algorithm for the selection of the optimal well placement system for carbonate reservoirs allows to realize a large variation of the development system parameters in a short time. In this paper, the algorithm for selecting the optimal well placement system is presented on the example of one of the Company's fields. The aim of this study is to establish a method for optimizing multivariate carbonate reservoir development systems. Our proposed method builds on the existing corporate software module, which facilitates the making of operational design decisions for any new drilling sites of carbonate objects. The module has been modified to include parameters that describe fluid filtration in a carbonate reservoir, such as reservoir type, wettability character, and secondary medium parameters.
1. Fedorov A.E., Dilmukhametov I.R., Povalyaev A.A. et al., Multivariate optimization of the system for the development of low-permeability reservoirs of oil fields of the Achimov formation (In Russ.), SPE-201811-RU, 2020, DOI: http://doi.org/10.2118/201811-RU
2. Fedorov A.E., Suleymanov B.I., Povalyaev A.A. et al., Decision support system for tight oil fields development Achimov deposits and their analogues using machine learning algorithms (In Russ.), SPE-201921-RU, 2020, DOI: http://doi.org/10.2118/201921-MS
3. Sayakhutdinov A.I., Ambartsumyan R.A., Kalimullin F.M., Classification of carbonate reservoirs for the purpose of increasing the efficiency of the development of carbonate objects (In Russ.), Ekspozitsiya Neft' Gaz = Exposition Oil Gas, 2022, no. 6, pp. 58–63, DOI: http://doi.org/10.24412/2076-6785-2022-6-58-63
4. Nelson R., Geologic analysis of naturally fractured reservoirs, Gulf Professional Publishing, 2001, 352 p.
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6. Aguilera R., Naturally fractured reservoirs, Tulsa, Oklahoma: PennWell Books, 1995, 521 p.
7. Sergeychev A.V., Toropov K.V., Antonov M.S. et al., Automated intelligent assistant in the selection of well placement when developing hard-to-recover reserves (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2020, no. 10, pp. 76–81, DOI: https://doi.org/10.24887/0028-2448-2020-10-76-81
8. Rozova A.R., Saf'yannikov I.M., World experience in applying various systems to develop low-permeable carbonate reservoirs (In Russ.), Neft'. Gaz. Novatsii, 2019, no. 1, pp. 24-28.
9. Lutfullin A.A., Basic methods of increasing of recoverable oil in Russia (In Russ.), Burenie i neft', 2009, no. 1, pp. 6–9.
10. Nurgaliev A.A., Khabibullin L.T., Analysis of well spacing effect on oil recovery and flooding pattern in small carbonate reservoirs in the Republic of Tatarstan (In Russ.), Interekspo Geo-Sibir', 2016, V. 2, no. 3, pp. 234–238
11. Topal A.Yu., Usmanov T.S., Zorin A.M. et al., Efficiency of horizontal wells elongation in carbonate reservoirs on the example of deposits Udmurtneft OJSC (In Russ.), Burenie i neft', 2018, no. 10, pp. 60–64.
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Since 1997 Vietsovpetro has been successfully applying the gaslift method of well operation on South Vietnam offshore fields, such as White Tiger, Dragon, White Bear, Beluga, White Hare. The gaslift method has a number of advantages providing the possibility to operate the wells with such complicating factors as high saturation pressure of oil, high gas-oil ratio, presence of asphaltene, resin and paraffin deposits and scaling, increased content and major solid returns during operation, significant well inclination angles. Gaslift downhole equipment allows running the tools for well testing, performing well stimulation by means of acidizing, repeated perforation, applying physical EOR methods. Conversion of wells into the injection system can be done without replacement of gaslift equipment and, therefore, without high costs on mobilizing the drilling unit. One of the major advantages among other artificial lifting methods is the long mean time between failures under the offshore fields conditions. However, the gaslift production method has some disadvantages. Operation of low-rate wells by the continuous gaslift method increases the specific gas flow rate, may lead to unstable lift operation, decreases the flow temperature at the wellhead and, therefore, increases paraffin formation on the tubings walls. There is a need to ensure the tightness of the downhole equipment and kick-off valves to secure well potential and reduce the specific flow rate of a compressed gas. Underperformance of gas lift operation can occur with the increase in water-cut of extracted products. Well operation depends on many factors that may vary over the period of development (water-cut, reservoir pressure, gas-oil ratio, pressure in the gathering and gaslift supply system). The experience of operating gas lift units in Vietnam fields showed that by eliminating multi-point gas injection and lift leaks, the specific gas consumption can be reduced by 20%, while ensuring the potential of well performance. Optimally distributing the compressed gas, it is possible to reduce specific costs by 10%. Therefore, one of the main objectives in monitoring the gaslift well stock operation is to research and identify the leakage areas in the downhole equipment and kick-off valves. Based on the tests results, the actions are developed to restore the equipment performance and improve its efficiency.
