The article represents methodical approaches to the study of clay component conductivity during resistance measurements of core samples through multiple salinity and further evaluation of cation exchange capacity by log data interpretation using specific modeling of clayey sandstones. The objective of the paper is to increase the adequacy of oil and gas (water) saturation ratio for the purpose of reliable hydrocarbon reserves appraisal in sedimentary rocks containing shaly minerals within the company’s facilities. Low permeable reservoirs of Achimov formation carrying hard-to-recover hydrocarbon reserves are the main object of analysis. The deposits have typical clinoform structure, extremely low reservoir porosity and permeability, and heterogeneous oil saturation. Substantiation of oil–and-gas saturation ratio for such deposits is essentially complicated by quantitative evaluation of shaly minerals resistivity, because analysis based on standard approach (Archie-Dakhnov equation) most commonly leads to an underestimation of hydrocarbon saturation. The authors considered Russian and foreign approaches to evaluation of shaly minerals resistivity, demonstrated application of Ellansky advanced conductivity model and worldwide used Woxman-Smits equation. Results of petrophysical resistivity modeling for fully and partially saturated samples using standard technique and specific models of shaly sands show that theoretical conclusions are validated by core analysis data under thermobaric conditions with acceptable experiment accuracy. Effect of shale content on the apparent parameters of the degree of cementation and wettability according to the Archie – Dakhnov equation depends on formation water salinity. Observed variation between mean values of water saturation for different models is up to 9 %. This variation could be the reason of mismatch between expected oil inflow calculated by log data and drill stem test interpretation.

References

1. Dacy J., Martin P., Practical advances in core-based water saturation analysis of shaly tight gas sands, Petrophysics, 2008, V. 49, URL: https://jgmaas.com/SCA/2006/SCA2006-29.pdf

2. Dakhnov V.N., Geofizicheskie metody opredeleniya kollektorskikh svoystv i neftegazonasyshcheniya gornykh porod (Geophysical methods for the determination of reservoir properties and oil and gas saturation of rocks), Moscow: Nedra Publ., 1985, 310 p.

3. Waxman M.H., Smits L.J.M., Electrical conductivities in oil-bearing shaly sands, Soc. Pet.Eng. J., 1968, V. 8(02), pp. 107-122, DOI: https://doi.org/10.2118/1863-A

4. Vendel’shteyn B.Yu., On the relationship between the porosity parameter, surface conductivity coefficient, diffusion-adsorption activity and adsorption causes of terrigenous rocks (In Russ.), Proceedings of MINKhiGP,1960, V. 31, pp. 16–30.

5. Vendel’shteyn B.Yu., Ellanskiy M.M., Effect of rock adsorption properties on the dependence of relative resistance on porosity coefficient (In Russ.), Prikladnaya geofizika, 1964, V. 40, pp. 181–193.

6. Ellanskiy M.M., Petrofizicheskie svyazi i kompleksnaya interpretatsiya dannykh promyslovoy geofiziki (Petrophysical relationships and complex interpretation of production geophysics data), Moscow: Nedra, 1978, 215 p.

7. Ellanskiy M.M., On the issue of modeling the electrical conductivity of clayey aquifers and oil and gas bearing rocks with intergranular porosity (In Russ.), Geofizika, 2001, no. 2, pp. 54-62.

8. Enikeev B.N., K probleme postroeniya modeley udel’nogo elektricheskogo soprotivleniya gornykh porod (nekotorye problemy teorii obobshchennoy provodimosti mnogokomponentnykh smesey) (On the problem of constructing models of electrical resistivity of rocks (some problems of the theory of generalized conductivity of multicomponent mixtures)), Saratov: Publ. of SSU, 1979, pp. 70–96.

9. Clavier C., Coates G., Dumanoir J., Theoretical and experimental bases for dual-water model for shaly-sands interpretation, SPE-6859-PA, 1984,

DOI: https://doi.org/10.2118/6859-PA

10. Darling T., Well logging and formation evaluation, Amsterdam: Elsevier, 2005.

11. Juhasz I., Normalised Qv — the key to shaly sand evaluation using the Waxman – Smits equation in the absence of core data, Proceedings of SPWLA 22nd Annual logging symposium, 23–26 June 1981, Mexico City, Mexico, Paper SPWLA-1981-Z.

12. McPhee C., Reed J., Zubizarreta I., Core analysis: A best practice guide, Elsevier, 2015, 852 p.

13. Metodicheskie rekomendatsii po issledovaniyu porod-kollektorov nefti i gaza fizicheskimi i petrofizicheskimi metodami (Guidelines for the study of reservoir rocks of oil and gas by physical and petrophysical methods): edited by Goroyan V.I., Moscow: Publ. of VNIGNI, 1978, 396 p.

14. Zhizhimontov I.N., Makhmutov I.R., Evdoshchuk A.A., Smirnova E.V., Heterogeneous saturation cause analysis during petrophysical modeling of low permeability Achimov deposits (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2022, no. 3, pp. 30-35, DOI: 10.24887/0028-2448-2022-3-30-35

The development of hard-to-recover reserves in regions with developed oil production infrastructure is of great practical importance. In oilfields with traditional reservoirs, it is economically advantageous to add unconventional reservoirs from the underlying horizons to the development. The characteristic of such reservoirs is important for the competent use of secondary methods for enhanced oil recovery. One of the problems is to assess the hydrophobicity/hydrophilicity of the rocks which are composed not only of different minerals in various proportions, but also of organic matter. Laboratory studies of low-permeability reservoirs of the West Siberian petroleum basin carried out using a complex of lithological, petrophysical and geochemical methods make it possible to solve this problem as well as increase the reliability of searches for new hydrocarbon reservoirs and reduce risks during their development. Rock samples from the Upper Jurassic-Cretaceous sedimentary section of low-permeable deposits were studied using the X-ray diffraction method (mineral composition), the pyrolytic Rock-Eval method (organic matter) and the Pfeffer and HexCo methods (cation exchange capacity). The study of the physic-chemical activity of the mineral surface of such formations as the Frolov, Bazhenov, Abalak, Achimov showed that clay, siliceous minerals and organic matter could form organomineral aggregates during sedimentation. Analysis of interaction of humic material into mineral matrix during diagenetic and catagenetic stages showed 2 mechanisms of interaction with molecules: intrusion (immobilization) into a mineral volume (hydrolysis and polycondensation) and adsorption at a mineral surface (hydrogen and covalent bonds). The factor of intrusion of organic matter into the silica requires special attention during the study of wettability of rocks and making decisions on the development of oil and gas bearing formations of unconventional low-permeable reservoirs.

References

1. Lopatin N.P., Emets T.P., Piroliz v neftegazovoy geologii (Pyrolysis in oil and gas geology), Moscow: Nauka Publ., 1987, 143 p.

2. Kozlova E.V., Fadeeva N.P., Kalmykov G.A. et al., Geochemical technique of organic matter research in deposits enriched in kerogen (the Bazhenov formation, West Siberia) (In Russ.), Vestnik MGU. Seriya 4. Geologiya = Moscow University Geology Bulletin, 2015, no. 5, pp. 44–54.

3. Spasennykh M., Maglevannaia P., Kozlova E., et al., Geochemical trends reflecting hydrocarbon generation, migration and accumulation in unconventional reservoirs based on pyrolysis data (on the example of the Bazhenov Formation), Geosciences, 2021, V. 11, no. 8,

DOI: https://doi.org/10.3390/geosciences11080307

4. Kazak E.S., Kireeva T.A., Kazak A.V., Bogdanovich N.N., The ion-salt complex composition of the Bazhenov formation rocks in Western Siberia (In Russ.), Vestnik MGU. Seriya 4. Geologiya = Moscow University Geology Bulletin, 2017, no. 4, pp. 68-75.

5. Kazak E.S., Kazak A.V., Experimental features of cation exchange capacity determination in organic-rich mudstones, J. Nat. Gas Sci. Eng., 2020, V. 83, DOI: https://doi.org/10.1016/j.jngse.2020.103456

6. Nemova V.D., Koloskov V.N., Pokrovskiy B.G., Formation processes carbonatized reservoir in the clay-siliceous sediments of Bazhenov horizon in the west Mid-Ob (In Russ.), Razvedka i okhrana nedr, 2011, no. 12, pp. 31–35.

7. Bychkov A.Yu., Kalmykov G.A., Bugaev I.A. et al., Geochemical features of Bazhenov and Abalak formations (Western Siberia) (In Russ.), Vestnik MGU. Seriya 4. Geologiya = Moscow University Geology Bulletin, 2016, no. 6, pp. 86–93.

