To achieve strategic goals of efficiency improvement, our Company implements performance management from potential. Benchmarking is an essential part of measuring success in any business. The current process analyzes top-level indicators characterizing company as a whole, but didn't let targeted identification of the most promising levers. New in-depth technical benchmarking approach is proposed. The developed method is based on the general principles of qualimetry and systems engineering: justification for the choice of metrics that reflect the purpose of the assessment and the features of the process under consideration; selection of initial data and determination of requirements for their accuracy; development of methods for determining the optimal values of quality indicators; unification of conditions for the use of metrics. The deep benchmarking based on the developed algorithms requires a huge amount of data. This is a very labor-intensive exercise for employees, so it was decided to create an IT tool that will automatically pull up the necessary data from corporate databases, process and compare with each other. For this purpose, Gazprom Neft has created the Gradient IT tool. Task of the tool for address searching and assessment the potential is to find a benchmark, assess the potential in each area (metric) and help production units with the search for activities that will allow this potential to be realized. The developed tool will consist of modules in accordance with the stages of deep technical benchmarking by processes and cost items by assets and industry, including: Assessment of potential, Modeling/ Goal-setting, Monitoring, Factor analysis. And the additional helpful modules: Asset analysis, Dynamics of a metrics. As a result of the Gradient project, it is expected: a) improving the quality of the formation of hypotheses about potential due to a targeted search for levers of its implementation; b) creating of a unified cost decomposition methodology and metrics database for the entire company with the ability to anonymously data view for all assets; c) the possibility of regular internal analyzing at all levels of management and potential searching; d) improved quality аnd speed of decision making through advanced analytics and modeling.

References

1. Bazyleva N., Mozhchil A. et al., Project gradient - A tool for comparative analysis and potential search, Paper presented at the International Petroleum Technology Conference, Riyadh, Saudi Arabia, February 2022, DOI: https://doi.org/10.2523/IPTC-22447-MS

2. Khasanov M.M., Maksimov Yu.V., Skudar’ O.O. et al., Value-Driven Engineering in Gazprom Neft (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2019, no. 12, pp. 6–11, DOI: https://doi.org/10.24887/0028-2448-2019-12-6-11

3. Glukhikh I., Pisarev M., Arzykulov O., Nonieva K., Evaluating the cost efficiency of systems engineering in oil and gas projects, Applied system innovation, 2020, no. 3(3), pp. 39, DOI: https://doi.org/10.3390/asi3030039.

4. Khasanov M.M., Maksimov Yu.V., Mozhchil’ A.F. et al., Osnovy sistemnogo inzhiniringa (Fundamentals of systems engineering), Moscow – Izhevsk: Publ. of Institute of Computer Science, 2020, 422 p.

5. Azgal’dov G.G., Glichev A.V., Panov V.P., Chto takoe kachestvo (What is quality), Moscow: Ekonomika Publ., 1968, 135s.

6. Azgal’dov G.G., Raykhman E.P., O kvalimetrii (About qualimetry), Moscow: Izdatel’stvo standartov Publ., 1973, 172 p.

7. Khasanov M.M., Sugaipov D.A., Ushmaev O.S., Development of cost engineering in Gazprom Neft JSC (In Russ.), Neftyanoe Khozyaystvo = Oil Industry, 2013, no. 12, pp. 14-16.

8. Skudar’ O.O., Pashkevich L.A., Khlyzova K.V., Operational expenditure: cost model of new opportunities (In Russ.), PROneft’. Professional’no o nefti, 2016, no. 2(2), pp. 72-75.

Thermal history reconstruction of a sedimentary basin is one of the key stages of petroleum system modeling. Heat transfer is dependent on sedimentary basin formation mechanism, heat physical properties (function of multiple factors that contribute to the rock section) and sedimentation rate. The analysis of the issue made it possible to systemize and generalize methodic approaches to predicting the density of heat flow and its components. The process of heat transfer in the Earth crust is a complicated physical phenomenon the description of which, let alone its modeling, implies certain assumptions. Heat flow is measured on the daylight surface or at shallow depth. At the same time, the power of the source (mantle heat flow and radiogenic heat) changes through time. Heat resistance of the crust also changes through time in a complicated way: temperature transformations of rocks occur. The rate of such transformations depends on mechanochemical activation, the Rehbinder’s effect, and other factors. The article shows the necessity of predicting the heat flow density in the context of a conceptual geologic model of the region evolution. Examples from the West Siberian and South American basins (Jurua Sub-basin, Solimoes Basin) show methodological techniques for predicting the heat flow density with account of the stages of tectonic processes and petroleum system evolvement. Iterative approach was used for predicting the heat flow density with account of catagenetic transformation maps of the basement, Middle Jurassic, top of Jurassic deposits in the Gydan Peninsula, the east of Yamal, the west of Yenisei-Khatanga Trough, and the adjacent offshore area. A distinctive feature of Jurua Sub-basin (Brazil) is the presence of intrusive bodies in the section of the sedimentary cover. The trend analysis method was applied when predicting the thermal history. Regional and local components were considered. The regional component is associated with changes in the Earth crust thickness, composition of the basement, and stages of tectonic history. The local component was predicted taking into account the magnetic field anomaly map.

References

1. Gies C., Struijk M., Bekesi E. et al., An effective method for paleo-temperature correction of 3D thermal models: a demonstration based on high resolution data sets in Netherlands, Global and planetary change, 2021, V. 199, pp. 1–15, DOI: https://doi.org/10.1016/j.gloplacha.2021.103445

2. Popov Y., Spasennykh M., Shakirov A. et al., Advanced determination of heat flow density on an example of West Siberia Russian oil field, Geosciences, 2021, V. 11, pp. 1–32, DOI: https://doi.org/10.3390/geosciences11080346

3. Hardwick C.L., Willis H.W., Gwynn M.L., A basin scale geothermal assessment of co-produced waters in oil and gas fields: Uinta basin, Utah, USA, GRC Transactions, 2015, V. 39, pp. 661–669.

4. Khutorskoy M.D., Teveleva E.A., Tsybulya L.A. et al., Heat flow in the salt dome basins of the northern Euroasian, Georesursy, 2010, no. 2(34), pp. 27-35.

5. Astakhov S.M., Georeaktor. Algoritmy neftegazoobrazovaniya (Georeactor. Algorithms for oil and gas generation), Rostov-on-Don: Kontiki Publ., 2015, 256 p.

6. Roy R.F., Blackwell D.D., Birch F., Heat generation of plutonic rocks and continental heat flow provinces, Earth and Planetary Science Letters, 1968, V. 5, pp. 1–12, DOI: https://doi.org/10.1016/S0012 -821X(68)80002-0

7. Bücker, C, Rybach L., A simple method to determine heat production from gamma-ray logs, Marine and Petroleum Geology, 1996, V. 13, pp. 373–375, DOI: https://doi.org/10.1016/0264-8172(95)00089-5

8. Hantschel T., Kauerauf A.I., Fundamentals of basin and petroleum system modeling, Springer-Verlag Berlin Heidelberg, 2009, 476 p.

9. Astakhov S.M., Reznikov A.N., Geothermal regimes of the world sedimentary basins for historical-genetic modeling of oil and gas-bearing (In Russ.), Geologiya, geofizika i razrabotka neftyanykh i gazovykh mestorozhdeniy, 2014, no. 9, pp. 15–21.

10. Peshkov G., Improving the accuracy of thermal history in basin modelling: the reduction of uncertainties in petroleum system analysis: doctoral thesis, Moscow, Skolkovo, 2021, 159 p.

11. Mareschal J.C., Jaupart C., Radiogenic heat production, thermal regime and evolution of continental crust, Tectonophysics, 2013, V. 609, pp. 524–534, DOI: https://doi.org/10.1016/j.tecto.2012.12.001

12. Duchkov A.D., Ayunov D.E., Yan P.A. et al. Thermal conductivity of rocks and estimates of heat flow in the Lena–Anabar interfluve (Siberian Platform) (In Russ.), Geologiya i geofizika = Russian Geology and Geophysics, 2022, V. 64, no. 6, pp. 858–869, DOI: http://doi.org/10.2113/RGG20224518

13. Chapman D.S., Keho T.H., Bauer M.S. et al., Heat flow in the Uinta Basin determined from bottom hole temperature (BHT) data, Geophysics, 1984, V. 49, no. 4, pp. 453–466.

14. Deshin A.A., Istoriko-geologicheskiy analiz protsessov formirovaniya skopleniy uglevodorodov v severo-vostochnoy chasti Zapadno-Sibirskogo megabasseyna (Historical and geological analysis of the processes of formation of hydrocarbon accumulations in the northeastern part of the West Siberian megabasin): thesis of candidate of geological and mineralogical science, Novosibirsk, 2022.

15. Polishchuk A.V., Lebedev M.V., Perepelina A.N., Modeling of petroleum system influenced by intrusive bodies (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2018, no. 1, pp. 12–17, DOI: http://doi.org/10.24887/0028-2448-2018-1-12-17

Currently, there is an active interest in the introduction of neural networks (NN) in seismic data interpretation (for automatic correlation of horizons and faults, for forecasting reservoir properties, and for highlighting geological objects etc.). Highlighting geological objects is particularly interesting from the point of view of object-oriented interpretation. Standard interpretative approaches are largely subjective and require considerable time. Using of NN for outlining an object makes it possible to give interpretation process greater objectivity and prepare object for subsequent morphometric analysis.

The article discusses use of NN to identify paleochannels in process of interpreting seismic data and generating images of their conceptual geological models. Paleocannels are the best object for testing new approaches, since it is possible to project our knowledge about the features of modern river sedimentogenesis, morphology of rivers, patterns of their development in time and space on events captured in geological history, referring to method of "actualism" by Charles Lyell. The article analyzes two methodological approaches. The first one is to apply computer vision algorithms and a Holistically Nested Edge Detection algorithm based on a deep learning model using a convolutional NN. These algorithms have been tested on the example of color images of results of spectral decomposition and images obtained using eXchroma technology, on which paleochannels were identified during interpretation. The second approach is to use NN to generate an image based on a text description. Such popular networks as Midjourney, Problembo, Kandinsky have been tested. This approach will allow to generate images when searching for analogues of developed sedimentation models. The development of NN methods for selecting channels and generating images of possible sedimentation analogues seems to be an extremely promising direction.

References

1. Van der Walt S., Schonberger J.L., Nunez-Iglesias J. et al., scikit-image: image processing in Python, PeerJ, 2014, no. 2, DOI: https://doi.org/10.7717/peerj.453

2. Rogers M.S.J., Bithell M., Brooks S.M., Spencer T., VEdge_Detector: automated coastal vegetation edge detection using a convolutional neural network,

DOI: https://doi.org/10.1080/01431161.2021.1897185

3. Xie S., Tu Z., Holistically-nested edge detection, Int J Comput Vis, 2017, V. 125, pp. 3-18, DOI: https://doi.org/10.1007/s11263-017-1004-z

4. Alekseeva P.A., Kalugin A.A., Kir’yanova T.N., Identification of Tyumen formation paleochannels by using a neural network and 3D seismic data (In Russ.), Geofizika, 2022, no. 3, pp. 9-15.

5. Ol’neva T.V., Zhukovskaya E.A., Oreshkova M.Yu., Kuz’min D.A., Diagnostics of morphogenetic types of paleochannels on the basis of parameterization of seismic images (In Russ.), Geofizika, 2022, no. 2, pp. 17-25.

The article is devoted to analysis drilling results at BU212 and BU213-1 deposits of Vostochno-Messoyakhskoe field. These deposits are composed by deep-water fans of lower Neokomian clinoform complex. Srednemessoyakhsky Swell had a huge impact to lateral paleo-transport directions of sediments. It was a kind of barrier helped to generate a sediment wedge that has affected on sediment flow direction. BU212 and BU213-1 deposits differ from analogue Achimov formation in neighbor oilfields by relatively high properties: average value of porosity coefficient varies from 16.5 to 19.5 %, while permeability may reach from 3.6·10-3 up to 46·10-3 μm2. Comparison of well lithology interpretation with simultaneous inversion results has showed that P-wave impedance cube matches well data best of other calculated elastic parameters. Therefore, this cube is used in geological model for net volume cube calculation. Due to seismic data resolution, calculated acoustic impedance shows only the tendency of reservoir distribution. There is a risk to estimate net volume incorrectly in the case of layer thinning and interference with underlying bed. For instance, section of one of the wells, drilled in proximal part of fan and channel, testifies that impedance matches well log interpretation data: you can clearly determine the borders of distributary channel and fan on seismic section. At the same time another well, drilled in distal part of the fan, has revealed the section with significantly higher compartmentalization and lower NTG, despite the fact that seismic data in this zone are characterized by the same values of acoustic impedance as in the proximal zone. In this case, optimal drilling strategy and well construction were chosen owing to sedimentary process understanding. Regarding formation are characterized by anomalous high pressure, therefore elastic parameters behavior in overpressured reservoir conditions should be taken into account. In this state acoustic impedance decreases within argillaceous rocks as well as in the reservoir. This feature makes geological interpretation of inversion results more complicated and ambiguous. According to analysis of Achimov formation at Vostochno-Messoyakhskoe field such a dramatic decrease of impedance down to reservoir values might be caused by decompaction in conjunction with gas presence in clay pores. To avoid misinterpretation of argillaceous formation as reservoir units, complex geological and geophysical analysis should be conducted including petro-elastic modelling and precise seismic and geological model with potential reservoir area determination.