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The article deals with a pressing problem whole drilling horizontal wells - the presence of a non-measurement zone with downhole logging tools. There is a high probability of leaving the target interval when drilling horizontal wells, and a decrease in a flow rate. In these cases, the value of geochemical research conducted by a mud logging station increases. Today, in mud logging, there are several methods for studying cuttings, such as description of the penetration section lithology, determination of the density and carbonate content of rocks, and the type saturation using the LBA method. All these methods were developed more than 50 years ago, have not been improved to three days, and do not meet modern tasks. Searching for methods to increase the information content of sludge led to the technology of microbiota DNA sequencing. During the drilling process, along with drill cuttings or core, microorganisms inhabiting the formation are brought to the surface. With the development of new, and relatively inexpensive, quantitative description tools (DNA sequencing), detailed identification of formation microorganisms and determination of the conditions of their live and feed (oil or gas) have become possible. Thus, it became possible to use microorganisms as natural DNA markers to determine the zone and the type of reservoir saturation. The report describes potential areas for possible application of the technology in the process of well drilling and during subsequent well operation. The experience of using thigh technology at a field in the Russian Federation is also described.
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3 Il'yazov. R.R., Nikiforov S.A., Chernikov E.Yu., Rakhimov T.R., Gas logging for geosteering and rapid determination of interfluid contacts while horizontal drilling (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2023, no. 2, pp. 72–77, DOI: https://doi.org/10.24887/0028-2448-2023-2-72-77
4. Posdyshev A.S., Shelyakin P.V., Shaikhutdinov N.M. et al., Using DNA-logging to determine inflow profile in horizontal wells, SPE-206515-MS, 2021,
5. Vigneron A. et al., Comparative metagenomics of hydrocarbon and methane seeps of the Gulf of Mexico, Sci Rep., 2017, no 7, DOI: https://doi.org/10.1038/s41598-017-16375-5
6. Shakhverdiev A.Kh., Aref'ev S.V., Pozdyshev A.S., Il'yazov R.R., On inclusion of high-watered reserves of oil-poor reservoirs in the category of hard-to-recover reserves (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2023, no. 4, pp. 34–39, DOI: https://doi.org/10.24887/0028-2448-2023-4-34-39
7. Shakhverdiev A.Kh., Aref'ev S.V., Davydov A.V., Problems of transformation of hydrocarbon reserves into an unprofitable technogenic hard-to-recover reserves category (In Russ), Neftyanoe khozyaystvo = Oil Industry, 2022, no. 4, pp. 38–43, DOI: https://doi.org/10.24887/0028-2448-2022-4-38-43
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13. Ismail W.A., van Hamme J.D., Kilbane J.J., Ji-Dong Gu, Editorial: Petroleum microbial biotechnology: Challenges and prospects, Frontiers in Microbiology, 2017, no. 8, DOI: https://doi.org/10.3389/fmicb.2017.00833
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Keywords: robotization, simulation modeling, queuing system, production process, repair of pumping and compressor pipes
The article presents a general approach to simulation modeling of a robotic workshop engaged in the repair and restoration of pumping and compressor pipes. The main purpose of the simulation is to evaluate the effectiveness of repair work management using modern high-performance equipment. To achieve this goal, a review of various simulation languages and tools was carried out. A modeling algorithm based on queuing systems was selected and applied, allowing taking into account the features of the production process and effectively simulating the management of repair work. The algorithm is based on the idea of serving customers in a queue, where each customer represents a repair request. The queuing system takes into account the processing time of the application, the waiting time in the queue and the service time for each client. To carry out simulation modeling of the production process, the SimEvents environment, which is part of the Matlab/Simulink package, was selected. This environment provides ample opportunities for creating and analyzing computer models, and also allows you to organize a dynamic information database and visualize modeling results. Based on the results of simulation modeling, an assessment was made of the effectiveness of managing repair work in a robotic workshop, on the basis of which a proposal was made to optimize the production process. This proposal includes optimal resource allocation, improved work planning, optimization of robotic systems and other measures aimed at increasing the efficiency of the workshop and reducing the time it takes to complete repair work. Thus, the use of simulation modeling in this study allows us to evaluate the effectiveness of managing repair work in a robotic workshop and propose measures to optimize the production process. This is an important step in the development of modern methods of management and planning of production processes in the field of repair and restoration of tubing.
1. Lanskaya D.V., Kuznetsova K.A., Tools for solving problems of increasing competitiveness in the enterprise in the context of the introduction of lean manufacturing and digital transformations (In Russ.), Vestnik Akademii znaniy, 2021, no. 2(43), pp.119–124, DOI: https://doi.org/10.24412/2309-6139-2021-11051
2. Ponikarova I.N., Application of lean manufacturing tools and technologies in the management of knowledge-intensive companies in the context of innovation (In Russ.), Innovatsionnaya ekonomika: perspektivy razvitiya i sovershenstvovaniya, 2021, no. 8(58), pp. 97–104, DOI: https://doi.org/10.47581/2021/PS-94/IE.8.58.13
3. Il'in K.O., Gavrilova O.A., Kraevskiy N.N., Developing the concept of a robotic technological complex for well servicing and workover (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2022, no. 1, pp. 82–85, DOI: https://doi.org/10.24887/0028-2448-2022-1-82-85
4. Pleskunov M.A., Teoriya massovogo obsluzhivaniya (Queuing theory), Ekaterinburg: Publ. of Ural University, 2022, 264 p.