8. Borisenko S.A., Bogdanovich N.N., Kozlova E.V. et al., Estimating lyophilic properties of the Bazhenov formation rocks by adsorption and NMR methods (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2017, no. 3, pp. 12–16, DOI: http://doi.org/10.24887/0028-2448-2017-3-12-16

9. Bogdanovich N.N., Borisenko S.A., Kozlova E.V. et al., Mosaic hydrophobization of the surface of organic-mineral matrix from rocks of Bazhenov formation (In Russ.), SPE-187873-RU, 2017, DOI: https://doi.org/10.2118/187873-MS

10. Bazhanova A.E., Danilin I.V., Popov E.Yu. et al., Sostav kompleksa obmennykh kationov organomineral’noy matritsy verkhneyursko-nizhnemelovykh otlozheniy mestorozhdeniya Krasnoleninskogo svoda, Zapadnaya Sibir’ (Composition of the complex of exchangeable cations of the organo-mineral matrix of the Upper Jurassic-Lower Cretaceous deposits of the Krasnoleninsky arch deposit, Western Siberia), Proceedings of “Geomodel-2022” conference, Gelendzhik, 5-8 September 2022, Moscow, pp. 448-451.

11. Chukin G.D., Khimiya poverkhnosti i stroenie dispersnogo kremnezema (Surface chemistry and structure of dispersed silica), Moscow: Paladin, Printa Publ., 2008, 172 p.

12. Popov A.I., Guminovye veshchestva: svoystva, stroenie, obrazovanie (Humic substances: properties, structure, formation): edited by Ermakov E.I., St. Petersburg: Publ. of St. Petersburg University, 2004, 248 p.

13. Sutton R., Sposito A., Molecular structure in soil humic substances: The new view, Environmental Science & Technology, 2005, V. 39, no. 23, pp. 9009-9015, DOI: https://doi.org/10.1021/es050778q

14. Piccolo A., Conte P., Molecular size of humic substances: Supramolecular associations versus macromolecular polymers, Advances in Environmental Research, 2000, no. 3(4), pp. 508-521.

Hard-to-recover hydrocarbon reserves in Western Siberia are mostly concentrated in reservoirs of complex structure, represented by a combination of massive conventional reservoirs with intervals of thinly bedded sandstones and clays, interbeds of sandstones and siltstones with increased content of dispersed clay, and reservoirs with partially carbonated void space. Reservoir delineation methods based solely on open porosity are limited to massive conventional reservoirs. Lowering the porosity threshold may result in the inclusion of clay intervals. In order to predict porosity in such sediments, it is advisable to use nuclear magnetic logging, which makes it possible to identify all interbeds in the section that have effective porosity, regardless of the type of reservoir. The limitation of the application of nuclear magnetic logging is the fact that this method is present in a small number of wells, usually not more than 3 % of the well stock. In this work, effective porosity was modeled using neural network models and prediction maps of additional effective thicknesses were constructed. The average effective thicknesses over the field area was about 5 m. In some areas, the additional reservoir thickness was determined to be 7-10 m, demonstrating the promising application of the proposed methodology to improve the efficiency of field development. The proposed interpretation method, based on modeled effective porosity from nuclear magnetic and neutron logging data, allows the identification of dense interbedded and partially thin bedded, highly clayey, low permeability pseudo-reservoirs. To evaluate candidate wells, a model for calculating well inflow after hydraulic fracturing from pseudo-reservoir intervals is proposed. The results obtained and the developed approach are planned to be used to study and interpret a complex geological section formed in the distal part of the sea shelf and deep-sea sedimentation environment.

References

1. Samuel A.L., Some studies in machine learning using the game of checkers, IBM Journal, 1959, July, pp. 210–229, DOI: https://doi.org/10.1147/rd.33.0210

2. Mitchell T.M., Machine learning, McGraw-Hill, 1997, 432 p.

3. Ghareb H., Elsakka A., Chaw Y.N., Artificial Neural Network (ANN) prediction of porosity and water saturation of shaly sandstone reservoirs, Proceedings of 2018 AAPG/EAGE/MGS Myanmar Oil and Gas Conference: A Global Oil and Gas Hotspot: Unleashing the Petroleum Systems Potential, 2018, DOI: https://doi.org/10.1306/51559nyein2019

4. Cvetković M., Velić J., Malvić T., Application of neural networks in petroleum reservoir lithology and saturation prediction, Geologia Croatica, 2009, V. 62, pp. 115-121, DOI: http://doi.org/10.4154/gc.2009.10

5. Kanaev I.S., Neyrosetevoe detektirovanie produktivnykh intervalov na primere ob»ekta BV10 Samotlorskogo neftegazokondensatnogo mestorozhdeniya (In Russ.), Neftyanaya provintsiya, 2019, no. 4(20), pp. 157-169, DOI: https://doi.org/10.25689/NP.2019.4.157-171

6. Mardi M., Nurozi H., Edalatkhah S., A water saturation prediction using artificial neural networks and an investigation on cementation factors and saturation exponent variations in an Iranian oil well, Petroleum Science and Technology, 2012, V. 30, pp. 42-434, DOI: http://doi.org/10.1080/10916460903452033

7. Liping Zhu, Hongqi Li, Zhongguo Yang, Chengyang Li, Yile Ao, Intelligent logging lithological interpretation with convolution neural networks, Petrophysics, 2018, V. 59, pp. 799-810, DOI: http://doi.org/10.30632/PJV59N6-2018a5

8. Murav’ev I.A., Application of machine learning algorithms to interpret well logging results in the context of the task of identifying terrigenous reservoirs (In Russ.), Vestnik TGU. Fiziko-matematicheskoe modelirovanie. Neft’ gaz energetika, 2019, V. 5, pp. 123-137.

9. Nadezhdin O., Efimov D., Minikeeva L., Markov A., Experience with using data analysis technologies in identification of lost production zones (In Russ.), SPE-191597-18RPTC-MS, 2018, DOI: http://doi.org/10.2118/191597-18RPTC-MS

The lithological characteristics of clastic rocks are determined by the conditions of their formation. The mineral composition reflects the features of the source of demolition and post–sedimentation transformation, and the grane composition reflects the features of transportation and dynamics of the sedimentation environment. In practice, the mineral composition is more often used to restore the physical properties of rocks of well sections studied by a limited geophysical well logging complex in order to provide petroelastic and geomechanical modeling. There is no single way to restore physical characteristics. In practice, correlation methods are often used when one property is determined by a paired or multidimensional relationship from another property. Experience shows that such approaches do not provide the necessary forecasting accuracy and, for this reason, the results of petroelastic and geomechanical modeling have large uncertainties, more often leading to ambiguous results. In conditions of limited data on the mineral composition and its variability by section, in order to determine the composition and structure of rocks, on which the key characteristic of reservoirs – filtration heterogeneity depends, the need to use available data, which can serve as a grane characteristic, is determined. Today, data on the grane composition are used to solve the inverse problem of studying the geological past of the land, as well as various properties of terrigenous reservoirs of oil and gas. On the basis of this information, a lithological classification of rocks is carried out, at the prospecting stage of geological exploration, capacitive properties, bulk mass, permeability and other parameters are predicted. This paper describes the possibility of using grane composition at a quantitative level to model petrophysical properties. The method of restoring physical properties was developed based on the results of a study of rocks selected from different terrigenous deposits of various regions of Russia. The performed analysis made it possible to significantly increase the practical significance of the grane characteristics of rocks in the petrophysical study of well sections and geological modeling of natural terrigenous reservoirs.

References

1. Avdusin P. P., Baturin V.P., Opyt metodiki issledovaniya mekhanicheskikh osadkov (primenitel’no k izucheniyu litologii neftyanykh mestorozhdeniy) (Experience in methods for studying mechanical sediments (in relation to the study of lithology of oil fields)), Proceedings of AzNSh, Seriya rabot po obshchey i prikladnoy geologii, 1930, pp. 65-68.

2. Gostintsev K.K., Metody i znachenie gidrodinamicheskoy klassifikatsii peschano-alevritovykh porod pri prognoze litologicheskikh lovushek nefti i gaza (Methods and significance of hydrodynamic classification of sand-silt rocks in predicting lithological oil and gas traps), Leningrad: Publ. of VNIGRI, 1981, pp. 51-62.

3. Kotyakhov F.I., Fizika neftyanykh i gazovykh kollektorov (Physics of oil and gas reservoirs), Moscow: Nedra Publ., 1977, 287 p.

4. Metodicheskie ukazaniya po drobnomu granulometricheskomu analizu sedimentatsionnym sposobom (Guidelines for fractional granulometric analysis by sedimentation method), Leningrad: Publ. of VNIIGRI, 1989, 181 p.