References

1. Nezhdanov A.A., Ponomarev V.A., Gorbunov S.A., Turenkov N.A., Geologiya i neftegazonosnost’ achimovskoy tolshchi Zapadnoy Sibiri (Geology and oil and gas content of the Achimov strata of Western Siberia), Moscow: Publ. of Academy of Mining Sciences, 2000, 247 p.

2. Baraboshkin E.Yu., Prakticheskaya sedimentologiya. Terrigennye rezervuary. Posobie po rabote s kernom (Practical sedimentology. Terrigenous reservoirs. On how to operate core samples), Tver: GERS Publ., 2011, 152 p.

The article presents the results of long-time monitoring (more 2 years) for production horizontal wells with multistage hydraulic fracturing and for vertical wells with hydraulic fracturing at the pilot project of Achimov deposits development. The aim of the study was to estimate reservoir properties, reservoir pressure, productivity, as well as to analyze pattern efficiency on pilot project of Achimov deposits. The initial data of well test, daily production rates of liquid and oil, bottom-hole pressure were used. In addition, the authors used well log interpretation results and PVT-properties. The article presents an assessment of reservoir and near wellbore parameters, such as permeability, skin-factor, fracture half-length, radius of drainage and reservoir pressure. These parameters were interpreted according to three scenarios: minimum (min case), basic (base case), and maximum (max case). Radius of drainage helped to perform interference analysis. The article describes an approach to analytical estimation of water injection system efficiency based on well test models qualitatively and quantitative. Fluid dynamics parameters from well test help history match and generation of dynamic models. Interference analysis of production and injection wells allow to design/optimize oil-field exploitation system, prove wells spacing and the distances between them. At the same time, a quantitative assessment of water injection system increases accuracy of cost estimates.

References

1. Achimovskie gorizonty – sovmestnyy spetsproekt “Gazprom neft’” i Neftegaz.RU (The Achimov horizons are a joint special project of Gazprom Neft and Neftegaz.RU), URL: https://achimovka.neftegaz.ru/

2. Deeva T.A., Kamartdinov M.R., Kulagina T.E., Mangazeev P.V., Gidrodinamicheskie issledovaniya skvazhin: analiz i interpretatsiya dannykh (Well test: analysis and interpretation of data), Tomsk: Publ. of TPU, 2009, 340 p.

3. Ipatov A.I., Kremenetskiy M.I., The longterm monitoring of resevoir data as significant direction of contemporary welltest analysis development (In Russ.), Inzhenernaya praktika, 2012, no. 9, pp. 4–8.

4. Viturat D., Houzé O., Fjaere O.S., The theory and practice of pressure transient and production analysis & The use of data from permanent downhole gauges,

URL: https://www.kappaeng.com/documents/flip/dda51001/files/assets/basic-html/page-1.html

5. Davletbakova L.A., Shuvaev D.V., Klimov V.Yu., Usefulness of well test made in different time. Monitoring injection wells hydraulic fracture dynamics in low-permeability reservoirs by PLT and PTA (In Russ.), PRONEFT. Professionally about oil = PRONEFT’’. Professional’no o nefti, 2023, no. 8(2), pp. 58-67.

The correct well testing data interpretation is of particular interest in case of injection wells with the induced fractures (waterflooding fractures) that occur due to the high injection pressure. Standard software used for the well testing simulation does not have the functionality to model filtration processes with hydraulic fractures of varying geometry and conductivity. The coupled hydrogeomechanical model accounting the waterflooding fractures is used in this work for the interpretation of field experiment data. The well test is simulated in two selected areas of oil fields with wells oriented along maximum region stress. In the first case, one vertical injection well surrounded by production wells is considered. In the second one, the sector of the field development system is treated. The sector includes two horizontal injection wells with multi-stage hydrofracturing and production wells located nearby. It is shown that in the both cases the model pressure curves are in an acceptable agreement with the field data. The comparison of the field data with the results of the standard well test modeling shows that the discrepancy occurs when the fracture length changes. In the case of the sector of field development system, the model is able to simulate the performance of two injection wells simultaneously. Numerical calculations expose the possibility of main fracture growth between two injection wells. During the pressure falloff test, the fractures close quickly due to the large leaks into the formation. When the injection is resumed, the waterflooding fractures grow rapidly and merge into the main fracture. The fracture propagation rate is used to improve the multiphase hydrodynamic model. The hydrodynamic simulations demonstrate the possible positive impact of the waterflooding fracturing on the economic performance of the development system by reducing the number of injection wells.

References

1. Davletbaev A., Asalkhuzina G., Ivaschenko D. et al., Methods of research for the development of spontaneous growth of induced fractures during flooding in low permeability reservoirs (In Russ.), SPE-176562-MS, 2015, DOI: https://doi.org/10.2118/176562-MS

2. Kalinin S.A., Baykin A.N., Abdullin R.F. et al., Modeling and analysis of hydraulic fractures coalescence during waterflooding in a direct line drive pattern (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2022, no. 12, pp. 40–45, DOI: https://doi.org/10.24887/0028-2448-2022-12-40-45

3. Baykin A.N., Abdullin R.F., Dontsov E.V., Golovin S.V., Two-dimensional models for waterflooding induced hydraulic fracture accounting for the poroelastic effects on a reservoir scale, Geoenergy Sci. Eng., 2023, V. 224, Article no. 211600, DOI: https://doi.org/10.1016/j.geoen.2023.211600

4. Coussy O., Poromechanics, Chichester: J.Wiley& Sons Ltd, 2004, 360 p., DOI: https://doi.org/10.1002/0470092718

5. Dontsov E., Peirce A.P., Comparison of toughness propagation criteria for blade-like and pseudo-3D hydraulic fractures, Eng. Fract. Mech., 2016, V. 160, pp. 238–247, DOI: https://doi.org/10.1016/j.engfracmech.2016.04.023

6. Kremenetskiy M.I., Ipatov A.I., Gidrodinamicheskie i promyslovo-tekhnologicheskie issledovaniya skvazhin (Hydrodynamic and oil field and technological research of wells), Moscow: MAKS Press Publ., 2008, 476 p.

7. Hecht F., New development in FreeFem++, J. Num. Math. Vol., 2012, V. 20, no. 3– 4, pp. 251–266.

In the oil and gas industry in the process of field development it is an urgent task to create PVT models capable of describing changes in reservoir fluids in such nodes as reservoir, well and surface gathering and transport network. The cost of error in the PVT model is very high and at facilities with different types of oil, the planned NPV for the year may not reach the economic limit of 0.5-2.9%. Therefore, it is important to reproduce the properties of hydrocarbon mixtures reliably already at the early stages of field development. The use of high-quality PVT models early in field development will also reduce the cost of additional fluid testing and analysis, as the models can provide sufficiently accurate data for decision making. A characteristic feature of new assets is the lack of laboratory fluid results required for PVT modelling. In such cases, the value from such oil and gas projects carries a high degree of uncertainty, and the process of making important strategic decisions takes a long time. To solve this problem it is proposed to implement a completely new approach in the selection of PVT model analogues and operational creation of PVT model of Black Oil using machine learning algorithms, as well as the creation of a unified database of created PVT metamodels. This approach will allow the engineer to solve the problem with PVT section in the reservoir simulation model in an operative mode and at the same time retain a high degree of its predictive ability.

References

1. Serebryakova D.А., Margarit A.S., Technology development PVT simulations in the Upstream Division of Gazprom Neft Company (In Russ.), PROнефть. Профессионально о нефти = Professionally about Oil, 2018, no. 3, pp. 75–77.

2. Pechko K., Afanasyev A., Brovin N. et al., Application of machine learning in integrated modeling of the oil and gas fields, Proceedings of 3rd EAGE Digitalization Conference and Exhibition, European Association of Geoscientists & Engineers, 2023, pp. 1–4.

3. Brusilovskiy A.I., Fazovye prevrashcheniya pri razrabotke mestorozhdeniy nefti i gaza (Phase transformations in the development of oil and gas fields), Moscow: Graal’ Publ., 2002, 575 p.

4. Yushchenko T.S., Brusilovsky A.I., A step-by-step approach to creating and tuning PVT-models of reservoir hydrocarbon systems based on the state equation (In Russ.), Georesursy = Georesources, 2022, 24(3), pp. 164–181, DOI: https://doi.org/10.18599/grs.2022.3.14

5. Whitson C.H., Brule M.R., Phase behavior, SPE Monograph, V. 20, Rechardson, Texas, 2000, 233 p.

The article presents a methodology for predicting the behavior of the pressure build-up curve and estimating reservoir pressure for the case of a short-term well stop. Their duration is not enough to measure a build-up curve long enough and its subsequent full interpretation. A regression analysis method was used in order to identify the most accurately predictive behavior of the pressure buildup curve during a real well test based on various models tested on real well operating data. A C# programming language script was written to optimize the calculation of regression coefficients. Testing and application of the methodology was carried out at the wells of the field named after A. Zhagrin of Gazpromneft-Khantos LLC. A new approach has been obtained for predicting pressure build-up and estimating reservoir pressure, which allows increasing the coverage of wells by testing without conducting additional long-term well testing and, accordingly, losses in production. The proposed approach does not exclude long-term stops of wells to pressure build-up, but allows to understand the energy state of the reservoir in operational activities, as a result, to improve the quality of the decisions made in the process of field development. The results of the algorithm allow us to conclude the effectiveness of the proposed solution and show the importance of these technological stops in understanding the dynamics of reservoir pressure. The advantages of the developed approach are the possibility of implementation in Digital Oil Field monitoring tools, ease of program realization and integration into existing software tools. The accuracy of prediction depends on the quality of input data describing the properties of the reservoir or regions with similar field conditions.

References

1. Kremenetskiy M.I., Ipatov A.I., Gidrodinamicheskie i promyslovo-tekhnologicheskie issledovaniya skvazhin (Hydrodynamic and oil field and technological research of wells), Moscow: MAKS Press Publ., 2008, 476 p.

2. Ipatov A.I., Kremenetskiy M.I., Geofizicheskiy i gidrodinamicheskiy kontrol’ razrabotki mestorozhdeniy uglevodorodov (Geophysical and hydrodynamic control of development of hydrocarbon deposits), Moscow – Izhevsk: Regular and Chaotic Dynamics Publ., 2005, 780 p.

3. Shagiev R.G., Issledovanie skvazhin po KVD (Well testing), Moscow: Nauka Publ., 1998, 304 p.

4. Chernov B.S., Bazlov M.N., Zhukov A.I., Gidrodinamicheskie metody issledovaniya skvazhin i plastov (Well testing), Moscow: Gostoptekhizdat Publ., 1960, 319 p.

Chemical enhanced oil recovery (EOR) methods are becoming increasingly widespread, but the effectiveness of using oil-displacing compositions is characterized by a large amount of uncertainties that must be addressed. In this work, the effectiveness of three reagents for surfactant-polymer (SP) flooding were assessed. The assessment was carried out in two stages. The first one is laboratory research. At this stage the oil-displacing solution is selected in accordance with the geo-physical parameters of the field such as flow properties, reservoir fluids, reservoir temperature. Complex laboratory studies include special core analysis and filtration tests. During the laboratory stage design with the best performance was identified. The second stage is the flow simulation stage. During this stage the filtration tests were simulated in the model with following rescaling and evaluation of the effect on a full-scale 3D flow model. For flow modeling of chemical EOR, a number of necessary laboratory data and parameters are proposed, which are the following: dependence of interfacial tension in oil-water system on surfactant concentration, isotherm of dynamic adsorption for surfactants, residual oil saturation decrement, displacement coefficient increment, residual resistance factor. Linear dimensions of core samples, filtration-capacitance properties, and relative phase permeability endpoints were used as additional parameters during the model adaptation. 3D model estimated the increase in oil recovery factor as 19% when SP flooding implemented after waterflooding. The most performing SP composition is recommended for single well chemical tracer test and for pilot testing.

References

1. Sholidodov M.R., Kozlov V.V., Altunina L.K., Chernova U.V., Laboratory testing of acid oil-displacing composition to enhance oil recovery (In Russ.), Interekspo Geo-Sibir', 2021, V. 2, no. 1, pp. 301-306, DOI: https://doi.org/10.33764/2618-981x-2021-2-1-301-306

2. Silin M.A., Magadova L.A., Davletshina L.F. et al., Application experience and major trends in polymer flooding technology worldwide (In Russ.), Territoriya Neftegaz, 2021, no. 9-10, pp. 46-52.