5. Oslin B.G., Modelirovanie. Imitatsionnoe modelirovanie SMO (Modeling. Simulation modeling of QS), Tomsk: Publ. of Tomsk Polytechnic University, 2010, 128 p., URL: http://simulation.su/uploads/files/default/2010-uch-posob-oslin.pdf
6. Zazulina D.S., Simulation modeling and artificial intelligence (In Russ.), Nauchnye vyskazyvaniya, 2023, no. 10(34), pp. 15–17. https://nvjournal.ru/article/Imitatsionnoe_modelirovanie_i_iskusstvennyj_intellekt
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Corrosion-erosion wear is a complex mechanism of material degradation resulting from simultaneous electrochemical and mechanical processes. Serious economic consequences of corrosion-erosion are expressed in failure of oil and gas equipment components, pipelines, and increased downtime and maintenance costs. The authors evaluated the corrosion resistance of pipe steels, the effectiveness of corrosion inhibitors, epoxy coatings as methods of anti-corrosion protection of equipment in the presence of mechanical impurities. As a result of the research, it was found that the presence of mechanical impurities causes increase in corrosion rate of carbon and low-alloy steels by 30-50%, depending on gas-liquid velocity. The most negative effect of mechanical impurities is appeared at high flow rates. Significant difference in comparable test conditions for steels containing chromium in an amount of 0.5% wt. and chromium-free have not been identified. Polymeric epoxy coatings are effective in preventing corrosion-erosion; however, their use in environments containing mechanical impurities and at high flow rates requires separate wear tests. Water-soluble corrosion inhibitor for protection against corrosion-erosion has been studied. It has been shown that use of a corrosion inhibitor in basic dosages (25 mg/l) is not effective. A possible mechanism for low efficiency of corrosion inhibitor at the indicated dosage is inhibitor adsorption on mechanical impurities and/or the breakdown of the corrosion inhibitor film during the mechanical action of suspended particles on metal surface. At higher dosages, the corrosion inhibitor effectively reduces the corrosion-erosion rate.
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The importance of developing an ESG approach, applicable to assessing the effectiveness of achieving goals, takes into account development, including by oil and gas industry enterprises, which is a fairly common problem in the modern Russian economy. A classic point in the creation of most companies is the wise use and expansion of the potential of human resources from the position of presenting it as the main fixed capital of the organization. Current transformational trends are focused on achieving ESG standards, defining new high requirements for the position, responsibility and qualifications of employees in environmental areas of knowledge, including issues related to the theory of development, and, in particular, the ESG concept as a tool for its assessment. However, the authors’ analysis of scientific sources of information showed a lack of methods for assessing environmental intelligence among enterprise managers, which is not only a new vector for the development of ESG methodology, but also a direction for the development of the oil and gas industry as a whole. Taking into account the classification division of environmental intelligence according to the scale of its production, it is considered appropriate to conduct a study of the level of development of economic environmental intelligence at oil and gas industry enterprises. The article presents the authors’ multi-criteria methodology for assessing environmental intelligence, supplemented by a scale for assessing the calculated results. An approbation calculation of statistics of open access data from enterprises in the fuel and energy sector was carried out. The analyzed results made it possible to paint over the general problems in the field of environmental exploration and identify promising directions for its development, characteristic of oil and gas industry enterprises.
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Drilling cuttings and associated process fluids re-injection underground into geological formations is a complex process. In order to inject drilled-out rock back into the formation, cuttings must follow through a long preparation chain. Firstly, rock is grained at several stages to obtain desired size granules. Then slurry pulp is prepared by mixing the slurry with the liquid. The rheology of the slurry pulp must maintain the solid phase in suspension (until them displaced in the formation). Next, the slurry pulp is injected into geological domain at pressure exceeding formation hydraulic fracturing pressure. Of all the existing drilling waste disposal methods the cuttings re-injection is considered the most appropriate technique for shelf projects due to environmentally sensitive marine ecosystem. This technology allows safely dispose all necessary drilling waste and at the same time allows to meet strict "zero discharge" requirements. Cuttings re-injection technology especially relevant for technical projects where it is not possible to dispose drilling waste using traditional methods (thermal desorption, annealing, dehydration, drying of drill cuttings, encapsulation and burial in sludge pits) due to severe climatic conditions, complexity of production processes. This article describes the basic principles of cuttings re-injection process and reviews the reasons for geological object capacity decrease while drilling waste disposal. The article also describes measures aimed at restoring fractured domain capacity probed at cuttings re-injection well drilled at offshore Piltun-Astokhskoye oilfield, the Sea of Okhotsk.
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