5. Velizhanin V.A., Golovatskaya I.V., Gulin Yu.A. et al., Opredelenie emkostnykh svoystv i litologii porod v razreze neftegazovykh skvazhin po dannym radioaktivnogo i akusticheskogo karotazha (Determination of capacitive properties and lithology of rocks in the context of oil and gas wells using radioactive and acoustic logging data), Kalinin: Publ. of Soyuzpromgeofizika, 1984, 110 p.

The hydrocarbon reserves calculation is the basis for planning of field development. Nowadays, such data as initial reservoir pressure, oil/gas/water contact definition, formation fluid properties, initial production rate and some other parameters needed for hydrocarbon reserves calculation can be obtained during cased hole testing. This requires fair amount of materials and lots of time. Certain well tests can extend up to a year or more, and are fraught with high costs. The wireline formation test has long been applied in exploration worldwide. During the wireline formation test the operator can receive real-time geological information, which is also required for hydrocarbon reserves estimation and conversion to B₁ and C₁ reserve categories. The efficiency of this method allows taking measurements with high density over a short time. As a result, geological data obtained by this method is more detailed and informative than that produced from the cased hole test. The time duration of well test program can be significantly reduced. Cost and time saving can be beneficial for exploration in remote regions where logistics and drilling team support issues can become particularly sensitive. It can also speed up decision-making on additional exploration in the fields under development. However, the wireline formation test cannot substitute the casing well test; this data cannot be self-sufficient for hydrocarbon reserves calculation in common practice. Yet, the regulation for acquiring and applying this data can allow the common practice to be changed and full-scale application of wireline formation test data in the context of reserves categorization.

References

1. Abdrakhmanova L.G., Akhmedsafin S.K., Blinov V.A. et al., Metodicheskie rekomendatsii po obosnovaniyu podschetnykh parametrov zalezhey v terrigennykh otlozheniyakh po dannym GIS i novym metodam GDK-OPK pri postanovke na uchet i perevode UVS v promyshlennye kategorii zapasov (Methodological recommendations for substantiating the calculated parameters of deposits in terrigenous deposits using well logging data and new methods of hydrodynamic logging and formation testing when registering and transferring hydrocarbons to industrial categories of reserves), Moscow, 2015, 64 p.

2. MDT Modular Formation Dynamics Tester, Schlumberger, 2002.

3. Khisamov R.S., Suleymanov E.I., Fakhrullin R.G. et al., Gidrodinamicheskie issledovaniya skvazhin i metody obrabotki rezul’tatov izmereniy (Hydrodynamic testing of wells and methods for processing measurement results), Moscow: Publ. of VNIIOENG, 1999, 227 p.

4. Metodika rascheta dobyvnogo potentsiala skvazhin (Methodology for calculating the production potential of wells), Ufa: Publ. of YuganskNIPIneft’, 2001, 85 p.

5. 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, 261 p.

The article presents the results of studying the fracturing of the Osinsky productive horizon on the example of hydrocarbon deposits based in the central part of the Nepa arch of Nepa-Botuoba anteclise of Eastern Siberia. The identification of additional factors affecting the reservoir properties of productive horizons and the inclusion of the data obtained into geological and hydrodynamic models is an urgent scientific and technical task taking into account the complex geological structure of carbonate reservoirs. The formation of the O1 layer of the Osinsky horizon in the arched part of the Nepa-Botuoba anteclise in an area with developed fault-block tectonics caused the widespread development of fracturing, which until recently was little studied by field and laboratory geological and geophysical research methods. Based on a comprehensive analysis of well logs, core research results and well test data, the characteristic of the fractured component of the void space of the O-1 formation is given, and its role in the current state of development of carbonate reservoir deposits in Eastern Siberia is determined. During the work, new data was obtained on the presence of subvertical tectonic fractures in the section of the O-1 formation, characterized by the greatest disclosure and acting as additional highly permeable fluid filtration channels. In the near future, it is planned to conduct comprehensive lithological and petrographic studies in new wells, which will significantly clarify the parameters of fracture systems and obtain additional data to improve petrophysical algorithms for the purpose of differentiated calculation of reserves in both porous-cavernous and fractured formations, as well as clarify permeability coefficient of Osinsky horizon reservoirs in zones of tectonic fracturing development.

References

1. Shemin G.G., Geologiya i perspektivy neftegazonosnosti venda i nizhnego kembriya tsentral’nykh rayonov Sibirskoy platformy (Nepsko-Botuobinskaya, Baykitskaya anteklizy i Katangskaya sedlovina) (Geology and oil and gas potential Vendian and Lower Cambrian deposits of central regions of the Siberian Platform (Nepa-Botuoba, Baikit anteclise and Katanga saddle)): edited by Kashirtsev V.A., Novosibirsk: Publ. of SB RAS, 2007, 467 p.

2. Mel’nikov N.V., Vend-kembriyskiy solenosnyy basseyn Sibirskoy platformy (Stratigrafiya, istoriya razvitiya) (Vendian-Cambrian salt basin of the Siberian Platform (Stratigraphy, development history)), Novosibirsk: Publ. of SNIIGGiMS, 2018, 177 p.

3. Kuznetsov V.G., Ilyukhin L.N., Postnikova O.V. et al., Drevnie karbonatnye tolshchi Vostochnoy Sibiri i ikh neftegazonosnost’ (Ancient carbonate strata of Eastern Siberia and their oil and gas potential), Moscow: Nauchnyy Mir Publ., 2000, 104 p.

4. Kuznetsov V.G., Postnikova O.V., Malinina A.K., Reservoir properties and structure of the Osinsky reservoir of the Talakanskoye field (In Russ.), Geologiya, geofizika i razrabotka neftyanykh i gazovykh mestorozhdeniy, 1995, no. 1, pp. 24-30.

5. Kalacheva V.N., Nekotorye dannye o treshchinovatykh porodakh nizhnego kembriya Irkutskogo amfiteatra (Some data on the Lower Cambrian fractured rocks of the Irkutsk amphitheater), Proceedings of VNIGRI, 1958, V. 121.

6. Nikulina M.Yu., Nikulin E.V., Luk’yanov V.V. et al., Prospects for searching for oil and gas deposits in the Osinsky pay zone in the territory of Nepa-Botuoba anteclise of Eastern Siberia (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2023, no. 9, pp. 85-89, DOI: http://doi.org/10.24887/0028-2448-2023-9-85-89

7. Bagrintseva K.I., Treshchinovatost’ osadochnykh porod (Fracturing of sedimentary rocks), Moscow: Nedra Publ., 1982, 241 s.

8. Belonovskaya L.G., Fracture of rocks and basis of oil and gas fractured reservoirs searching developed in VNIGRI (In Russ.), Neftegazovaya geologiya. Teoriya i praktika, 2006, no. 1, pp. 1–11.

9. Diyashev R.N., Fedorov V.N., Iktisanov V.A., Specification of reservoir filtration system model for Talakansky field on the well test basis

(In Russ.), SPE-104352-RU, 2006,

DOI: https://doi.org/10.2118/104352-MS

Development of oil and gas fields with hard-to-recover reserves often requires the use of multi-casing design. The use of standard coupling casing strings in such wells leads to significant metal consumption, increased consumption of associated materials (drilling mud, cement slurry, etc.) and the use of heavy-duty drilling rigs. One of the options to reduce investment costs for drilling is construction of wells using integral casing connections. Realization of well construction with integral casings is possible due to application of threaded connections TMK UP MOMENTUM FL and TMK UP MOMENTUM SFL. TMK UP MOMENTUM FL is a flush high-torque gas-tight connection with tensile and compression efficiency of 60% of the pipe body. TMK UP MOMENTUM SFL is a high-tension, high torque, semi-flush connection with tensile and compression efficiency of up to 90% of the pipe body. In this article on the example of a typical well in the Volga economic region it is demonstrated that the use of pipes with integral threaded connections allows to reduce the metal consumption of the well and the total amount of drilling and cement mud. Reduction of metal consumption relative to the base variant amounted to 10.7%. Reduction of total requirement of drilling mud of 30% and cementing mud of 51% relative to the basic variant with coupled connections. Increase of profitability of field development consists not only in new methods of oil recovery enhancement, but also in search of methods reducing investment costs for well construction. It is shown that one of the options to reduce investment costs for drilling is construction of wells using integral connections.

References

1. Chigladze P.G., Shtyfel’ A.P., Gur’ev V.N. et al., Construction of slim holes as a way to increase performance index of low cost-effective field development (In Russ.), Neft’. Gaz. Novatsii, 2019, no. 3, pp. 64-69.