3. Kamal M.S., Hussein I.A., Sultan A.S., Review on surfactant flooding: Phase behavior, retention, IFT, and field applications, Energy & Fuels, 2017, V. 31(8), pp. 7701-7720, DOI: https://doi.org/10.1021/acs.energyfuels.7b00353

4. Druetta P., Picchioni F., Surfactant-polymer interactions in a combined enhanced oil recovery flooding, Energies, 2020, V. 13(24), Article No. 6520,

DOI: https://doi.org/10.3390/en13246520

5. Douarche F., Rousseau D., Bazin B. et al., Modeling chemical EOR processes: some illustrations from lab to reservoir scale, Oil Gas Sci. Technol., 2012, V. 67, no. 6, pp. 983-997, DOI: https://doi.org/10.2516/ogst/2012059

6. Ilyasov I., Koltsov I., Golub P. et al., Polymer retention determination in porous media for polymer flooding in unconsolidated reservoir, Polymers, 2021, V. 13(16), Article No. 2737, DOI: https://doi.org/10.3390/polym13162737

7. Melo M.A., Almeida A.R., Determining the sweep efficiency of waterflooding using tracers, SPE-184956-MS, 2017, DOI: https://doi.org/10.2118/184956-MS

8. Barati-Harooni A., Najafi-Marghmaleki A., Tatar A., Mohammadi A.H., Experimental and modeling studies on adsorption of a nonionic surfactant on sandstone minerals in enhanced oil recovery process with surfactant flooding, Journal of Molecular Liquids, 2016, V. 220, pp. 1022-1032, DOI: https://doi.org/10.1016/j.molliq.2016.04.090

9. Budhathoki M., Barnee S.H.R., Shiau B.-J., Harwell J.H., Improved oil recovery by reducing surfactant adsorption with polyelectrolyte in high saline brine, Colloids and Surfaces A : Physicochemical and Engineering Aspects, 2016, no. 498, pp. 66-73, DOI: https://doi.org/10.1016/j.colsurfa.2016.03.012.

10. Ahmadi Y., Mohammadi M., Sedighi M., Chapter 1. Introduction to chemical enhanced oil recovery, In: Enhanced Oil Recovery Series. Chemical Methods, Gulf Professional Publishing, 2022, pp. 1-32. – https://doi.org/10.1016/B978-0-12-821931-7.00002-X

The primary method for production Achimov tight-oil reserves is hydraulic fracturing. The high efficiency of the hydraulic fracturing fluid, as observed in actual field operations on these reserves, contributes to the development of fractures in the vertical plane. Proppant is distributed along this plane, and the anchored width tends to form a "monolayer" throughout the fracture volume. Considering that there are studies in the global experience on the proppant failure dependency on the layers number in the pack, as well as previously obtained theoretical dependencies by the authors, it can be assumed that fractures with proppant width close to a "monolayer" will not lead to achieving economically viable well productivity under the the research object geomechanical conditions. The proppant will break, the broken particles will be pressed into the rock formation, and the fractures will "collapse." To confirm the theoretical research and industry experience presented earlier, our own modified laboratory program studies has been conducted. This program allows addressing the deficiencies of the standard method for investigating proppant crush resistance to reproduce the actual width of the hydraulic fracture. The study involves a series of tests on the crushing of proppant with variable height in a cell for crush testing. The results confirm that the critical onset of crushability is at three layers of proppant. Proppant with smaller dimensions better resists crushing. The use of high-strength proppants in the shell is advisable for the application in Achimov tight-oil reserves. Qualitative photo control of crushed particles confirms that only a limited amount of proppant is subjected to external load regardless of changes.

New challenges, including the wide access of Russian oil and gas companies to complex geological objects with hard-to-recover reserves, required more active use of various kinds of technological complications and innovations in oil production. First of all, this applies to the construction of horizontal and multi-barrel wells, to downhole completion systems, including methods of multistage hydraulic fracturing. To control the development of deposits and monitor the operation of such reservoir, it also required the development and implementation of new well monitoring systems. Currently, many domestic oil and gas companies use variations of stationary information and measurement systems for long-term permanent study of the phase profiles of inflow and pick-up. Among these technological solutions, the most common in Russia are: a) distributed monitoring systems based on submersible fiber optic cable sensors (with registration of thermal DTS, and sometimes optionally also acoustic DAS characteristics of the inflow), and b) point-distributed marker monitoring systems (mainly using cameras-cassettes with a marker substance in the intervals of fluid inflow from isolated stages of horizontal wells or using a marker coating injected with proppant). Both of these methods are quite competitive at first glance: both in terms of mobility and the cost of their use. However, the cornerstone point in their application is how much information on the distributed profiles of component–by-component tributaries can be trusted. Usually, in order to answer this question, oil and gas companies are forced to supplement stationary monitoring with one-time measurements of the traditional complex of methods of production logging tools (PLT). To solve this problem Gazprom Neft PJSC conducted unique comparative "blind" tests on a ground-based multiphase hydraulic stand for commercial marker monitoring systems. The main results of the tests performed are presented in the article.

References

1. Kremenetskiy M.I., Ipatov A.I., Primenenie promyslovo-geofizicheskogo kontrolya dlya optimizatsii razrabotki mestorozhdeniy nefti i gaza (Application of field geophysical control to optimize the development of oil and gas fields), Part II. Rol' gidrodinamiko-geofizicheskogo monitoringa v upravlenii razrabotkoy (Role of hydrodynamic and geophysical monitoring in development management), Moscow - Izhevsk: Publ. of Institute of Computer Science, 2020, 756 p.

2. Ipatov A.I., Malyavko E.A., What happens to inflow profiles after development of horizontal wells (In Russ.), Neftegazovaya vertikal', 2022, no. 6, pp. 88–97.

3. Kayukov D.Yu., Testing of tracer monitoring systems of horizontal wells on a multiphase metrological test bench (In Russ.), Aktual'nye problemy nefti i gaza, 2023, no. 2(41), pp. 173–183, DOI: https://doi.org/10.29222/ipng.2078-5712.2023-41.art11

Long-term distributed fiber optic monitoring of temperature (DTS) and acoustic (DAS) parameters in horizontal wells has been used for some time in the industry. However, wells for permanent fiber optic monitoring were previously either naturally flowing oil and gas wells, or injection wells. It is obvious that distributed monitoring technology is of the greatest interest for wells with the electrical submersible pumps (ESP), but there have always been issues with the RIH operation of fiber-optic cable sensors to the toe of the horizontal well beyond the ESP. Having passed the path from the pilot jobs to a couple of dozens of DTS installations in horizontal wells in recent years, Gazprom Neft have mastered this innovative technology for the first time in Russia, in modifications with both DTS and DAS. Distributed fiber optic based permanent monitoring of multi-stage hydraulically fractured horizontal wells with the ESP has now been successfully implemented at the Yuzhno-Priobskoye oil field. In 2022 and 2023, the Company equipped two operational pumping wells with a fiber-optic monitoring system, and the duration of monitoring for one of them exceeded one year. Also, engineers radically improved the technology of interpretation and analysis of the received data, which made it possible to abandon the services of a third-party service and significantly reduce the cost of technological processes. Currently, the DTS of long-term permanent monitoring is prepared for a massive implementation at other Gazprom Neft business units, and the obtained information is recognized as in demand for optimizing the development system of low-permeable reservoirs. Below, the authors present some results illustrating the uniqueness and at the same time the universality of the information support of DTS monitoring in order to substantiate workovers on the production wells with multistage horizontal completion.

References

1. Asmandiyarov R.N., Ipatov A.I., Yazkov A.V.et al., Gazprom Neft's experience in testing commercial marker monitoring systems for oil wells and in assessing their reliability (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2023, No. 12, pp. 53-57, DOI: https://doi.org/10.24887/0028-2448-2023-12-53-57

2. Ipatov A.I., Kremenetskiy M.I., Kaeshkov I.S. et al., Undiscovered DTS potential of horizontal well inflow profile monitoring (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2014, no. 5, pp. 96–100.

3. Ipatov A.I., Kremenetskiy M.I., Kaeshkov I.S., Buyanov A.V., Horizontal well production monitoring with distributed temperature sensor (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2016, no. 12, pp. 69–71.

4. Ipatov A.I., Kremenetskiy M.I., Kaeshkov I.V. et al., Experience in the effective monitoring of a flowing horizontal oil well by distributed optic fiber temperature measurements (In Russ.), Karotazhnik, 2017, no. 8(278), pp. 34–50.

5. Ipatov A.I., Kremenetskiy M.I., Kleshkov I.S., Experience in the application of distributed fiber optic thermometry for monitoring wells in the company Gazprom Neft (In Russ.), PRONEFTʹ. Professionalʹno o nefti, 2017, no. 3, pp. 55–64.

6. Ipatov A.I., Andrianovskiy A.V., Voronkevich A.V. et al., Study of seismoacoustic effects in an producing oil horizontal well based on a fiber-optic cable sensor DAS (In Russ.), PROneft'. Professional'no o nefti, 2021, no. 2, pp. 50–57, DOI: https://doi.org/10.51890/2587-7399-2021-6-2-50-57

7. Ipatov A.I., Kremenetskiy M.I., Kaeshkov I.V. et al., Horizontal wellbore production profile evaluation by distributed fiber-optic temperature surveillance (In Russ.), PROneft'. Professional'no o nefti, 2021, no. 4, pp. 81–91, DOI: https://doi.org/10.51890/2587-7399-2021-6-4-81-91

8. Ipatov A.I., Kremenetskiy M.I., Andrianovskiy A.V. et al., Digital solutions for field development surveillance based on permanent distributed fiber-optic systems (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2022, no. 3, pp. 54–60, DOI: https://doi.org/10.24887/0028-2448-2022-3-54-60

9. Kremenetskiy M.I., Ipatov A.I., Primenenie promyslovo-geofizicheskogo kontrolya dlya optimizatsii razrabotki mestorozhdeniy nefti i gaza (Application of field geophysical control to optimize the development of oil and gas fields), Part II. Rol' gidrodinamiko-geofizicheskogo monitoringa v upravlenii razrabotkoy (Role of hydrodynamic and geophysical monitoring in development management), Moscow - Izhevsk: Publ. of Institute of Computer Science, 2020, 756 p.

10. Patent RU 2702042 C1. Method of quantitative assessment of inflow profile in low- and medium-rate horizontal oil wells with MHFR, Inventors: Ipatov A.I., Kremenetskiy M.I., Lazutkin D.M.

11. Patent RU 2703055 C1. System for long-term distributed monitoring of the inflow profile in a horizontal well equipped with an ECP, Inventors: Yakovlev A.A., Suleymanov A.G., Fayzullin I.G., Ipatov A.I., Kremenetskiy M.I., Shurunov A.V., Sarapulov N.P., Simakov S.M.

12. Fischer P.A., Monodiameter wells continue to expand possibilities, Word Oil, 2006, July, URL: https://www.worldoil.com/magazine/2006/july-2006/special-focus/monodiameter-wells-continue-to-expand-possibilities/

In case of the weakly consolidated formations the oil production is often accompanied by the sand production and the pouring of the horizontal part of the well, which leads to the drop in the productivity coefficient during the operation of wells. One of the methods for preventing the sand production is the treatment of borehole rocks with chemical reagents. However, the methods of calculating the volume of injection of the reagent into the bottom-hole zone of the formation used by technology suppliers are part of commercial information and do not allow comparing the effectiveness of different formulations. In this regard, a method was developed for calculating the volume of injection of chemical reagents. This methodology is based on a mathematical model of reservoir operation using the results of physico-chemical properties of the reagent, filtration and geomechanical studies of cores before and after exposure to the reagent. Calculations according to the proposed model require data obtained from lab experiments. During lab experiments it is required to measure physical and chemical characteristics of consolidation liquid, evaluate porosity and permeability of the core, as well as the strength characteristics, before and after treatment of the core with the consolidation liquid. Later, acquired data is used as an input in the developed mathematical model. The model can be used to evaluate the amount of sand produced depending on the volume of the consolidation liquid. By varying the volume of the consolidation liquid in the model, the optimal volume of the liquid can be estimated. The optimal volume should be chosen depending on the two factors: the increase of the volume of consolidation liquid causes decrease in fluid production, as well as in sand production. Is some cases it is possible to achieve a significant decrease in sand production, while a very small decrease in fluid production is observed.

References

1. Rahmati H., Jafarpour M., Azadbakht S. et al., Review of sand production prediction models, Journal of Petroleum Engineering, V. 2013, Article ID 864981,

DOI: https://doi.org/10.1155/2013/864981

2. Lezhnev K., Timofeeva T., Biluta M., Practical Application of geomechanics for critical depression estimation in sand control problem. Case study for Kikinda oilfield, SPE-187825-MS, 2017, DOI: https://doi.org/10.2118/187825-MS

3. Tananykhin D.S., Petukhov A.V., Shagiakhmetov A.M., Chemical consolidation of friable sandstones in operating wells of an underground gas storage (In Russ.), Zapiski Gornogo instituta, 2013, V. 206, pp. 107–111.