2. Al-Abri O.S., Pervez T., Structural behavior of solid expandable tubular undergoes radial expansion process – Analytical, numerical, and experimental approaches, International Journal of Solids and Structures, 2013, V. 50, no. 19, pp. 2980–2994, DOI: http://doi.org/10.1016/j.ijsolstr.2013.05.013

3. Nabokin R.E., Agishev A.R., Domestic solutions in the segment of casing pipes with Premium threaded connections. Technology for the construction of offshore wells with extended reach from the vertical in modern conditions (In Russ.), Inzhenernaya praktika, 2023, no. 3.

4. RD 39-00147001-767-2000. Instruktsiya po krepleniyu neftyanykh i gazovykh skvazhin (Instructions for oil and gas wells cementing), 2000, 214 p.

5. Instruktsiya po raschetu obsadnykh kolonn dlya neftyanykh i gazovykh skvazhin (Instructions on the design of casing for the oil and gas wells), Kuybyshev, 1989.

6. Fedoseev D.A., Korovin I.Yu., Koval’ M.E. et al., On the possibility to reduce metal consumption for well structure (In Russ.), Neft’. Gaz. Novatsii, 2021, no. 8, pp. 25-30.

7. Rekin S.A., Nurgaleev A.R., Agishev A.R. et al., Modern technical solutions for well construction in the pipe industry (In Russ.), Burenie i neft’, 2021, no. 4, pp. 27-28.

The study of the characteristics of fine clays and the development of universal drilling fluids on their basis for the purpose of safe well drilling are the main factor in increasing of hydrocarbon production, reducing the duration of well drilling and eliminating complications and accidents. The scientific novelty of this work is the study of the possible use of fine clay from the Gubadag deposit as the main material for the preparation of drilling mud in order to create hydrostatic pressure during well drilling. An important aspect is the development of solution compositions adapted to a variety of geological formations and rocks. The lack of an optimal composition can lead to instability of the well walls or loss of permeability, which will seriously complicate further operation. The results obtained show that Gubadag clay can be classified as low-quality materials. Solutions created from its samples with various types of water (fresh, marine and Koitendag) are almost the same in volume. However, it is noted that as a result of the treatment of seawater with caustic soda, sample No. 2 significantly increases in volume of the solution, reaching more than 4 m3, which differs from other samples. All this indicates the stability of the properties of clays in various environmental conditions, which may be important when choosing optimal solutions for drilling wells in different regions with different types of water and geological characteristics. The practical significance of the research is the possibility of adapting drilling fluids to various geological conditions, minimizing risks during drilling and improving the efficiency of production processes.

References

1. Nafikova S., Bugrayev A., Taoutaou S. et al., Elimination of the sustained casing pressure using self-healing cement in Turkmenistan section of the Caspian sea, SPE-195945-MS, 2019, DOI: http://doi.org/10.2118/195945-MS

2. Pulatov B.R., Technological aspects and emerging complications when drilling wells in rapiferous zones (In Russ.), Innovatsii v neftegazovoy otrasli =Innovations in the oil and gas industry, 2021, no. 2(3), pp. 103-114.

3. Proceedings of the international scientific-practical conference “Geological and technological aspects of development of hard-to-recover of hydrocarbon fields”: edited by Ahmetov B.B., Aktau: Publ. of Yessenov University, 2019, 268 p., URL: https://yu.edu.kz/wp-content/uploads/2020/06/sbornik-18-aprelya-2019.pdf

4. Negmatov S.S., Sharifov G.N., Kobilov N.S., Negmatova K.S., Utyazhelyayushchie organomineral’nykh ingredienty dlya polucheniya utyazhelennykh burovykh rastvorov primenyayushchikhsya pri burenii neftegazovykh skvazhin (Weighting organomineral ingredients for obtaining weighted drilling fluids used in drilling oil and gas wells), Proceedings of Republican scientific and technical conference “Resurso- i energosberegayushchie, ekologicheski bezvrednye kompozitsionnye nanokompozitsionnye materialy” (Resource- and energy-saving, environmentally friendly composite nanocomposite materials), Tashkent, 2019, pp. 195-199.

5. Deryaev A.R., Selection of drilling mud for directional production and evaluation wells (In Russ.), SOCAR Proceedings, 2023, no. 3, pp. 51–57,

DOI: http://doi.org/10.5510/OGP20230300886

6. Deryaev A.R., Features of forecasting abnormally high reservoir pressures when drilling wells in the areas of Southwestern Turkmenistan (In Russ.), SOCAR Proceedings Special Issue, 2023, no. 2, pp. 7–12, DOI: http://doi.org/10.5510/OGP2023SI200872

7. Deryaev A.R.б Drilling of horizontal wells in Western Turkmenistan (In Russ.), SOCAR Proceedings Special Issue, 2023, no. 2, pp. 32–40,

DOI: http://doi.org/10.5510/OGP2023SI200877

8. Deryaev A.R., Analysis of the opening of zones with abnormally high reservoir pressures in the oil and gas fields of the Western part of Turkmenistan (In Russ.), SOCAR Proceedings Special, 2023, no. 2, pp. 22–27, DOI: http://doi.org/10.5510/OGP2023SI200871

9. Da Câmara P.C., Madruga L.Y., Marques N.D.N., Balaban R.C., Evaluation of polymer/bentonite synergy on the properties of aqueous drilling fluids for high-temperature and high-pressure oil wells, Journal of Molecular Liquids, 2021, V. 327, DOI: https://doi.org/10.1016/j.molliq.2020.114808

10. Akpan E.U., Enyi G.C., Nasr G. et al., Water-based drilling fluids for high-temperature applications and water-sensitive and dispersible shale formations, Journal of Petroleum Science and Engineering, 2019, V. 175, pp. 1028-1038, DOI: http://doi.org/10.1016/j.petrol.2019.01.002

11. Mohamed A., Salehi S., Ahmed R., Significance and complications of drilling fluid rheology in geothermal drilling: A review, Geothermics, 2021, V. 93,

DOI: http://doi.org/10.1016/j.geothermics.2021.102066

12. Deryaev A.R., Selection of drilling mud for directional production and evaluation wells (In Russ.), SOCAR Proceedings, 2023, no. 3, pp. 51–57,

DOI: http://doi.org/10.5510/OGP20230300886

13. Deryaev A.R., Forecast of the future prospects of drilling ultra-deep wells in difficult mining and geological conditions of Western Turkmenistan (In Russ.), SOCAR Proceedings Special Issue, 2023, no. 2, pp. 13–21, DOI: http://doi.org/10.5510/OGP2023SI200874

14. Jun Rui Zhang, Meng Dan Xu, Georgios E.Ch., Chun Hui Zhou, Clay minerals in drilling fluids: functions and challenges, Clay Minerals, 2020, V. 55(1), pp. 1-11,

DOI: http://doi.org/10.1180/clm.2020.10

15. Muhammed N.S., Olayiwola T., Elkatatny S., A review on clay chemistry, characterization and shale inhibitors for water-based drilling fluids, Journal of Petroleum Science and Engineering, 2021, V. 206, DOI: http://doi.org/10.1016/j.petrol.2021.109043

16. Mahon R., Development of an optimised integrated underbalanced drilling strategy for cuttings transport in gas-liquid flow through wellbore annuli: PhD thesis, Robert Gordon University, 2023, DOI: https://doi.org/10.48526/rgu-wt-1880278

17. Deryaev A.R., Well trajectory management and monitoring station position borehole (In Russ.), SOCAR Proceedings Special Issue, 2023, no. 2, pp. 1–6,

DOI: http://doi.org/10.5510/OGP2023SI200870

18. Chouikhi N., Cecilia J.A., Vilarrasa-García E. et al., CO2 adsorption of materials synthesized from clay minerals: A review, Minerals, 2019, V. 9(9), pp. 514,

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19. Ho T.A., Criscenti L.J., Greathouse J.A., Revealing transition states during the hydration of clay minerals, The Journal of Physical Chemistry Letters, 2019, V. 10(13),

pp. 3704-3709, DOI: https://doi.org/10.1021/acs.jpclett.9b01565

20. Swai R.E., A review of molecular dynamics simulations in the designing of effective shale inhibitors: application for drilling with water-based drilling fluids, Journal of Petroleum Exploration and Production Technology, 2020, V. 10(8), pp. 3515-3532, DOI: http://doi.org/10.1007/s13202-020-01003-2

21. Khoury H.N., Review of clays and clay minerals in Jordan, Arabian Journal of Geosciences, 2019, V. 12(23), DOI: http://doi.org/10.1007/s12517-019-4882-2

22. Kuliev M.Yu., The use of cement mixtures to eliminate absorption during drilling (In Russ.), Innovatsii v neftegazovoy otrasli =Innovations in the oil and gas industry, 2022, no. 3(4), pp. 50-53, DOI: http://doi.org/10.5281/zenodo.7473375

23. Xin Chen, Chengwen Wang, Yucheng Xue et al., A novel thermo-thickening viscosity modifying admixture to improve settlement stability of cement slurry under high temperatures, Construction and Building Materials, 2021, V. 295, DOI: https://doi.org/10.1016/j.conbuildmat.2021.123606

Offshore fixed platforms and wellhead platforms are the main elements of Vietsovpetro JV fields development on the shelf of Vietnam. These facilities gather and treat the oil coming from production wells, which is then supplied through the underwater pipeline systems to the floating storage and offloading units. Field development by means of wellhead platforms and central processing platform helps avoiding significant capital investments in construction of metal-intensive fixed platforms with a multifunctional top structure and reduces operating costs. The development vector of the Vietsovpetro JV in the area of capital construction is aimed at reducing metal consumption and costs. Optimization of construction solutions and transition to unmanned technologies for operating wellhead platforms led to cost reduction by more than half compared to 2014. Currently, the priority offshore structures in the Company are the unmanned wellhead platforms and satellite platforms. The introduction of unmanned wellhead platforms and satellite platforms benefits in optimizing the company's capital costs, however further minimization of the investments for construction of new wells on existing platforms during the late development stage, requires additional non-standard approaches. One of such solutions is the organization of additional wells at existing offshore structures. The article covers the issues related to designing and construction of new additional wells on the operating facilities, which have not been considered by the initial standard design. The implementation of an integrated approach to improving the efficiency of offshore field development at the Vietsovpetro JV allows the company to maintain its leading position in the Southeast Asia.

References

1. Ty Tkhan' Ngia, Veliev M.M., Le V'et Khay, Ivanov A.N., Razrabotka shel'fovykh neftyanykh mestorozhdeniy SP V'etsovpetro (Pryzhok “Belogo Tigra” dlinoyu v 35 let...) (Development of offshore oil fields by JV Vietsovpetro (Leap of the "White Tiger" 35 years long ...)), St. Petersburg: Nedra Publ., 2017, 386 p.

2. Salavatov T.Sh., Veliev M.M., Suleymanov A.A., Bondarenko V.A., Nekotorye osobennosti razrabotki i ekspluatatsii morskikh neftegazovykh mestorozhdeniy (Some features of the development and operation of offshore oil and gas fields), Part 1, Baku: Chashyoglu Publ., 2018, 496 p.

In most platform-type reservoirs, most of the initial reserves are concentrated in terrigenous sediments, which are mainly found in the area and are characterized by high productivity, efficient development and high production rates. Despite the long development history of the Arlanskoye field, the Lower Carboniferous terrigenous formation is still the main production target. Seven pay zones with different reservoir characteristics have been identified in the main development target interval. The zones are unevenly distributed over the area. Three units have been identified - Upper, Middle and Lower. All three units are operated simultaneously and as a result there is an uneven development of reserves in terms of area and section due to the differentiation of reservoir properties combined with increased oil viscosity. At present, the target is in the final stage of development, the development system has been formed, the current well spacing density is 12 ha/well, and the recovery of reserves in the area is 98%. Scientific research and industrial experiments have enabled the formation of efficient development systems, which is evidenced by the high values of the current oil recovery factors (0.41-0.55) in the cross section of the identified lots. In the first place, it is necessary to determine the zones of location of the remaining recoverable reserves by section and to make decisions on their effective development. The application of an integrated approach allowed the commissioning of new horizontal wells and lateral horizontal wells with oil production rates of up to 170 t/day. The identification of residual reserve zones by section and area in mature fields under conditions of uneven reserve depletion is a promising direction. The results of the drilling confirm the relevance and feasibility of expanding the work on the verification of residual reserves by section in order to increase the efficiency of the development of the basic multi-zone target of the unique Arlanskoye field in the Republic of Bashkortostan.

References

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

2. Gareev A.T., Nurov S.R., Vagizov A.M., Sibaev T.V., Complex approaches to improving development system of unique Arlanskoye oilfield (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2018, no. 12, pp. 112–116, DOI: https://doi.org/10.24887/0028-2448-2018-12-112-116

3. Fedorenko N.V., Lozin E.V., Gareev A.T. et al., Improving production efficiency of multilayer terrigenous Low Carbonic thick series of Arlanskoye oilfield (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2018, no. 9, pp. 106–110, DOI: http://doi.org/10.24887/0028-2448-2018-9-106-110

4. Chervyakova A.N., Gareev A.T., Vagizov A.M., Khisamiev T.R., Poisk perspektivnykh uchastkov dlya bureniya skvazhin i bokovykh stvolov s ispol’zovaniem rezul’tatov geologicheskogo modelirovaniya i geologo-promyslovogo analiza na primere TTNK Novo-Khazinskoy ploshchadi Arlanskogo mestorozhdeniya (Search for promising areas for drilling wells and sidetracks using the results of geological modeling and geological and field analysis using the example of the Lower Carboniferous terrigenous strata of the Novo-Khazinskaya area of the Arlanskoye field), Collected papers “Aktual’nye nauchno-tekhnicheskie resheniya dlya razvitiya neftedobyvayushchego potentsiala PAO ANK “Bashneft’” (Current scientific and technical solutions for the development of the oil production potential of Bashneft), Proceedings of BashNIPIneft, 2016, V. 124, 694 p.

5. Gareev A.T., Nurov S.R., Faizov I.A. et al., Production features and concept of further development of the unique Arlanskoye field (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2023, no. 4, pp. 40–45, DOI: http://doi.org/10.24887/0028-2448-2023-4-40-45

6. Vagizov A.M., Gareev A.T., Timerkhanov R.F. et al., Burenie vysokodebitnykh GS na zavershayushchey stadii razrabotki mnogoplastovogo ob»ekta TTNK Arlanskogo mestorozhdeniya za schet kompleksnogo podkhoda k verifikatsii ostatochnykh zapasov po razrezu (Drilling high-yield horizontal wells at the final stage of development of a multilayer object of terrigenous formation of the Lower Carboniferous of the Arlanskoye field through an integrated approach to verifying residual reserves along the section), Proceedings of scientific and technical forum of SamaraNIPIneft LLC, Samara: Portal Innovatsiy Publ., 2022, pp. 36–37.

7. Devlikamov V.V., Khabibullin Z.A., Kabirov M.M., Anomal’nye nefti (Abnormal oil), Moscow: Nedra Publ., 1975, 168 p.

8. Suleymanova M.V., Mironenko A.A., Safin A.Z. et al., Oil migration on the last stage of oil fields development (In Russ.), Ekspozitsiya Neft’ Gaz, 2023, no. 1, pp. 72–75, DOI: http://doi.org/10.24412/2076-6785-2023-1-72-75

9. Patent RU 2672766 C1, Method for predicting morphometric parameters of channel bodies (paleochannels), Inventors: Ol’neva T.V., Zhukovskaya E.A.

10. Grishchenko V.A., Yakupov R.F., Veliev E.F. et al., Formation of approaches to the development of reserves, taking into account the facial geological model of sedimentation on the example of the Bobrikovsko-Radevsky horizon of the Tuymazinsky oil field (In Russ.), Ekspozitsiya Neft’ Gaz, 2022, no. 5, pp. 16–20,

DOI: http://doi.org/10.24412/2076-6785-2022-5-16-20

The search for methods and technologies for enhanced oil recovery is a priority task for Vietsovpetro JV. The Lower Miocene of the Northern Area of White Tiger field has a long history of development and injection process with the highest water cut and relatively low oil viscosity. The specific characteristics of the area geology, petrophysical properties, reservoir properties, energy and temperature regimes, formation fluid properties and development indicators determined its selection as a pilot test object. For the selected pilot area, successive laboratory studies were carried out to determine the parameters of the fluid and rock, the surfactant and polymer, the formulation of the surfactant-polymer composition and filtration in the pore medium using core material. The choice of surfactants for the current conditions of the field was carried out on the basis of a hydrophilic / hydrophobic ratio for an equivalent separation between oil and synthetic solution. For this study, thermostable hydrophilic molecules from two types of surfactants are considered. Three filtration tests were carried out to assess dynamic adsorption and mechanical destruction on the prepared core material. As a result of the experiments, the oil displacement efficiency was 0.75-0.86, which is higher by 30-40% than displacement efficiency obtained during flooding (0.45). The following parameters were determined: the optimal concentrations of surfactant and polymer, the formulation of a thermally stable surfactant-polymer composition that allows achieving ultra-low phase tension and is suitable for operation in the conditions of the Lower Miocene object of the Northern Area of the White Tiger field.