4. Podoprigora D.G., Korobov G.Y., Bondarenko A.V., Acid stimulation technology for wells drilled the low-permeable high-temperature terrigenous reservoirs with high carbonate content, International Journal of Civil Engineering and Technology, 2019, V. 10, Issue 01, pp. 2680–2696.

5. Podoprigora D., Byazrov R., Sytnik J., The comprehensive overview of large-volume surfactant slugs injection for enhancing oil recovery: Status and the outlook, Energies, 2022, V. 15(21), Article No. 8300, DOI: https://doi.org/10.3390/en15218300

6. Mardashov D.V., Bondarenko A.V., Raupov I.R., Technique for calculating technological parameters of non-Newtonian liquids injection into oil well during workover (In Russ.), Zapiski Gornogo instituta, 2022, V. 258, pp. 881-894, DOI: https://doi.org/10.31897/pmi.2022.16

7. Raupov I., Burkhanov R., Lutfullin A. et al., Experience in the application of hydrocarbon optical studies in oil field development, Energies, 2022, V. 15(10), Article No. 3626, DOI: https://doi.org/10.3390/en15103626

8. Tananykhin D., Grigorev M., Korolev M. et al., Experimental evaluation of the multiphase flow effect on sand production process: prepack sand retention testing results, Energies, 2022, V. 15(13), Article No. 4657, DOI: https://doi.org/10.3390/en15134657

9. Bondarenko V.A., Savenok O.V., Research of methods and technologies management of complications, due to sand control (In Russ.), Gornyy informatsionno-analiticheskiy byulleten’, 2014, no. S5-1, pp. 3-27.

10. Fjaer E., Holt R.M., Horsund P. et al., Petroleum related rock mechanics, Elsevier, 2008, 514 p.

11. Van den Hoek P.J., Geilikman M.B., Prediction of sand production rate in oil and gas reservoirs, SPE-84496-MS. 2003, DOI: https://doi.org/10.2118/84496-MS

12. Lezhnev K., Roshchektaev A., Pashkin V., Coupled reservoir - Well model of sand production processes (In Russ.), SPE-196883-MS, 2019, DOI: https://doi.org/10.2118/196883-MS

13. Wang J., Walters D., Wan R., Settari A., Prediction of volumetric sand production and wellbore stability analysis of a well at different completion schemes, The 40th U.S. Symposium on Rock Mechanics (USRMS), Anchorage, Alaska, USA, 05-842 ARMA Conference Paper, 2005.

14. Climent N., Arroyo M., O’Sullivan C., Gens A., Sand production simulation coupling CFD with DEM, European Journal of Environmental and Civil Engineering, 2014,

V. 18, Issue 9, pp. 983-1008, DOI: https://doi.org/10.1080/19648189.2014.920280

15. Khasanov M.M., Lezhnev K.E., Pashkin V.D., Roshchektaev A.P., Application of the new multi-component suspension model for skin-factor evaluating on the wells equipped with gravel packs (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2018, no. 12, pp. 63-67, DOI: https://doi.org/10.24887/0028-2448-2018-12-63-67

The article analyzes the chemical composition of reservoir water of oil and gas fields and compares it with the composition of other sources of hydromineral lithium-containing raw materials such as salar brines and geothermal waters. It has been shown that the anion composition of lithium-containing reservoir water is determined by chloride ions, the cation composition by sodium, potassium, calcium, and magnesium ions. At the same time, the content of magnesium and calcium, which can lead to problems with the selectivity of lithium release and salt deposition, in contrast to salar brines, can reach quite high values. Promising provinces for extracting lithium from reservoir water of oil and gas fields in the Russian Federation are Central Siberian and South Ural. At the same time, lithium-bearing brines from deposits in the Central Siberian province have an extremely difficult composition for lithium extraction (high concentrations of magnesium and total mineralization), which results in the need to combine several methods for lithium extraction and, probably, refinement of existing technical solutions. Currently, sorption and extraction methods for extracting lithium from hydromineral raw materials have been developed in the Russian Federation. The selectivity of the process of lithium isolation by sorption methods is due to the steric effect; the interaction occurs through the intercalation mechanism. In this regard, one can expect the sensitivity of this method to the content of magnesium in the raw material, which has a similar ionic radius to lithium. In extraction methods, the selectivity of lithium separation is determined to a greater extent by the charge characteristics and chemical nature of the ion, rather than by its size. As a result, these methods are less sensitive to alkaline earth metal content.

References

1. Dry M., Extraction of lithium from brine – Old and new chemistry, In: Extraction 2018. The Minerals, Metals & Materials Series: edited by Davis B.R. et al., Springer, Cham., 2018, DOI: https://doi.org/10.1007/978-3-319-95022-8_187

2. Duyvesteyn W.P.C., Recovery of base metals from geothermal brines, Geothermics, 1992, V. 21, Issue 5–6, pp. 773–779, DOI: https://doi.org/10.1016/0375-6505(92)90030-D

3. Steinmetz R.L.L., Salvi S., Brine grades in Andean salars: When basin size matters. A review of the Lithium Triangle, Earth-Science Reviews, 2021, V. 217, Article no. 103615, DOI: https://doi.org/10.1016/j.earscirev.2021.103615

4. Dresel P.E., Rose A.W., Chemistry and origin of oil and gas well brines in Western Pennsylvania, 4th ser. Open-File Report OFOG 10–01.0, Harrisburg: Pennsylvania Geological Survey, 2010, 48 p.

5. Ryabtsev A.D., Hydromineral raw materials - an inexhaustible source of lithium in the 21st century (In Russ.), Izvestiya Tomskogo politekhnicheskogo universiteta, 2004, T. 307, №7, pp. 64–68.

6. Knapik E., Rotko G., Marszałek M., Recovery of lithium from oilfield brines-Current achievements and future perspectives: A mini review, Energies, 2023, V. 16, Article no. 6628, DOI: https://doi.org/10.3390/en16186628

7. Larichev V.V., Popkov V.I., Hydromineral resources of hydrocarbon deposits (In Russ.), Geologiya, geofizika i razrabotka neftyanykh i gazovykh mestorozhdeniy, 2009, no. 12, pp. 20-26.

8. Warren I., Techno-economic analysis of lithium extraction from geothermal brines, Technical Report NREL/TP-5700-79178, Golden, CO: National Renewable Energy Laboratory, 2021, URL: https://www.nrel.gov/docs/fy21osti/799178.pdf

9. Nicolaci H., Young P., Snowdon N. et al., Global metals & mining: Direct lithium extraction – A potential game changing technology. Equity Research, Goldman Sachs Group Inc, 2023, URL: https://www.goldmansachs.com/intelligence/pages/gs-research/direct-lithium-extraction/report.pdf

10. Tsivadze A.Yu., Baulin V.E., Kostikova G.V., Bezdomnikov A.A., Selective extraction of lithium from mineral, hydromineral and secondary raw materials (In Russ.), Vestnik RAN = Herald of the Russian Academy of Sciences, 2023, V. 93, no. 7, pp. 623–630.

11. Kuz'menko P.S., Chmerev V.S., Mikheeva E.D., Conditions of formation and patterns of distribution of lithium-bearing brines on the territory of the Russian Federation (In Russ.), Razvedka i okhrana nedr, 2023, no. 7, pp. 33–46, DOI: https://doi.org/10.53085/0034-026X_2023_07_33

12. Mityusheva T.P., Amosova O.E., Sravnitel'nyy analiz soderzhaniy tsennykh komponentov v promyshlennykh vodakh Khoreyverskoy vpadiny (Comparative analysis of the content of valuable components in the industrial waters of the Khoreyver depression), Collected papers “Geologiya i mineral'nye resursy Evropeyskogo Severo-Vostoka Rossii” (Geology and mineral resources of the European North-East of Russia), Proceedings of XVII Geological Congress of the Komi Republic, 16-18 April 2019, Syktyvkar, 2019, V. 3, pp. S. 219–222.

13. Tseplyaev I.I., Medvedev A.R., Kasperovich D.A., Savinovskiy D.A., Recovery of lithium from associated waters during oil preparation at the fields of Eastern Siberia (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2023, no. 8, pp. 114–117, DOI: https://doi. org/10.24887/0028-2448-2023-8-114-117

14. Klyucharev D.S., Mikheeva E.D., On the grade of lithium and by-products in lithium-bearing industrial grounwaters of potentially perspective territories of Russia (In Russ.), Razvedka i okhrana nedr, 2020, no. 4, pp. 53–60.

The maintenance of static equipment is conditional on accuracy, sufficiency and up-to-dateness of information which is used to make qualitative conclusions about the technical condition and residual life of a production unit. The effectiveness of maintenance measures, on the one hand, depends on regulatory requirements, and on the other hand, on the human factor. Significant costs are normally expected. The installation of advanced telemetry systems for static equipment units of relatively low cost and criticality is often not economically reasonable. Moreover, some pieces of acquired information are not applied advantageously. The article presents a solution to effective data acquisition via hybrid modelling to collect additional information on technical condition and residual life. This method is illustrated on 50 units of field tanks storing oil and produced water. The proposed approach fully complies with the regulatory documentation of the Russian Federation and involves the joint use of three main models: 1) stress-strain state, 2) defect growth accounting, and 3) defect prediction model. The approach is universal; its application is possible for various types of static equipment. The article presents, firstly, particularities of raw data processing modelling; secondly, training of cross-functional neural network stress-strain state models; thirdly, formation of a defect prediction model based on general recommended practice; and lastly, development of a machine learning model for defect prediction. There are also results of verification process of a model which was applied on tanks that have been in operation since 1980s. Considering the complexity of this model, verification was carried out separately for each individual type of the hybrid model. Validation of the model and feedback from operating organizations confirmed the prospect of using the developed hybrid model as part of a recommendation system for more thorough control of the weakest units; more accurate assessment of the technical condition and residual life of a unit (taking into account probable defects); assessing the risks of negative developments and planning budgets for various types of diagnostics and maintenance.

References

1. Golikov A.V., Slozhenkin G.E., Overview of types and analysis of the causes of defects and damages in the bearing structures of steel tanks (In Russ.), Vestnik Volgogradskogo gosudarstvennogo arkhitekturno-stroitel’nogo universiteta. Ser. Stroitel’stvo i arkhitektura, 2021, no. 4(85), pp. 14–28.

2. Smolyago G.A., Frolov N.V., Applied method for predicting corrosion damages and remaining resource of bendable reinforced concrete elements taking into account operating experience of similar projects (In Russ.), Vestnik Belgorodskogo gosudarstvennogo tekhnologicheskogo universiteta im. V.G. Shukhova = Bulletin of Belgorod State Technological University named after. V. G. Shukhov, 2019, no. 2, pp. 49–54, DOI: https://doi.org/10.12737/article_5c73fc0ef063c3.60645861

3. Gaysin E.Sh., Bakhtizin R.N., Gabdrakhmanova N.T., Frolov Yu.A., Mathematical model of estimation of the residual resource of vertical steel tanks (In Russ.), Problemy sbora, podgotovki i transporta nefti i nefteproduktov, 2017, no. 3(109), pp. 113-122.

4. Yumaguzin U.F., Bashirov M.G., Forecasting of equipment remaining life in the oil and gas industry (In Russ.), Fundamental’nye issledovaniya, 2014, no. 3–2, pp. 277–280.

The article considers the peculiarities of the material (chemical and mineral composition) and their influence on the nuclear-physical characteristics (effective atomic number, atomic mass, photoelectric absorption index and macroscopic capture section of thermal neutrons) of the solid phase of rocks on the example of the volcanogenic-sedimentary sequence of the northeastern framing of the Krasnoleninsky arch in East Siberian region. The nuclear physical characteristics of the rocks of the studied object vary over a wide range. As the effective atomic number and atomic mass increase, the photoelectric absorption index and macroscopic capture section of thermal neutrons increase. The authors revealed positive correlations of the photoelectric absorption index and the macroscopic section of thermal neutron capture of the solid phase of rocks with the content of iron, magnesium, potassium, titanium oxides, as well as with the content of minerals – potassium feldspars, chlorite, and siderite. Negative correlations were revealed with the content of silicon, sodium oxides, also with the content of minerals – quartz and albite. It has been shown that the effective atomic number increases from acidic volcanites to medium, basic, ultramafic differences. Transformed by secondary processes volcanites are characterized by increased values of nuclear-physical characteristics, due to higher concentration of clay, carbonate minerals and secondary potassium feldspar. The need to take into account the influence of the material composition of the solid phase of rocks when interpreting neutron logging by thermal logs is shown. The prospects of using pulsed neutron and litho-density logs in the sections of volcanogenic deposits are shown in order to find intervals promising for testing.