References

1. Kudin E.V., Kurguzkina I.V., Nguyen The Dzung, The main principles of the experimental studies to substantiate the effectiveness of surfactant-polymer flooding for the conditions of White Tiger field (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2022, no. 8, pp. 76–80, DOI: https://doi.org/10.24887/0028-2448-2022-8-76-80

2. Ruzin L.M., Morozyuk L.M., Metody povysheniya nefteotdachi plastov (teoriya i praktika) (EOR methods (theory and practice)), Ukhta: Publ. of USTU, 2014, 127 p.

3. Surguchev M.L., Vtorichnye i tretichnye metody uvelicheniya nefteotdachi plastov (Secondary and tertiary methods of enhanced oil recovery), Moscow: Nedra Publ., 1985, 308 p.

4. Ivanov E.N., Kononov Yu.M., Selection of enhanced oil recovery methods based on analytical assessment of geological and geophysical information (In Russ.), Izvestiya Tomskogo politekhnicheskogo universiteta, 2012, no. 1, pp. 149–154.

5. Salager J.-L., Morgan J.C., Schechter R.S. et al., Optimum formulation of surfactant/water/oil systems for minimum interfacial tension or phase behavior, SPE-7054-PA, 1979,

DOI: https://doi.org/10.2118/7054-PA

6. Al-Shakry B., Shiran B. Sh., Skauge T., Skauge A., Polymer injectivity: Influence of permeability in the flow of EOR polymers in porous media, SPE-195495-MS, 2019, DOI: https://doi.org/10.2118/195495-MS

7. Sheng J.J., Leonhardt B., Azri N., Status of polymer-flooding technology, SPE-174541-PA, 2015, DOI: http://doi.org/10.2118/174541-PA

8. Stiller W., Arrhenius equation and non equilibrium kinetics: 100 years Arrhenius equation (Teubner-Texte Zur Physik, 21), Teubner, Leipzig, 1989, 170 p.

9. Winsor P.A., Binary and multicomponent solutions of amphiphilic compounds. Solubilization and the formation, structure, and theoretical significance of liquid crystalline solutions, Chemical Reviews, 1968, V. 68, no. 1, pp. 1-40, DOI: https://doi.org/10.1021/cr60251a001

10. Chun Huh, Equilibrium of a microemulsion that coexists with oil or brine, SPE-10728-PA, 1983, DOI: https://doi.org/10.2118/10728-PA

11. Sidorovskaya E.A., Adakhovskiy D.S., Tret'yakov N.Yu. et al., Integrated laboratory studies when optimizing surfactant-polymer formulations for oil deposits in Western Siberia (In Russ.), Neft' i gaz = Oil and Gas Studies, 2020, no. 6, pp. 107-118, DOI: https://doi.org/10.31660/0445-0108-2020-6-107-118

Studies of nonlinear effects in porous media have primarily focused on oil flow in both high- and low-permeability sandstones. A limited number of studies have been conducted in carbonates with permeability of less than 0.1 µm2 and quite a few studies have been performed on the flow of polymer solutions in high-permeability reservoirs in presence of residual oil. Nonlinear pattern of the flow is attributable to non-Newtonian properties, primarily pseudoplasticity. To study nonlinear effects of the flow of polymer solutions through porous media, core flood experiments were carried out on consolidated Bobrikovian core samples of production target using the developed experimental set-up. Two sets of experiments have been conducted: 1) polymer solution flow in presence of connate water and initial oil saturation (characteristic of the initial state of the reservoir); 2) polymer solution flow in presence of residual oil saturation (characteristic of fully waterflooded state of the reservoir). Based on coreflood experiments, deviation from Darcy's linear law is observed during the flow of polymer solution both through sand-pack model and core samples at small pressure gradients regardless of fluid saturation and viscosity of polymer solution. During the flow of polymer solution through core samples pressure gradient of the transition process is substantially higher than that while flowing through the sand-pack model, especially for high-viscosity fluids. Consequently, the flow rate of polymer solution in in-situ conditions should be selected such that to take into account the ultimate pressure gradient at which the transition to linear law occurs.

References

1. Bulgakova G.T., Neravnovesnye i nelineynye effekty v protsessakh dvukhfaznoy fil’tratsii (Non-equilibrium and non-linear effects in two-phase filtration processes): thesis of doctor of physical and mathematical science, Ufa, 2000.

2. Mirzadzhanzade A.Kh., Voprosy gidrodinamiki vyazkoplastichnykh i vyazkikh zhidkostey v primenenii k neftedobyche (Issue of hydrodynamics of viscoplastic and viscous liquids in application to oil production), Baku: Aznefteizdat Publ., 1959, 409 p.

3. Mirzadzhanzade A.Kh., Shakhverdiev A.Kh., Dinamicheskie protsessy v neftegazodobyche: sistemnyy analiz, diagnoz, prognoz (Dynamic processes in the oil and gas production: systems analysis, diagnosis, prognosis), Moscow: Nauka Publ., 1997, 254 p.

4. Baykov V.A., A.V. Kolonskikh, A.K. Makatrov et al., Nonlinear filtration in low-permeability reservoirs. Laboratory core examination for Priobskoye oilfield (In Russ.), Nauchno-tekhnicheskiy vestnik OAO “NK “Rosneft’”, 2013, no. 2, pp. 4–7.

5. Baykov V.A., Galeev R.R., Kolonskikh A.V., Makatrov A.K. et al., Nonlinear filtration in low-permeability reservoirs. Analisys and interpretation of laboratory core examination for Priobskoye oilfield (In Russ.), Nauchno-tekhnicheskiy vestnik OAO “NK “Rosneft’”, 2013, no. 2, pp. 8–12.

6. Suleymanov B.A., Osobennosti fil’tratsii geterogennykh sistem (Features of filtration of heterogeneous systems), Moscow –Izhevsk: Publ. of Institute for Computer Research, 2006, 356 p.

In the modern world, typification and unification acquires a special, important role in various spheres of life, influencing social, economic, and technological processes. Unification is the process of standardization, uniformity and unification of various elements or systems through the use of standard solutions. A typical solution in geology and development is a replicable best practice, in fact, it is a formalization of unique, successful, practical experience in solving problems. In a narrower sense, best practice is the best way to achieve an initially set goal. Since today the oil and gas industry is becoming not only financially attractive, but also risky for investments, it is important to optimize work in all major business segments of activity: in geology and development through the use of standard solutions; in design and survey work through the unification and standardization of equipment, typification of design solutions. To implement this direction in the field of geology and development, as a rule, a list of best practices is formed aimed at implementing standard solutions in geological exploration, laboratory core studies, conceptual design, design of oil and gas field development. The essence of the typification of technological processes is that, based on a preliminary study and analysis of the particular features inherent in a particular technology, the best achievements of practical experience are summarized, and these generalizations are given the character of technological patterns, which are then extended to the appropriate classification groups. Thus, typification implies the need for classification of technological processes, which is usually based on geological, industrial, technological and administrative-organizational conditions peculiar to a particular oil and gas producing society.

References

1. Zvorykina Yu.V., Adrianov A.K., International standardization and the competitiveness of Russian oil and gas equipment exports under western sanctions (In Russ.), Rossiyskiy vneshneekonomicheskiy vestnik, 2021, no. 7, pp. 27-42, DOI: https://doi.org/10.24412/2072-8042-2021-7-27-42

2. 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

3. 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

4. Stepanov S.V., Glukhikh I.N., Arzhilovskiy A.V., The concept of multilevel modeling as the basis of a decision-making support system for the development of mature oil fields (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2023, no. 12, pp. 112-117, DOI: https://doi.org/10.24887/0028-2448-2023-12-112-117

5. Zakrevskiy K.E., Popov V.L., Lepilin A.E., Ryzhikov E.A., Geological and technological features of creating flexible typical templates for geological modeling (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2020, no. 11, pp. 38-43, DOI: https://doi.org/10.24887/0028-2448-2020-11-38-43

6. Kravchenko A.N., Salimov O.V., Project cost management through individual process typing (In Russ.), Tekhniko-tekhnologicheskie problemy servisa, 2022, no. 4(62), pp. 57-62.

7. Vasil’ev V.V., Kravchenko A.N., Smelyanskiy V.V. et al., New horizons of standard design system at Rosneft: Geology and reservoir engineering (In Russ.),

Ekspozitsiya Neft’ Gaz, 2020, no. 5(78), pp. 12-15, DOI: https://doi.org/10.24411/2076-6785-2020-10098

8. Hart J., Phaf N., Vermeltfoort K., Saving time and money on major projects, URL: http://www.mckinsey.com/Insights/Energy_Resources_Materials/Saving_time_and_money_on_major_projects

9. Kravchenko A.N., Vasil’ev V.V., Salimov O.V., Samoylov M.I., Hydraulic fracturing. Special aspects and potential of process type assignment (In Russ.), Neftyanaya provintsiya, 2022, no. 2(30), pp. 134-149, DOI: https://doi.org/10.25689/NP.2022.2.134-149

10. Kravchenko A.N., Vasil’ev V.V., Salimov O.V., Selection of best IOR/EOR technologies based on analytic hierarchy process (In Russ.), Neftyanaya provintsiya, 2022, no. 2(30), pp. 98-110, DOI: https://doi.org/10.25689/NP.2022.2.98-110

A method has been developed to optimize the field operating mode. This involves calculating the optimal flow rates for production wells, considering both technological and economic constraints, to maximize the production of marketable products. The method was implemented using an integrated fishery model on a computer. A mathematical model has been developed to describe the objective function, which represents the total marginality of marketable product output. This model takes into account the flow rates of production wells, the component compositions of products from each well, as well as the specific marginality and component compositions of each commercial product. Technological and economic limitations have also been considered. The search for optimal flow rates of production wells, where the objective function reaches its maximum value, is conducted during a calculation stage. This stage has a duration that allows for negligible changes in the parameters affecting the objective function. The linear programming method is used to solve this optimization problem. The calculation includes the evaluation of the total marginality of marketable products, the yield and composition of each product, and the injectivity of injection wells. The optimization process is divided into five stages. Firstly, the calculation horizon and duration of the calculation stage are determined, along with the specific marginality of each commercial product and the constraints independent of the development system's throughput. Secondly, production wells participating in the optimization process are selected, and constraints dependent on the development system's throughput are set. The component compositions of products from each well and each commercial product are also calculated at this stage. Next, the optimization problem is solved for the specific calculation stage. Then, using an integrated production model, the production regime is determined based on the flow rates calculated in the previous stage. Finally, in the fifth stage, a planning regime is developed, and goals for the next design stage are set. The goal of this work is to establish a methodology and implement it in a computer program to efficiently find the optimal operating mode for the fishery. This methodology considers all technological and economic limitations.

References

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14. URL: https://oissolutions.net/wp-content/uploads/2021/11/OIS_UFAM_GAS.pdf

15. URL: https://www.aspentech.com/ru/products/msc/aspen-pims

One of the key problems in the oil and gas industry is protecting pipelines from corrosion. As a result of many years of research, a number of solutions to this problem have been proposed. The article discusses the results of studies of the reliability and strength of a cone-flare connection made from pipes welded with high-frequency currents under the influence of loads simulating real operating conditions of the pipeline. The studies were carried out for two standard sizes of pipes made of steel grades 09GSF and 09G2S. To assess the stress-strain state (SSS) of the pipe end, which arises during the manufacture of the cone-flare joint, the process of deformation of the cone and flare parts, as well as the SSS of the connection itself, was simulated depending on the influence of external factors. Calculation and modeling were carried out using the ANSYS software package. It has been established that crimping the ends of pipes (making cones) and distributing them (making flares) does not create dangerous residual SSS. Modeling showed that deformation does not cause cracks or destruction of the pipe metal. The impact of operational loads on the cone-flare connection was simulated. Based on the calculations performed, it was concluded that the compounds under study are capable of ensuring reliable operation of the pipeline under loads equivalent to the normal operating conditions of conventional pipes. To confirm the results obtained, a set of bench tests was carried out. The last stage of a comprehensive assessment of the strength characteristics of the cone-flare connection was the study of samples after operation in field conditions. The connections were operated as part of an oil gathering pipeline at one of the fields in Western Siberia. The results obtained indicate the tightness and reliable protection of the ends of the pipes from the penetration of the transported medium into the connection of the type considered. It is concluded that the manufacturing technology of the cone-flare connection ensures the preservation of the viscoplastic properties of the pipe metal in the deformed zone. The internal protective coating at the cone-flare connection creates reliable protection against the development of corrosion processes, which guarantees trouble-free operation of the pipeline.

References

1. Rodomakin A.N., Sovershenstvovanie tekhnologiy montazha neftepromyslovykh truboprovodov bez primeneniya svarki (Improving technologies for installing oilfield pipelines without welding): thesis of candidate of technical science, Ufa, 2010.

2. Novikov S.V., Prospects for the development of methods for protecting pipeline welds with internal anti-corrosion coating (In Russ.), Inzhenernaya praktika, 2016, no. 9.

3. Amosov A.P., Yudin P.E., Akulinin A.A., Modern methods of corrosion protection of equipment in petrochemical engineering (In Russ.), Naukoemkie tekhnologii v mashinostroenii, 2014, no. 8, pp. 34–40.

4. Protasov V.N., Teoriya i praktika primeneniya polimernykh pokrytiy v oborudovanie i sooruzheniya neftegazovoy otrasli (Theory and practice of using polymer coatings in equipment and structures of the oil and gas industry), Moscow: Nedra Publ., 2007, 374 p.

5. Protasov V.N., Features of technology for assembling and quality control of mechanical faucet joint made by the butler tech method of steel pipes with internal epoxy coating of oilfield pipelines (In Russ.), Territoriya Neftegaz, 2020, no. 3–4, pp. 86–93.

6. Bayburova M.M., Burmistova N.N., Mekhanicheskoe soedinenie truboprovodov (Mechanical connection of pipelines), Collected papers “Dostizheniya, problemy i perspektivy razvitiya neftegazovoy otrasli” (Achievements, problems and prospects for the development of the oil and gas industry), Proceedings of V Mezhdunarodnoy nauchno-prakticheskoy konferentsii, Al'met'evsk, 12 November 2020, Part 2, Al'met'evsk: Publ. of ASPU, 2020, pp. 16-18.

7. Kaplun A.B., Morozov E.M., Olfer'eva M.A., ANSYS v rukakh inzhenera: prakticheskoe rukovodstvo (ANSYS in the hands of an engineer: a practical guide), Moscow: Editorial URSS Publ., 2003, 272 p.

8. Fedorova N.N., Val'ger S.A., Danilov M.N., Zakharova Yu.V., Osnovy raboty v ANSYS 17 (Basics of working in ANSYS 17), Moscow: DMK Press Publ., 2017, 210 p.

9. Ioffe A.V., Revyakin V.A., Borisenkova E.A., Knyaz'kin S.A., Features of corrosion destruction of petrogas pipes under operating conditions Komi and Western Siberia (In Russ.), Vektor nauki TGU, 2010, no. 4(14), pp. 50-53.

Increasing well depths and complication well trajectories are a steady trend of the last decades in the oil and gas industry. Complex well trajectories and large displacement from the vertical lead to an increase in friction factors. It may require the use non-aqueous fluid (NAF) and drilling rigs with a higher lifting capacity. Therefore reducing the coefficient of friction is an actual technological challenge in oil and gas industry. In some cases, reducing the friction coefficient allows drill wells within the limits of project profitability without switching to technologically more complex and expensive solutions. The widely used way to reduce friction coefficient is lubricating additives.

The article considers the state of the lubricant additives market. Despite the variety of products and the abundance of specialized service companies, the industry has not developed uniform technical requirements for lubricant additives. The authors demonstrate differences in the requirements of service companies and note the fact that the requirements for the same class products differ in the same service company. The critical role of model drilling fluid in laboratory lubricity testing is noted. Most service companies and manufacturers use clay slurries in their tests, which significantly differ from the drilling fluids used in well construction. Data demonstrating the difference in friction coefficient reduction in different fluids are presented. Rosneft Oil Company specialists developed a unified testing methodology and a list of technical requirements for lubricant additives taking into account actual drilling conditions. The demonstrated approach was implemented as part of a pilot project at the facilities of RN-Yuganskneftegas LLC.