References

1. Korovina T.A., Kropotova E.P., Romanov E.A., Shadrina S.V., Geologiya i neftenasyshchenie v porodakh triasa Rogozhnikovskogo LU. Regional’nye seysmologicheskie i metodicheskie predposylki uvelicheniya resursnoy bazy nefti, gaza i kondensata, povyshenie izvlekaemosti nefti v Zapadno-Sibirskoy neftegazonosnoy provintsii (Geology and oil saturation in the Triassic rocks of the Rogozhnikovsky license area. Regional seismological and methodological prerequisites for increasing the resource base of oil, gas and condensate, increasing oil recoverability in the West Siberian oil and gas province), Collected papers “Sostoyanie, tendentsii i problemy razvitiya neftegazovogo potentsiala Zapadnoy Sibiri” (The state, trends and problems of the development of oil and gas potential of Western Siberia), Proceedings of mezhdunarodnoy akademicheskoy konferentsii, Tyumen, 11-13 October 2006, Ekaterinburg: Format Publ., 2006, pp. 138–142.

2. Kropotova E.P., Korovina T.A., Romanov E.A., Fedortsov I.V., Sostoyanie izuchennosti i sovremennye vzglyady na stroenie, sostav i perspektivy doyurskikh otlozheniy zapadnoy chasti Surgutskogo rayona (Rogozhnikovskiy litsenzionnyy uchastok) (The state of knowledge and modern views on the structure, composition and prospects of pre-Jurassic deposits of the western part of the Surgut region (Rogozhnikovsky license area)),Proceedings of IX scientific and practical conference “Puti realizatsii neftegazovogo potentsiala KhMAO” (Ways of realization of oil and gas potential of KhMAO), Ekaterinburg: IzdatNaukaServis Publ., 2006, pp. 133–146.

3. Kropotova E.P., Korovina T.A., N Gil’manova.V., Shadrina S.V., Usloviya formirovaniya zalezhey uglevodorodov v doyurskikh otlozheniyakh na Rogozhnikovskom litsenzionnom uchastke (Conditions for the formation of hydrocarbon deposits in pre-Jurassic sediments at the Rogozhnikovsky license area), Proceedings of X scientific and practical conference “Puti realizatsii neftegazovogo potentsiala KhMAO” (Ways of realization of oil and gas potential of KhMAO), Khanty-Mansiysk 13–17 November 2007, Ekaterinburg: IzdatNaukaServis Publ., 2007, pp. 372–383.

4. Shadrina S.V., Kritskiy I.L., The formation of volcanogenic reservoir by hydrothermal fluid (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2012, no. 8, pp. 18–21.

5. Efimov V.A., The nuclear physics characteristic of volcanogenic rocks (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2006, no. 8, pp. 108–110.

6. Dobryden’ S.V., Increasing geological information of well logging in volcanogenic deposits (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2023, no. 6, pp. 24-28, DOI: http://doi.org/10.24887/0028-2448-2023-6-24-28

7. Filippov E.M., Prikladnaya yadernaya geofizika (Applied nuclear geophysics), Moscow: Publ of USSR AS, 1962, 580 p.

9. Srugoa P., Rubinstein P., Porosity and permeability in volcanic rocks: A case study on the Serie Tobifera, South Patagonia, Argentina, Journal of Volcanology and Geothermal Research, 2004, no. 132, pp. 31-43, DOI: http://doi.org/10.1016/S0377-0273(03)00419-0

8. Kondakov A.P., Efimov V.A., Dobryden’ S.V., Reservoirs identifying in the volcanogenic-sedimentary rocks of the northeast edge of Krasnoleninskiy arch based on logging, core study and well testing (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2020, no. 1, pp. 29-34, DOI: http://doi.org/10.24887/0028-2448-2020-1-29-34

10. Ladygin V.M., Frolova J.V., Rychagov S.N., The alteration of effusive rocks due to acidic leaching by shallow thermal waters, the Baranskii geothermal system, Iturup island, Journal of Volcanology and Seismology, 2014, no. 1, pp. 17-33, DOI: http://doi.org/10.1134/S0742046314010035

11. Frolova J.V., Chernov M.S., Sokolov V.N., Kuznetsov R.A., The influence of hydrothermal argillization on the physical and mechanical properties of tuffaceous rocks: a case study from the Upper Pauzhetsky thermal field, Kamchatka, Bulletin of Engineering Geology and the Environment, 2021, no. 2, pp. 1635-1651,

DOI: http://doi.org/10.1007/s10064-020-02007-2

The analysis was undertaken to unravel possible reasons of reservoirs separation in hydrocarbon accumulations. Separation zones are practically not recognized by direct evidence such as well correlation, or seismic data. Possible locations of such separation zones can be inferred only from the presence of a combination of indirect indicators including: multi-facies zones, contact of sedimentary bodies from different depositional source areas, zones of reduced net thickness or NTG, increased compartmentalization, continuity, lack of communication between injecting and producing wells, contradictory well test results, different hydrocarbon contacts. The paper considers main reasons of forming the zones of separated reservoirs, which can be associated with a junction of areas formed by different depositional centers, or with reduced NTG of sedimentary sequences separating major sand depositional features, with boundaries of facies where pore space structure may change, with capillary barriers. Separation of reservoirs in the same formation zone can also be confirmed by a different reservoir temperature (when excluding reservoir production effects), presence of faults including “rootless” faults such as, for instance, a clastic elongated dike filled with clastic material. Besides, influence can be exerted by geochemical processes, as well as by lithology change and porosity reduction at facies boundaries, or by interfacing with thin shale barriers. As a result of the analysis, the authors identified main reasons of reservoirs separation in hydrocarbon accumulations

References

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. Smirnova E.V., Azarova N.O., Utyashev Yu.N. et al., Problems solution of oil and gas deposits geometrization of the Aptian-Albian age in the north-east of the West Siberia (In Russ.), Geologiya, geofizika i razrabotka neftyanykh i gazovykh mestorozhdeniy, 2019, no. 8, pp. 4-10, DOI: https://doi.org/10.30713/2413-5011-2019-8(332)-4-10

3. Polishchuk A.V., Sidorov A.E., Nassonova N.V. et al., Conceptual sedimentation model as the basis of geological correlation in a case study of AT6-8 reservoirs of Beregovoye field in West Siberia (In Russ.), Izvestiya vysshikh uchebnykh zavedeniy. Neft’ i gaz, 2022, no. 3, pp. 23-37, DOI: https://doi.org/10.31660/0445-0108-2022-3-23-37

4. Nassonova N.V., Distanova L.R., Kalabin A.A., Devyatka N.P., Regional and local factors of cracking formation in clay-silicon deposits of the Nizhneberezovskaya subsuite (In Russ.), Geologiya, geofizika i razrabotka neftyanykh i gazovykh mestorozhdeniy, 2020, no. 1, pp. 19-25, DOI: https://doi.org/10.30713/2413-5011-2020-1(337)-19-25

5. Bol’shakov Yu.Ya., Dinamicheskoe modelirovanie zalezhey nefti i gaza: Kurs lektsiy (Dynamic modeling of oil and gas reservoirs: Course of lectures), Tyumen: Publ. of Tyumen State Oil and Gas University, 2003, 66 p.

6. Dahlberg E.C., Applied hydrodynamics in petroleum exploration, Springer-Verlag New York, Inc. 1995, 296 p.

7. Strakhov N.M., Osnovy teorii litogeneza (Basics of the theory of lithogenesis). Part 1. Tipy litogeneza i ikh razmeshchenie na poverkhnosti Zemli (Types of lithogenesis and their placement on the Earth’s surface), Moscow: Publ. of USSR AS, 1960, 212 p.

8. Danenberg E.E., Belozerov V.B., Brylina N.A., Geologicheskoe stroenie i neftegazonosnost’ verkhneyursko-nizhnemelovykh otlozheniy yugo-vostoka Zapadno-Sibirskoy plity (Tomskaya oblast’) (Geological structure and oil and gas potential of Upper Jurassic-Lower Cretaceous deposits in the southeast of the West Siberian plate (Tomsk region)), Tomsk: Publ. of TPU, 2006, 207 p.

9. Nedolivko N.M., Evolution of void-pore space in oil-water contact zones (In Russ.), Izvestiya Tomskogo politekhnicheskogo universiteta, 2010, V. 316, no. 1, pp. 99-107.

10. Zhukovskaya E.A., Vakulenko L.G., Yan P.A., Oksfordskiy konkretsienosnyy gorizont v osadochnykh basseynakh. Yurskaya sistema Rossii: problemy stratigrafii i paleogeografii (Oxford nodule horizon in sedimentary basins. Jurassic system of Russia: problems of stratigraphy and paleogeography), V All-Russian meeting: scientific materials, Ekaterinburg: IzdatNaukaServis Publ., 2013, 270 p.

The Kashirskian-Podolskian carbonate deposits are the overlying return horizon for many fields in the Republic of Bashkortostan. The rocks are characterized by a significant degree of dolomitization, sulfation and silicification. The void space is expressed by pores, micropores, caverns, and cracks of subordinate significance. The complex structure and geological heterogeneity make it difficult to assess the value of porosity and saturation. In order to increase the reliability of quantitative interpretation of neutron logging in sediments of a complex reservoir, additional core studies were required. The main goal of the additional research program was to assess the neutron-absorbing properties of the mineral components of the rock. Mineral component model taking into account anomalous microelements will allow to set up neutron methods for studying wells and estimate the magnitude of the error in determining the current saturation coefficient. To obtain additional information on the properties of the Kashirskian-Podolskian deposits, studies of the elemental composition of rocks were carried out using the X-ray fluorescence, inductively coupled plasma mass spectrometry, thermogravimetric method and pyrolysis. As a result of complex processing of the data array obtained by various methods of core research, mineral-component models were built to calculate the lifetime values and macroscopic absorption cross section of thermal neutrons. The resulting lithotype models and neutron constants will improve the accuracy of oil saturation assessment based on pulsed neutron methods. Square deviation of the random error of the result of an indirect measurement inaccuracy in the definition of “mineralogy” can lead to an error in saturation determination of up to 14%. The lower is the porosity coefficient, the higher is the error in calculating the saturation coefficient. For limestone the oil saturation will be overestimated, for dolomite rock it will be underestimated. When assessing the nature of saturation, one should not use a single boundary value of the neutron lifetime or capture cross section for all lithotypes, but a relationship between the neutron lifetime and the porosity and salinity of formation water adjusted on one’s own core.

References

1. Privalova O.R., Burikova T.V., Akchurin A.A. et al., Refinement of current oil saturation calculation technique by evaluation of neutron characteristics of the rock (In Russ.), Karotazhnik, 2018, no. 3(285), pp. 38-49.

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

3. Mirnov R.V., Alekseeva T.V., Paleosols in the Kashira deposits in the south of the East European Craton (Republic of Bashkortostan): characteristics, paleoecological and stratigraphic significance (In Russ.), Litosfera, 2022, V. 22, no. 5, pp. 694-704, DOI: https://doi.org/10.24930/1681-9004-2022-22-5-694-704

4. Kozhevnikov D.A., Neytronnye kharakteristiki gornykh porod i ikh ispol’zovanie v neftegazopromyslovoy geologii (Neutron characteristics of rocks and their use in oil and gas field geology), Moscow: Nedra Publ., 1982, 221 p.

5. Lawson C. L., Hanson R. J. Solving least squares problems, Prentice-Hall, 1974, 340 p.

6. Rezvanov R.A., Radioaktivnye i drugie neelektricheskie metody issledovaniya skvazhin (Radioactive and other non-electric methods of well survey), Moscow: Nedra Publ., 1982, 368 p.

7. MI 2083-90.Rekomendatsiya. Gosudarstvennaya sistema obespecheniya edinstva izmereniy. Izmereniya kosvennye. Opredelenie rezul’tatov izmereniy i otsenivanie ikh pogreshnostey (Recommendation. State system for ensuring the uniformity of measurements. Measurements are indirect. Determination of measurement results and estimation of their errors), Moscow: Izdatel’stvo standartov Publ., 1991, 11 p.

The characteristic of the geological and geochemical conditions of sedimentation of the main oil and gas strata in the section of the Perm region is given. A multivariate analysis of the geochemical characteristics of the DOM was carried out in the context of the hydrocarbon plays within the tectonic units of the platform and the Pre-Ural fore deep. Correlation interactions between the geochemical and bituminological characteristics of the DOM have been studied for each stratum. Using the scientific hypothesis of N.B. Vassoevich on the relationship between the bituminoid coefficient and the organic carbon content, the authors, using statistical analysis methods, for the first time, the division of the DOM into three main types – idiogenous, epigenetic and mixed has been justified at the quantitative level. The constructed linear regressive models and discriminant functions made it possible to justify the distribution of the DOM types in all sedimentary complexes of the Perm region. The patterns of distribution of the selected types of the DOM according to the to the difference in bituminological composition for all tectonic units of the Perm region are investigated. The lines have been established between the types of the DOM for all tectonic elements. The line between the idiogenous type of the DOM and the mixed type by bituminoid coefficient value is in the range of 15-18%, and between the mixed and epigenetic in the range of 28-32%. For the territories of the Bashkir arch and the Solikamsk sag, the values of TOC for mixed and epigenetic types of the DOM are less than 8%, and the main part of the idiogenous DOM is characterized by a concentration of TOC not exceeding 10%. The values of TOC concentrations for mixed and epigenetic DOM types in the context of the territory of the Yazva-Chusovaya structural zone do not exceed 2%. The main part of the idiogenous DOM is characterized by a concentration of TOC not exceeding 6%. The various processes of differentiation of the dispersed organic matter of the rocks of the main hydrocarbon plays for the territory of the platform and the fore deep are statistically substantiated. Based on the obtained percentage of types, a scheme of quantitative distribution of migrationally capable epigenetic bitumoids within the tectonic elements of the Perm region is drawn.