References

1. Schamp J.H., Estes B.L., Keller S.R., Torque reduction techniques in ERD wells, SPE-98969-MS, 2006, DOI: https://doi.org/10.2118/98969-MS

2. Patel A., Zhang J.H., Ke M., Panamarathupalayam B., Lubricants and Drag reducers for oilfield applications - Chemistry, performance, and environmental impact, SPE-164049-MS, 2013, DOI: https://doi.org/10.2118/164049-MS

3. Sherman S., Quintero H., Moriyama C. et al., Optimization of metal-on-metal lubricants for coil tubing applications, SPE-185746-MS, 2017, DOI: https://doi.org/10.2118/185746-MS

4. Amanullah Md, Arfaj M.K., ARC Eco-Lube - A food industry waste-based green lubricant, SPE-188910-MS, 2017, DOI: https://doi.org/10.2118/188910-MS

5. Amanullah Md., Coefficient of friction reducing efficiency of ARC Eco-Lube, SPE-180504-MS, 2016, DOI: https://doi.org/10.2118/180504-MS

6. Yunfeng Liu, Zhengsong Qiu, Hanyi Zhong et al., Development of a novel anti-temperature, anti-wear and ecofriendly lubricant SDL-1 for water-based drilling fluid, IPTC-19406-MS, 2019, DOI: https://doi.org/10.2523/IPTC-19406-MS

This article explores the results obtained following a field and bench study of sampling devices (SD). The experimental research was conducted to determine the actual representativeness of samples obtained via SDs. The experimental bench research was completed in order to determine the actual representativeness values pertaining to SD samples when changing pumping parameters (flow velocity, diameter of the passage section upstream of the SD and the initial water concentration in the experimental bench) and to which extent the flow velocity and its turbulation affect the representativeness of samples obtained via SDs. The experimental field research was completed aiming to compare the representativeness of samples obtained via SDs and a plug cock conforming to state standard GOST 24200-80. The experimental bench research was conducted utilizing SDs with rated diameters of 80, 100, 150 mm with one and five holes. The experimental field research was completed using an SD with a rated diameter of 700 mm and a plug cock with a rated diameter of 10 mm. The experimental research produced the results describing local resistances and flow velocity efficiency on sample representativeness; relationship between sample representativeness and volumetric water content; actual volumetric water content in samples obtained with SDs and with a plug cock. The results of SD studies show that it is impossible to determine a unified SD design that would provide improved sample representativeness for all modes of SD operation. Sample representativeness for a particular SD (if necessary) can be improved by developing a dedicated methodology employed to recalculate its design parameters conforming to specific operating conditions.

References

1. Buyanov I.V., Aralov O.V., Korolenok A.M. et al., Main results of sampling equipment study (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2022, no. 4, pp. 86-89, DOI: https://doi.org/10.24887/0028-2448-2022-4-86-89

2. Goryunova S.M., Mukhametkhanova L.M., Petukhova L.V., Nikolaeva N.G., Problems of metrological support of the Russian oil complex (In Russ.), Vestnik Kazanskogo tekhnologicheskogo universiteta, 2011, no. 11, pp. 263-266.

3. Yagudin I.R., Petrov V.N., Dresvyannikov A.F., A promising direction in the development of mobile calibration units for measuring crude oil (In Russ.), Vestnik Kazanskogo tekhnologicheskogo universiteta, 2013, no. 4, pp. 203-208.

4. Aralov O.V., Korolenok A.M., Buyanov I.V. et al., Mathematical modeling of devices for sampling oil and oil products from pipelines (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2020, no. 12, pp. 128–130, DOI: https://doi.org/10.24887/0028-2448-2020-12-128-130

5. Solov’ev V.G., Varsegov V.L., Malyshev S.L., Petrov V.N., Development and creation of state primary special standard of a mass flow-rate unit of get 195-2011 gas-liquid mixtures (In Russ.), Vestnik KGTU im. A.N. Tupoleva, 2013, no. 3, pp. 32-38.

6. Petrov V.N., Malyshev S.L., Mukhametshina G.F., On the issue of controlling the process of circulating mixing (In Russ.), Vestnik Kazanskogo tekhnologicheskogo universiteta, 2016, no. 13, pp. 81-83.

7. Tukhvatullin A.R., Korneev R.A., Kolodnikov A.V. et al., Attestatsiya etalonov edinits massovogo i ob»emnogo raskhodov zhidkosti (In Russ.), Vestnik Kazanskogo tekhnologicheskogo universiteta, 2012, no. 18, pp. 245-247.

8. Kupkenov R.R. et al., Oil products purity monitoring in transportation through the main pipelines (In Russ.), Nauka i tehnologii truboprovodnogo transporta nefti i nefteproduktov = Science & Technologies: Oil and Oil Products Pipeline Transportation, 2019, V. 9, no. 3, pp. 342–352, DOI: https://doi.org/10.28999/2541-9595-2019-9-3-342-352

Efficient disposal of multi-tonnage waste from oil production is one of the most pressing environmental problems. The volume of oil production wastes is growing and amount to hundreds of thousands of cubic meters. These wastes are dangerous pollutants for ecosystems. In addition, the storage site of oil production waste is contaminated with petroleum products. The heavy fractions contained in oil slurries, as a rule, are sedentary and create stable foci of pollution, purification of the natural environment from them proceeds slowly and with great difficulty. In modern economic conditions it is very important to make optimal decisions on the use of oil production waste in recycling of waste with the reuse of raw materials for their intended purpose, which will give a significant social and economic effect. Since natural raw materials are currently being depleted, it is necessary to involve waste from oil production in the production turnover for the production of thermal insulation materials: porous aggregates and porous bricks. At the same time, the costs of geological exploration, construction and operation of quarries are excluded, and significant land plots are exempt from the impact of negative anthropogenic factors. Smeared soil from oil production with an increased content of calorific value (3600 cal/kg) is advisable to use not only as a filler, but also as a burnout and swelling additives for the production of porous aggregates. A porous aggregate of the M250 grade with high physical and mechanical properties was obtained.

References

1. Abdrakhimov V.Z., Kayrakbaev A.K., Ekologicheskiy menedzhment (Environmental management), Aktobe: Publ. of Aktobe University named after S. Baishev, 2019, 240 p.

2. Abdrakhimov V.Z., Kontseptsiya sovremennogo estestvoznaniya (Concept of modern natural science), Samara: Publ. of Samara State the University of Economics, 2015, 340 p.

3. Kayrakbaev A.K., Abdrakhimova E.S., Recycling of waste from the fuel and energy complex, non-ferrous metallurgy and petrochemical industry in the production of non-burning heat-resistant concretes (In Russ.), Ekologiya promyshlennogo proizvodstva, 2020, no. 3, pp. 5-12.

4. Abdrakhimova E.S., Abdrakhimov V.Z., Recycling of waste fuel-energy complex, oil production and petrochemistry in the production of earthquake-resistant bricks (In Russ.), Burenie i neft', 2020, no. 10, pp. 42-49.

5. Abdrakhimov V.Z., Abdrakhimova E.S., Oxidation processes in the firing of porous filler based on oil production wastes and intershale clay, Theoretical Foundations of Chemical Engineering, 2020, V. 54, no. 4, pp. 750–755, DOI: http://doi.org/10.1134/S0040579519050026

6. Gennadiev A.N., Pikovskiy Yu.I., Tsibart A.S., Smirnova M.A., Hydrocarbons in soils: Origin, composition, and behavior (Review) (In Russ.), Pochvovedenie, 2015, no. 10, pp. 1195–1209, DOI: http://doi.org/10.7868/S0032180X15100020

7. Mao D., Lookman R., Van de Weghe H. et al., Estimation of ecotoxicity of petroleum hydrocarbon mixtures in soilbased on HPLC – GCXGC analysis, Chemosphere, 2009, V. 77, no. 1, pp. 1508–1513, DOI: http://doi.org/10.1016/j.chemosphere.2009.10.004

8. Jingchun Tang, Xueqiang Lu, Qing Sun, Wenying Zhu, Aging effect of petroleum hydrocarbons in soil under different attenuation conditions, Agriculture, Ecosystems Environment, 2012, V. 149, pp. 109–117, DOI: http://doi.org/10.1016/j.agee.2011.12.020

9. Chang W., Dyen M., Spagnuolo L. et al., Biodegradation of semi- and non-volatile petroleum hydrocarbons in aged, contaminated soils from a sub-Arctic site: Laboratory pilot-scale experiment at site temperatures, Chemosphere, 2010, V. 80, pp. 319–326, DOI: http://doi.org/10.1016/j.chemosphere.2010.03.055

10. Pinedo J., Ibbez R., Lizen J.P.A., Irabien A., Human risk assessment of contaminated soils by oil products: total TPH content versus fraction approach, Human and Ecological Risk Assessment: An International Journal, 2014, V. 20, no. 5, pp. 1231–1248, DOI: http://doi.org/10.1080/10807039.2013.831264

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DOI: http://doi.org/10.1007/978-3-540-69371-0_18

12. Pao-Wen Liu, Tsung Chain Chang, Chih-Hung Chen et al., Effects of soil organic matter and bacterial community shift on bioremediation of diesel-contam-inated soil, International Biodeterioration & Biodegradation, 2013, V. 85, pp. 661–670, DOI: http://doi.org/10.1016/j.ibiod.2013.01.010

13. Abdrakhimova E.S., Abdrakhimov V.Z., Highly porous thermal insulation material based on liquid glass (In Russ.), Fizika i khimiya stekla, 2017, V. 143, no. 2, pp. 222–230.

14. Patent RU 2426710 S1, Method for production of porous filler, Inventors: Abdrakhimov V.Z., Semenychev V.K., Kulikov V.A., Abdrakhimova E.S.