References

1. Voevodkin V.L., Galkin V.I., Galkin S.V., Rastegaev A.V., Determination of promising directions for searching for oil and gas fields in the Perm region using probabilistic and statistical methods (In Russ.), Nauka – proizvodstvu, 2006, no. 1, pp. 1-5.

2. Voevodkin V.L., Galkin V.I., Krivoshchekov S.N., Investigation of the effect of oil-content and research criteria in the Perm region on the hydrocarbon deposits distribution (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2012, no. 6, pp. 30-34.

3. Galkin V.I., Kozlova I.A., Krivoshchekov S.N., Nosov M.A., Solutions to regional problems of forecasting oil bearing according to geological and geochemical analysis of dispersed organic matter of Domanic type rocks (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2015, no. 1, pp. 21-23.

4. Kozlova I.A., Krivoshchekov S.N., Sannikov I.V., Estimate of the petroleum potential of the western Solikamsk depression based on geochemical and geodynamic data (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2014, no. 6, pp. 12-15.

5. Galkin V.I., Koshkin K.A., Melkishev O.A., The justification of zonal oil and gas potential of the territory of Visimskaya monocline by geochemical criteria (In Russ.), Vestnik Permskogo natsional’nogo issledovatel’skogo politekhnicheskogo universiteta. Geologiya. Neftegazovoe i gornoe delo = Perm Journal of Petroleum and Mining Engineering, 2018, V. 18, no. 1, pp. 4–15, DOI: http://doi.org/10.15593/2224-9923/2018.3.1

6. Voevodkin V.L., Galkin V.I., Kozlova I.A., Krivoshchekov S.N., Kozlov A.S., Hydrocarbons migration volumes within the limits of Solikamsk Depression (Pre-Ural Deflection) and possibilities of its use for the oil and gas content forecast (In Russ.), Geologiya, geofizika i razrabotka neftyanykh i gazovykh mestorozhdeniy, 2010, no. 12, pp. 6-11.

7. Galkin V.I., Kozlova I.A., Development of probabilistic-statistical regional-zoning models of oil and gas potential prediction based on the data of geochemical studies of the upper Devonian carbonate deposits (In Russ.), Geologiya, geofizika i razrabotka neftyanykh i gazovykh mestorozhdeniy, 2016, no. 6, pp. 40-45.

8. Galkin V.I., Karaseva T.V., Kozlova I.A. et al., Differentiated probabilistic assessment of the generation processes in Domanic sediments of Perm region (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2014, no. 12, pp. 103-105.

9. Vassoevich N.B., Neftegazonosnost’ osadochnykh basseynov (Oil and gas bearing of sedimentary basins), Moscow: Nauka Publ., 1988, 260 p.

10. Vassoevich N.B., Korchagina Yu.I., Lopatin N.V., Main phase of oil formation (In Russ.), Vestnik MGU. Seriya 4, Geologiya, 1969, no. 6, pp. 3-27.

The study of the physical and mechanical properties of frozen soil has a great importance in the construction and operation of engineering structures in the conditions of the Far North. This makes it possible to take into account frozen soil features when designing and ensuring the safety of structures. This article discusses the mobile laboratory (ML) as a technological tool for the study of frozen soil in various climatic zones. Frozen soil is environmental complex with the constant presence of unfrozen water; its study is becoming more relevant due to climate change. The operation of the ML includes carrying out scientific work, solving engineering tasks and improving the quality of initial data for design. ML provides the opportunity to work in various geographical conditions and fast replacement over long distances by railway, road and water transport. ML can be easily transported to research sites: remote, rural or urban areas. It allows conducting research nearby of place of engineering survey. Based on the results of ML operation, authors concluded that the simultaneous presence of 3-5 employees in the laboratory complex makes it possible to distribute the labor resource potential in the most efficient way. Recommendations on the choice of its optimal ML location are given, considering the provision of operational maintenance and repair of equipment. The map of ML locations is presented. Physico-mechanical tests of frozen and dispersed soils according to set of rules SP 25.13330.2012 are listed.

References

1. Khalbashkeev A.A., Melting permafrost: risks and solutions for the oil and gas sector (In Russ.), Neftegazovaya promyshlennost’, 2022, no. 2, p. 54.

2. Isaev O.N., Sharafutdinov R.F., Grechishcheva E.S. et al., Development of guidelines for implementation of engineering and geological surveys in Arctic zone (In Russ.), Vestnik NITs «Stroitel’stvo», 2021, no. 2(29), pp. 58-75, DOI: https://doi.org/10.37538/2224-9494-2021-2(29)-58-75

3. Okhapkin D.V., Subbotin A.S., The influence of a mobile soil testing laboratory on construction process organization in the conditions of the Far North (In Russ.), Stroitel’stvo: nauka i obrazovanie = Construction: Science and Education, 2021, V. 11, no. 3, pp. 7. – DOI: https://doi.org/10.22227/2305-5502.2021.3.7

Mixing of liquid and powdery components of process fluids with the help of hydro-ejector devices and mechanical agitators does not always lead to a sufficiently rapid interaction of the components. It may take an unacceptably long time for the process fluid to reach stable parameters. In this regard, an important stage in the preparation of drilling fluids, grouting systems, silencing fluids and other process fluids used in drilling, repair and operation of wells is the dispersion and homogenization of their components, aimed at accelerating the interaction of phases. The high efficiency of existing dispersants and homogenizers in commercial practice is currently associated with high speeds. The higher the flow rates of liquids, the lower the operational reliability of the devices. For this reason, dispersants are rarely used in fishing practice. This leads to the fact that process fluids are either pumping into the well without being fully ready for operation, or useful working time is lost to bring the liquids parameters to the required values by prolonged mixing with mechanical agitators and by pumping recirculation. The purpose of such treatment is to obtain sedimentation-stable suspensions and emulsions with stable rheological parameters. A promising direction in this area is the use of cavitation technologies. At the heart of the design of all jet hydrodynamic cavitation shredders of suspended particles is a cavitation generator. The author's design was developed and the generated cavitation flows in the flow part were described. The greater the coefficient of local hydraulic resistance of the cavitation generator, the lower the speed required to obtain cavitation in the compressed section of the flow. At a given throughput and pressure, it is possible to find the area of the narrowed part of the local resistance that provides the beginning of cavitation. The developed design of the cavitation generator can be used with both low-pressure centrifugal pumps and high-pressure plunger pumps. When selecting parameters, it is necessary to ensure the flow velocity of 14 m/s in the flow section of the local hydraulic resistance.

Acknowledgement. The research was carried out with the financial support of the Kuban Scientific Foundation within the framework of the IFI-20.1/54 scientific project.

References

1. Kasatkin A.G., Osnovnye protsessy i apparaty khimicheskoy tekhnologii (Basic processes and apparatuses of chemical technology), Moscow: Khimiya Publ., 1973, 752 p.

2. Sidenko P.M., Izmel'chenie v khimicheskoy promyshlennosti (Grinding in the chemical industry), Moscow: Khimiya Publ., 1977, 368 p.

3. Yurov V.M., Portnov V.S., Ibraev N.Kh., Guchenko S.A., Superficial tension of solid state, small particles and thin films (In Russ.), Uspekhi sovremennogo estestvoznaniya, 2011, no. 11, pp. 55–58.

4. Drozdov A.N., Gorelkina E.I., Development of a pump-ejector system for SWAG injection into reservoir using associated petroleum gas from the annulus space of production wells (In Russ.), Zapiski Gornogo instituta = Journal of Mining Institute, 2022, V. 254, pp. 191–201, DOI: http://doi.org/10.31897/PMI.2022.34

5. Drozdov A.N., Gorelkina E.I., Investigation of the ejector`s characteristics for the system of injection of water-gas mixtures into the reservoir (In Russ.), SOCAR Proceedings, 2022, Special Issue no. 2, pp. 025–032, DOI: https://doi.org/10.5510/ogp2022si200736

6. Tsegel'skiy V.G., Struynye apparaty (Inkjet devices), Moscow: Publ. of Bauman University, 2017, 573 p.

7. Usov G.A., Malakhov I.V., Bushkov V.V., Konovalov K.O., Analiticheskiy obzor tekhnicheskikh sredstv dlya prigotovleniya burovykh ochistnykh agentov (Analytical review of technical means for the preparation of drilling cleaning agents), Proceedings of International scientific and practical conference “Ural'skaya gornaya shkola – regionam. Tekhnologiya geologicheskoy razvedki” (Ural Mining School - regions. Geological exploration technology), 16 April 2018, pp. 124–129.

8. Gevari M.T., Parlar A., Torabfam M., Influence of fluid properties on intensity of hydrodynamic cavitation and deactivation of Salmonella typhimurium, Processes, 2020, V. 8, no. 3, p. 326, DOI: https://doi.org/10.3390/pr8030326

9. Patent US7086777B2, Device for creating hydrodynamic cavitation in fluids, Inventor: Kozyuk O.V.

The article discusses a new concept of multilevel mathematical modeling as the basis of a decision support system for the development of oil deposits at a late stage. The motivation for creating a new concept is the enormous uncertainty of the modeling object – oil reservoir. The article considers various reasons for such uncertainty, in particular, the ambiguity of the rescaling procedure and numerical effects in solving the equations of multiphase filtration in the reservoir. The proposed concept of multilevel modeling consists of a stage of multiscale modeling (modeling of nested objects of different scales: core fragment – core – borehole neighborhood - formation) and a stage of hierarchical modeling (reservoir modeling using models of varying complexity). In this case, the principle of optimal complexity models is used. The scheme of multilevel modeling is substantiated, the implementation of which should allow to level the problem of colossal uncertainty and make operational decisions on the development of deposits. Such a scheme assumes the construction of a three-dimensional hydrodynamic model (as the vertices of the hierarchy of models) based on the finite element method, excluding its total dependence on the geological model, numerical effects and the problem of rescaling. The proposed concept is used in the developed architecture of the decision-making system, in relation to which five requirements are formulated: 1) taking into account the peculiarities of the approach to mathematical modeling; 2) the ability of the decision-maker to access his level of the spatial and temporal hierarchy of managerial decisions; 3) the possibility of using a variety of approaches to working with information (in particular, the case-based approach); 4) consideration of the surface development of the field; 5) consideration of the iterative business planning process based on the economic model. It is noted that it is advisable to use an ontological knowledge base to create an integrated model.

References

1. Stepanov S.V., Sokolov S.V., Ruchkin A.A. et al., Considerations on mathematical modeling of producer-injector interference (In Russ.), Vestnik Tyumenskogo gosudarstvennogo universiteta. Fiziko-matematicheskoe modelirovanie. Neft', gaz, energetika = Tyumen State University Herald. Physical and Mathematical Modeling. Oil, Gas, Energy, 2018, V. 4, no. 3, pp. 146–164, DOI: https://doi.org/10.21684/2411-7978-2018-4-3-146-164

2. Samarskiy A.A., Vabishchevich P.N., Chislennye metody resheniya obratnykh zadach matematicheskoy fiziki (Numerical methods for solving inverse problems of mathematical physics), Moscow: Editorial URSS Publ., 2004, 480 p.

3. 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.

4. Persova M.G., Soloveichik Yu.G., Vagin D.V. et al., The design of high-viscosity oil reservoir model based on the inverse problem solution, Journal of Petroleum Science and Engineering, 2021, V. 199, Article No. 108245, DOI: https://doi.org/10.1016/j.petrol.2020.108245

5. Soloveichik Yu.G., Persova M.G., Grif A.M. et al., A method of FE modeling multiphase compressible flow in hydrocarbon reservoirs, Computer methods in applied mechanics and engineering, 2022, V. 390, Article No. 114468, DOI: https://doi.org/10.1016/j.cma.2021.114468

6. Akin'shin A.V., Rodivilov D.B., Yatsenko V.M. et al., Detailed study of lithological and petrophysical properties of texturally heterogeneous terrigenous reservoirs of Western Siberia (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2023, no. 6, pp. 16-19, DOI: https://doi.org/10.24887/0028-2448-2023-6-16-19

7. Belyakov E.O., Petrofizicheskoe modelirovanie fil'tratsionno-emkostnykh svoystv neftenosnykh kollektorov v kontseptsii svyazannosti porovogo prostranstva (na primere traditsionnykh terrigennykh kollektorov Zapadnoy Sibiri) (Petrophysical modeling of filtration and reservoir properties of oil-bearing reservoirs in the concept of pore space connectivity (using the example of traditional terrigenous reservoirs of Western Siberia)), Moscow – Izhevsk: Publ. of Institute for Computer Research, 2021, 288 p.

8. Kadet V.V., Khurgin Ya.I., Sovremennye veroyatnostnye podkhody pri reshenii zadach mikro- i makrourovnya v neftegazovoy otrasli (Modern probabilistic approaches to solving micro- and macro-level problems in the oil and gas industry), Moscow – Izhevsk: Publ. of Institute for Computer Research, 2006, 240 p.

9. Eremin N.A., Modelirovanie mestorozhdeniy uglevodorodov metodami nechetkoy logiki (Modeling of hydrocarbon deposits by methods of fuzzy logic), Moscow: Nauka Publ., 1994, 462 p.

10. Altunin A.E., Semukhin M.V., Stepanov S.V., Using the material balance and the fuzzy sets theory to solve the problems of recovery separation at simultaneous development of several reservoirs (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2012, no. 5, pp. 56-60.

11. Galiullin M.M., Zimin P.V., Vasil'ev V.V., Methodology selection of wells for stimulation of the production usage mathematical tools fuzzy logic (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2011, no. 6, pp. 120–123.

12. Stepanov S.V., Arzhilovskiy A.V., On the issue of improving the quality of mathematical modeling in solving problems of oil field development support (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2023, no. 4, pp. 56-60, DOI: https://doi.org/10.24887/0028-2448-2023-4-56-60

13. 13. Stepanov S.V., Tyrsin A.N., Ruchkin A.A., Pospelova T.A., Using entropy modeling to analyze the effectiveness of the waterflooding system (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2020, No. 6, pp. 62-67, DOI: https://doi.org/10.24887/0028-2448-2023-12- 62-67

14. 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.

15. Bekman A.D., Zelenin D.V., Application of advanced CRMP for reservoir pressure mapping (In Russ.), Vestnik Tyumenskogo gosudarstvennogo universiteta. Fiziko-matematicheskoe modelirovanie. Neft', gaz, energetika, 2021, V. 7, no. 4(28), pp. 163–180, DOI: https://doi.org/10.21684/2411-7978-2021-7-4-163-180

16. Betelin V.B., Yudin V.A., Afanaskin I.V., Sozdanie otechestvennogo termogidrosimulyatora – neobkhodimyy etap osvoeniya netraditsionnykh zalezhey uglevodorodov Rossii (The creation of a domestic thermohydrosimulator is a necessary stage in the development of unconventional hydrocarbon deposits in Russia), Moscow: Publ. of Research Institute for System Studies of the RAS, 2015, 206 p.

17. Bashlykov A.A., Precedent theory methods applyed in the systems of decision-making when managing pipeline systems (In Russ.), Avtomatizatsiya, telemekhanizatsiya i svyaz' v neftyanoy promyshlennosti, 2016, no. 1, pp. 23-32.

18. Glukhikh I.N., P'yankov V.N., Zabolotnov A.R., Situational models in corporate knowledge bases of geological and technological activities (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2002, no. 6, pp. 45-48.

19. Khasanov M.M., Glukhikh I.N., Shevelev T.G. et al., Ontology-based approach to designing intelligent support systems for oil and gas engineering (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2022, no. 12, pp. 7-13, DOI: https://doi.org/10.24887/0028-2448-2022-12-7-13

The oil reserves of the Lutseyakhskoye field are concentrated in the low-permeable Achimov formations. Horizontal wells with multi-stage fracturing are seemed to be the only way for economically viable oil production. Few issues complicate the field development. The first issue is geological. Water-saturated layer Ach32 is located close to the oil-bearing reservoir occurs in the immediate vicinity of the oil-bearing reservoir Ach33. Thickness of the shale between layers varies from 6 to 12 m. Taking into account the total thickness of the oil-bearing formation of about 50 m, this imposes serious requirements for controlling the height of hydraulic fractures. According to estimations, breakthrough of hydraulic fractures into the aquifer leads to high initial water cut (up to 60-80%) of new wells. The second issue is economical, which consists of high capital expenditures that should be done on initial stage of the field development (pipeline and facilities construction) and high uncertainty of the production forecast due to low permeable and complicated reservoir characteristics. Optimization of hydraulic fracturing technology is the key to solving problems in both cases. The Achimov reservoir is referred to as a tight formation and is currently at the evaluation stage. Despite that, all hydraulic fracturing operations were technologically successful. In addition, this project was supported by an extensive investigation program for studying of geomechanical properties of the reservoir. This study includes core testing, construction of the geomechanical models and multiple calculations to optimize fracture parameters. Activities in the Achimov formation were complemented by specialized well logging methods like imagers and dipole acoustic and microseismic survey. This allows to orient the azimuth of horizontal sections of the wells and to calibrate the geomechanical model to the actual height of hydraulic fractures.

Monitoring the development of a hydrocarbon field begins with the recording of field dynamic data, such as measurements during well test. These data are then used to solve various field tasks: issuing recommendations on well operation, developing measures to improve the efficiency of the reservoir pressure maintenance and development system, estimating reserves, building a hydrodynamic model, and so on. In specialized program complexes are used for interpretation of well testing data, both domestic and foreign. Rosneft Oil Company is one of the industry leaders that successfully develop knowledge-intensive software covering all key oil and gas production processes. The software lineup currently includes 24 software products, 10 of which have already been brought to the market. RN-BashNIPIneft is the main developer of Rosneft's engineering software, maintaining the company's high status in this area. The developed software products are used to solve production tasks in geology and design, field development and operation. They surpass analogs in terms of speed and quality of algorithm implementation and offer users a clear and simple interface. In particular, the new program complex RN-VEGA allows interpreting the results of well test – from the preparation of primary data to the issuance of a conclusion. The functionality of RN-VEGA includes effective algorithms and software solutions for determining the most important reservoir properties, such as formation pressure and permeability. The article presents the physical and mathematical basis of pressure field modeling, functional capabilities and examples of practical application of RN-VEGA, approbation results and user solutions.

References

1. Asalkhuzina G.F., Bikkinina A.G., Davletbaev A.Ya., Kostrigin I.V., Implementation of well test business processes automation in RN-KIN software by the example of RN-Yuganskneftegas LLC (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2020, no. 2, pp. 94-98, DOI: https://doi.org/10.24887/0028-2448-2020-2-94-98

2. Patent RU 2734202 C1, Method of analyzing horizontal wells with multistage hydraulic fracturing in low-permeability headers, Inventors: Davletbaev A.Ya., Nuriev A.Kh., Makhota N.A., Ivashchenko D.S., Asalkhuzina G.F., Sinitskiy A.I., Zarafutdinov I.A., Sarapulova V.V., Urazov R.R., Mukhamedshin R.K.

3. Ozkan E., Performance of horizontal wells: PhD dissertation, USA: Tulsa University, 1988.

4. Badykov I.Kh., Baykov V.A., Borshchuk O.S., The software package "RN-KIM" as a tool for hydrodynamic modeling of hydrocarbon deposits (In Russ.), Nedropol'zovanie XXI vek, 2015, no. 4, pp. 96–103.

5. Deeva T.A., Kamartdinov M.R., Kulagina T.E., Mangazeev P.V., Gidrodinamicheskie issledovaniya skvazhin: analiz i interpretatsiya dannykh (Well test: analysis and interpretation of data), Tomsk: Publ. of TPU, 2009, 254 z.

6. Earlougher R.C. Jr., Advances in well test analysis, SPE Monograph Series, 1977, V. 5, 264 p.

7. Chiglintseva A.S., Sorokin I.A., Urazov R.R. et al., Results of approbation of multi-phase flow models for pressure calculation in the RN-VEGA software (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2023, no. 5, pp. 106-110, DOI: https://doi.org/10.24887/0028-2448-2023-5-106-110

8. Patent RU 2804085 C1, Method for determining speed of sound in annulus of well, Inventors: Ishmuratov T.A., Davletbaev A.Ya., Khamidullina A.I., Senina A.F., Kunafin A.F., Ziganshin V.A.

9. Mullagaliev T.I., Kochanov D.N., Trifonov M.D. et al., Virtual flowmeter development for Zarubezhneft JSC (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2023, no. 2, pp. 55–58, DOI: https://doi.org/10.24887/0028-2448-2023-2-55-

10. Baykov V.A., Davletbaev A.Ya., Usmanov T.S., Stepanova Z.Yu., Special well tests to fractured water injection wells (In Russ.), Neftegazovoe delo, 2011, no. 1, pp. 65-75, URL: http://ogbus.ru/files/ogbus/authors/Baikov/Baikov_1.pdf

11. Akhmetova O.V., Urazov R.R., Davletbaev A.Ya. et al., Graphical method for determining the parameters of the skin zone based on transient temperature and pressure data in RN-VEGA (In Russ.), Ekspozitsiya Neft' Gaz = Exposition Oil Gas, 2023, no. 3, pp. 74–79, DOI: https://doi.org/10.24412/2076-6785-2023-3-74-79

12. Asalkhuzina G.F., Davletbaev A.Ya., Salakhov T.R. 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

The article discusses the source of water cut for wells of the Bazhenov formation with hydraulic fracturing in case of RN-Yuganskneftegas oil fields. The current assumptions about the sources of water supply for wells of the Bazhenov formation are considered, including the influence of fracture fluids, fracture invasion in upstream and downstream development facilities intervals, filtration of self reservoir water. Cases of leakage of the column are excluded due to the exclusively technical nature. Data of the testing Bazhenov formation wells before and after the active introduction of hydraulic fracturing are presented. Conclusions are drawn regarding the distribution of the water content of well tests; the intervals of the most common water cut values are highlighted. Examples of water cut in wells with a long production period, where the volume of extracted water exceeded the volume of injected fracture fluid, are shown. The nature of the distribution of bound water in the rocks of the Bazhenov formation is described. The estimation of the water saturation by core studies and nuclear magnetic logging (NMR) represented. The probability of fracturing of nearby productive objects with fractures is considered from the point of view of geology, geomechanical models and typical injection plans. The process of analyzing the NMR data in the process of creating a scale model, which led to the allocation of low-porous intervals in the Under-Achimov clays above the Bazhenov formation, is presented. A hypothesis has been formulated that combines the analysis of existing ideas about the source of water cut and the results of the allocation of low-porous intervals in the Podachimov clays. To confirm the results, a program of field tests of wells has been formed, including testing of intervals of Under-Achimov clays and laboratory studies of surface samples of liquids from various objects. Already implemented tests have shown the water saturation of the intervals of the Under-Achimov clays, as well as high values of reservoir pressures that allow wells to operate in the gushing mode, which currently confirms the formulated hypothesis.

References

1. Chirkov V.L., Sonich V.P., Stepen' geologicheskoy izuchennosti bazhenovskoy svity na territorii deyatel'nosti OAO “Surgutneftegaz” (The degree of geological knowledge of the Bazhenov formation in the territory of operation of Surgutneftegas OJSC), URL: https://www.petroleumengineers.ru/sites/default/files/bazhenovskaya_svita_v_surgutneftegaz.pdf

2. Shemelina O.N., Analiz razrabotki bazhenovskoy svity na Salymskom mestorozhdenii (Analysis of the development of the Bazhenov formation at the Salym field), Proceedings of the international scientific and practical conference “Bulatovskie chteniya”, 2020, pp. 437–440.

3. Beryushchev S.E., Bibi R.L., Shaoul J. et al., Integrated interpretation of production data and reservoir fracturing treatment data aimed to improve performance of well stimulation operations by the example of Vasyuganskaya formation (In Russ.), SPE-101585-MS, 2006, DOI: https://doi.org/10.2118/101585-MS

4. Metodicheskie rekomendatsii po podschetu zapasov nefti v otlozheniyakh bazhenovskogo gorizonta Zapadno-Sibirskoy neftegazonosnoy provintsii (Methodological recommendations for calculating oil reserves in sediments of the Bazhenov horizon of the West Siberian oil and gas province), Moscow: Publ. of Russian Federal Government Agency State Commission on Mineral Reserves, 2021, 19 p.

5. Ardislamova D.R., Kadyrova K.R., Kompleksnyy podkhod k izucheniyu bazhenovskoy svity na osnove geomekhanicheskogo modelirovaniya (An integrated approach to the study of the Bazhenov formation based on geomechanical modeling), Proceedings of scientific and practical conference “Tsifrovye tekhnologii” (Digital technologies), Ufa: Publ. of RN-BashNIPIneft LLC, 2002.

6. Fedorova D.V., Astaf'ev A.A., Nadezhdin O.V., Latypov I.D., Petrophysical model of the Bazhenov formation of the Priobskoye field of Rosneft (In Russ.), Delovoy zhurnal “Neftegaz.RU”, 2020, no. 6(102), pp. 76-84.

7. Fedorova D.V., Astaf'ev A.A., Yatsenko V.M. et al., Specifics of Bazhenov formation properties evaluation with complex method using core and magnetic resonance logging data for reservoir porosity determination (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2022, no. 11, pp. 15–19, DOI: https://doi.org/10.24887/0028-2448-2022-11-15-19

This article continues a series of publications about the new tools of Rosneft Oil Company for the design of field development facilities. The article deals with the actual problem associated with the long terms of design, construction and commissioning of capital construction facilities. The problem of the Company and its subsidiaries is explained by the lack of design documentation for the equipment used in the project at the time of the beginning of the development of the working documentation. This may lead to adjustments to the working and project documentation, as well as significant time and financial costs. The article describes the main provisions of the methodology of "platform solutions" aimed at identifying suppliers of equipment and materials at the pre-project stage and timely provision of initial data (design documentation) to the designer for the development of design and working documentation. The methodology describes changes in the process of developing design estimates, aimed primarily at improving the efficiency of designing standard facilities for the development of oil and gas fields, as well as reducing the variability of the nomenclature of equipment and materials used. The approach is based on the principles of exemplary design, including the development of standard projects, platform solutions and the use of information modeling. The approach does not contradict the Company's regulations, does not restrict competition in the market of domestic equipment manufacturers and fully complies with the legislation of the Russian Federation. The main advantages of implementing the proposed methodology of "platform solutions" are listed. Information is provided on the use of design efficiency improvement tools (standard projects, platform solutions) at the early stages of design work in the Rosneft Oil Company.

References

1. Kravchenko A.N., Kosarev A.S., Pavlov V.A. et al., Standard design - Moving with the times (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2020, no. 11, pp. 13–15, DOI: https://doi.org/10.24887/0028-2448-2020-11-13-15

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

Correct assessment of the proppant-fluid slurry hydraulic friction in the tubing is important to prevent premature shutdown of the hydraulic fracturing operation. Injection modeling in a hydraulic fracturing simulator always includes calculation of the friction of the fluid mixture with proppant in the tubing to calculate wellhead pressure. The effect of proppant on friction is calculated either using the Keck model or using the tabulated dependence of the friction multiplier on the proppant concentration. This tabulated function is part of the design input data and should be validated against field data. This paper presents a technique that allows one to restore this dependence without additional experiments using actual hydraulic fracturing data. The proposed method for restoring the proppant friction modifier needs actual data on flow rate, bottomhole and wellhead pressures and proppant concentration. It is assumed that friction maps of pure liquids are already up to date. The article discusses three ways of representing the friction modifier: linear, quadratic and piecewise linear function of concentration. The paper presents the formulation of the inverse problem of restoring the parameters of the selected dependence. Examples of testing the methodology are given. Some of the frac jobs analyzed are shown where a linear dependence has been successfully restored. Others require a quadratic dependence, and some others require the most complex, piecewise linear dependence. Approbation at 10 and 8 frac stages in two horizontal wells is presented. Approbation of the method shows that the dependence of hydraulic friction on proppant varies from well to well, but the method allows one to obtain reproducible results for successive stages of multi-stage hydraulic fracturing and neighboring wells and to refine the correction for proppant used as input data for design calculations in RN-GRID fracturing simulation software. The new technique allows one to restore the dependence of hydraulic proppant friction modifier and gives engineers a tool to maintain the relevance of friction correlations for the proppants used in the RN-GRID hydraulic fracturing simulator without additional lab research.

References

1. Aksakov A.V., Borshchuk O.S., Zheltova I.S. et al., Corporate fracturing simulator: from a mathematical model to the software development (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2016, no. 11, pp. 35–40.

2. Akhtyamov A.A., Makeev G.A., Baydyukov K.N. et al., Corporate fracturing simulator RN-GRID: from software development to in-field implementation (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2018, no. 5, pp. 94–97, DOI: https://doi.org/10.24887/0028-2448-2018-5-94-97

3. Zheltova I.S., Filippov A.A., Pestrikov A.V. et al., Coiled tubing simulation software development (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2020, no. 7,

pp. 120-126, DOI: https://doi.org/10.24887/0028-2448-2020-7-120-126

4. Keck R.Q., Nehmer W.L., Strumolo G.S., A new method for predicting friction pressures and rheology of proppant-laden fracturing fluids, SPE-19771-PA, 1992,

DOI: https://doi.org/10.2118/19771-PA

Optimal pumping equipment arrangement is one of the key tasks in the modern oil industry. The article considers the characteristics of a tapered pump. The conclusions are made that can be used in the selection of equipment. It is noted that the equipment is not always optimally matched to the well. Situations arise when any section of the pump starts operating outside the operating range, especially for non-standard equipment layouts such as a tapered pump. The performance of the tapered pump section in the negative pump head zone is studied insufficiently. This is the main reason for carrying out experiments and clarifying calculation algorithms. Experimental confirmation of the characteristics of a tapered pump as an algebraic sum of the characteristics of each section is provided. The authors describe a research of the characteristics of a tapered pump manufactured by Novomet-Perm, both in the positive and negative pump head zone at various frequencies. Also the operation of the upper section beyond the right boundary was analyzed. During the analysis it was found that in certain operating modes, processes occur that reduce the performance of equipment. In some situations, the deterioration of the installation increases. This type of operation is undesirable, because it leads to decrease in service life and should be avoided. The article provides recommendations on how these undesirable modes can be avoided for different frequencies and pumps.

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. Mironov Yu.S., Reducing the harmful effects of free gas on the operation of a submersible centrifugal pump (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 1969, no. 6, pp. 57–59.

3. Swetnam J.C., Sackash M.L., Performance review of tapered submergible pumps in the three bar field, Journal of Petroleum Technology, 1978, V. 30(12), pp. 1781–1787, DOI: https://doi.org/10.2118/6854-PA

4. Zhou D., Sachdeva R., Design tapered electric submersible pumps for gassy wells, SPE-113661-MS, 2008, DOI: https://doi.org/10.2118/113661-MS

5. Ali A., Yuan J., Deng F. et al., Research progress and prospects of multi-stage centrifugal pump capability for handling gas–liquid multiphase flow: comparison and empirical model validation, Energies, 2021, V. 14(4), Article no. 896, DOI: https://doi.org/10.3390/en14040896

6. Ageev Sh.R., Konicheskiy nasos kak sredstvo povysheniya effektivnosti raboty i nadezhnosti ETsN pri otkachke gazozhidkostnoy smesi (Conical pump as a means of increasing the operating efficiency and reliability of ESPs when pumping gas-liquid mixtures), Reports of the XI All-Russian Technical Conference of ALNAS JSC, Moscow: Publ. of ALNAS, 2002.

7. Labakh N., Results of research of two-package "conical" configuration of the electrocentrifugal pump when pumping gas-liquid mix (In Russ.), Neft', gaz i biznes, 2015, no. 2, pp. 60–62.

8. Gorid'ko K.A., Bilalov R.R., Verbitskiy V.S., Express evaluation of the efficiency of a tapered electric submersible pump use when pumping gas-liquid mixtures from a well. Part 1 (In Russ.), Neftepromyslovoe delo, 2021, no. 2, pp. 43 48.

9. Drozdov A.N., Investigations of the submersible pumps characteristics when gas-liquid mixtures delivering and application of the results for SWAG technologies development (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2011, no. 9, pp. 108-111.

10. 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-MS, 2017, DOI: https://doi.org/10.2118/187741-MS

11. Drozdov A.N., Gorelkina E.I., Development of a pump-ejector system for SWAG injection into reservoir using associated petroleum gas from the annulus space of production wells (In Russ.), Zapiski Gornogo instituta = Journal of Mining Institute, 2022, V. 254, pp. 191–201, DOI: http://doi.org/10.31897/PMI.2022.34

12. Peng Y., Liao T., Kang Y. et al., Unlock the liquid loaded gas wells with ESP technology: The successful ESP dewatering application in China Sichuan gas field, IPTC-18801-MS, 2016, DOI: https://doi.org/10.2523/IPTC-18801-MS

13. Prishchepo D., Khruleva E., Ponomarev A. et al., Development of domestic technologies of offshore wells operation in the Arctic shelf of Russia (In Russ.), Territoriya Neftegaz, 2019, no. 3, pp. 56–59.

The article presents a developed methodology for assessing clay swelling using centrifugation. The article describes the problem of clay swelling when freshwater-based fluids are used in hydraulic fracturing, which is one of the most used methods of stimulation of reservoir fluids production. There is a need to solve this problem by adding special reagents (clay stabilizers) to water-based hydraulic fracturing fluids, the purpose of which is to prevent the swelling of clay particles. The correct choice of the method for evaluating the inhibitory ability of clay stabilizers allows minimizing the negative impact of fluids used in hydraulic fracturing on the reservoir rock. The absence of a unified standard for testing the inhibitory ability of clay stabilizers and the presence of a great variety of research techniques does not make it possible to unambiguously assess the degree of fluid influence on clay swelling. The article proposes using centrifugation to improve the method of clay swelling evaluation by sedimentation stability of suspension. Assessment of clay swelling using an optimized method allows us to study the effect of fracturing fluids of rock to prevent adverse consequences in the form of reduced permeability of the productive zone. The method presented in this work makes it possible to shorten the time of the evaluation of the stabilizing effect of swelling inhibitors and improve the accuracy of the research results by separating free water from swollen clay. It also helps to reduce the experimental time and increase the accuracy of the results by separating free water and water retained by the clay mineral. The proposed technique increases the accuracy and efficiency of evaluating the stabilizing ability of the reagents used to prevent clay swelling, which contributes to optimizing the fluid formulation for the hydraulic fracturing process.

References

1. Abrams M.E., Grieser B., Benoit D., Everything you wanted to know about clay damage but were afraid to ask, AADE-16-FTCE-35, 2016, URL: https://www.aade.org/application/files/7815/7131/8490/AADE-16-FTCE-35_-_Abrams.pdf

2. Karazincir O., Williams W., Rijken P., Prediction of fines migration through core testing, SPE-187157-MS, 2017, DOI: https://doi.org/10.2118/187157-MS

3. Velde B., Barré P., Soils, plants and clay minerals, Springer, 2010, 355 p., DOI: https://doi.org/10.1007/978-3-642-03499-2

4. Ze Li, Hongtao Li, Gao Li et al., The influence of shale swelling on casing deformation during hydraulic fracturing, Journal of Petroleum Science and Engineering, 2021, V. 205, Article no. 108844, DOI: https://doi.org/10.1016/j.petrol.2021.108844

5. Meunier A., Clays, Springer, 2005, 477 p.

6. Borodin S.A., Razrabotka usovershenstvovannykh metodov issledovaniya ingibiruyushchey sposobnosti stabilizatorov nabukhaniya glin dlya zhidkostey gidrorazryva plasta (Development of improved methods for studying the inhibitory ability of clay swelling stabilizers for hydraulic fracturing fluids): thesis of candidate of technical science, Moscow, 2022.

7. Kalbaev A.M., Abdikamalova A.B., The study of clay minerals deposits Bestyubinsk (In Russ.), Problemy sovremennoy nauki i obrazovaniya, 2018, no. 8(128), pp. 6-10.

8. Patent RU 2553812 C2, Inhibitors of clay swelling for drilling industry, Inventors: Merli L., Dzhani F., Pirovano P., Floridi Dzh., Li Bassi Dzh.

9. Jie Zhang, Weimin Hu, Li Zhang, Investigation of ammonium–lauric salt as shale swelling inhibitor and a mechanism study, Adsorption Science & Technology, 2019, V. 37, no. 1-2, pp. 49-60, DOI: https://doi.org/10.1177/0263617418809832

10. Jackson M.L., Soil chemical analysis advanced course, Madison, USA: Parallel Press, 1969, 895 p.

11. Naumkina N.I., Trofimova F.A., Vlasov V.V., Rentgenograficheskiy analiz izmeneniya strukturnykh parametrov montmorillonita pri mekhanoaktivatsii (X-ray analysis of changes in the structural parameters of montmorillonite during mechanical activation), Proceedings of I Russian workshop “Gliny, glinistye mineraly i sloistye materialy” (Clays, clay minerals and layered materials), Moscow: Publ. of IGEM RAN, 2011, pp. 40-41.

12. Zhang L., Li T., Huang L. et al., Preparation and application of melamine cross-linked poly ammonium as shale inhibitor, Chemistry Central Journal, 2018, V. 12,

DOI: https://doi.org/10.1186/s13065-018-0410-9

13. Pham H., Nguyen Q.P., Effect of silica nanoparticles on clay swelling and aqueous stability of nanoparticle dispersions, Journal of Nanoparticle Research, 2014, V. 16, DOI: https://doi.org/10.1007/s11051-013-2137-9

14. Xiang G., Lv L., Ge L., Simple method for evaluating swelling of GMZ01 Na-bentonite affected by temperature at osmotic swelling, Soils and Foundations, 2020, V. 60, no. 5, pp. 1312-1321, DOI: https://doi.org/10.1016/j.sandf.2020.09.003

15. Wang X., Zhang C., Sun G., Investigation on swelling performance of oil sands and its impact on oil production during SAGD processes, Energies, 2022, V. 15(18),

DOI: https://doi.org/10.3390/en15186744