The article considers the features of the seismic processing and interpretation stages aimed at improving the efficiency of reservoir property prediction for continental genesis formations. The effectiveness of using diffracted waves to refine the structure of meandering objects is demonstrated as a new methodological approach. The features of diffraction seismograms post-processing are considered. These features are necessary to obtain informative results when mapping the structure of continental genesis formations in the field of diffracted waves. Methodological approaches for the following stages are also proposed: object-oriented processing, constructing a sequence stratigraphic model for continental sediments using the example of the Yakovlev formation, features of correlation of reflecting horizons, performing inversion transformations and comparing the effectiveness of various attributes in mapping meandering objects and other elements of erosive relief. The effectiveness of the methodological approaches proposed in the article is demonstrated by the example of two metrics. First metric is the average percentage of conducting production wells through the reservoir at the field. The second metric is the average percentage of reservoir prediction confirmation based on seismic data in horizontal wells before and after applying the methodological approaches described in the article. These metrics directly affect the economic efficiency of the developed deposit. They can be used to assess financial efficiency when planning and justifying future similar work.

References

1. Posamentier H.W., Vail P.R. Eustatic controls on clastic deposition II – Sequence and systems tract models: edited by Wilgus C.K., Hastings B.S., Kendall C.G., Posamentier H.W., Ross C.A., van Wagoner J.C., In: Sea level changes – An integrated approach. SEPM Special Publication, 1988, V. 42, P. 125–154,

DOI: http://doi.org/10.2110/pec.88.01.0125

2. Van Wagoner J.C., Mitchum R.M., Posamentier H.W., Vail P.R., Seismic stratigraphy interpretation using sequence stratigraphy. Part 2: Key definitions of sequence stratigraphy: edited by Bally A.W., Atlas of seismic stratigraphy. AAPG Studies Geol., 1987, V. 1, no. 27, pp. 11—14, DOI: https://doi.org/10.1306/bf9ab166-0eb6-11d7-8643000102c1865d

3. Shanley K.W., McCabe P.J., Perspectives on the sequence stratigraphy of continental strata, American Association of Petroleum Geologists Bulletin, 1994, V. 78,

p. 544–568, DOI: https://doi.org/10.1016/S0070-4571(09)06205-0

4. Posamentier H.W., Allen G.P., Siliciclastic sequence stratigraphy: concepts and applications, SEPM, Concepts Sedimentol. Paleontol., 1999, V. 7,

DOI: https://doi.org/10.1029/EO082i013p00156

5. Fokin P.A. et al., Composition and conditions of formation of productive strata of the Nizhnekhetskaya and Yakovlevskaya suites of the Lower Cretaceous Vankor oil and gas field (northeast of Western Siberia) (In Russ.), Vestnik Moskovskogo universiteta. Seriya 4. Geologiya = Moscow University Bulletin. Series 4. Geology, 2008, no. 5, pp. 12-18.

6. Cherdantseva D.A., Krasnoshchekova L.A., Material composition and formation conditions of productive sandstoons of the Pur-Tazov oil and gas-being region

(on the example of Lodochnoe field, Krasnoyarsky Krai) (In Russ.), Geosfernye issledovaniya, 2021, no. 2, pp. 44-59, DOI: https://doi.org/10.17223/25421379/19/4

The article considers the creation of a detailed geological model of the upper subformation sediments of the Tyumen formation to improve the accuracy of reservoir properties forecasting and reserves localization. Based on a detailed analysis of core material 2 sedimentation environments were identified: a meandering river system in the interval of the YuS3 formation and transitional delta deposits in the interval of the YuS2 formation. The sedimentation conditions are described by a complex of facies, combined into 4 macrofacies in the YuS2 formation interval (shelf, submarine ridges, marshes and swamps, sandbanks and gullies, delta channels) and into 3 macrofacies in the YuS3 formation interval (floodplains and swamps, crevasse glyph, river channel). The best poro-perm properties are in the facies of the delta channel and river bed, transitional properties - in the facies of underwater ridges, beaches, shoals and gullies, crested glyph, the worst - in the facies of floodplains, marshes and swamps. The high poro-perm properties are connected with the active dynamics of the aquatic environment in which the sediments accumulated. Macrofacies are characterized based on well logging data: average poro-perm parameters, boundary porosity values for identifying reservoirs are specified. The high poro-perm reservoir is concentrated in the facies of the river-bed, delta channel and underwater ridge. Facies maps of sediments are compiled using 3D seismic interpretation (spectral decomposition cube sections and other attributes). A detailed geological model with quantitative morphological parameters of facies was obtained which enables to develop hydrocarbon reserves of tight-oil deposits of the Tyumen formation.

References

1. Walker R.G , James N.P., Facies models: response to sea level change, Geological Association of Canada, 1992.

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.

3. Kontorovich A.E., Kontorovich V.A., Ryzhkova S.V. et al., Jurassic paleogeography of the West Siberian sedimentary basin (In Russ.), Geologiya I geofizika = Russian Geology and Geophysics, 2013, V. 54, no. 8, pp. 972–1012.

4. Isakova T.G., Persidskaya A.S., Khotylev O.V. et al., Typification of the deposits of the Tyumen Formation according to the degree of hydrodynamic conditions of sedimentation to create a petrophysical model and differentiated interpretation of well log data (In Russ.), Georesursy = Georesources, 2022, V. 24, no. 2, pp. 172–185,

DOI: https://doi.org/10.18599/grs.2022.2.16

5. Gabdullina G.T., Suleymanov E.D., Kararova A.Z., Fakhrutdinova A.M., Update of petrophysical and geological model of Middle Jurassic deposits during well monitoring (In Russ.), Neftegazovoe delo, 2024, V. 22, no. 3, pp. 8–18, DOI: https://doi.org/10.17122/ngdelo-2024-3-8-18

6. Muromtsev V.S., Elektrometricheskaya geologiya peschanykh tel – litologicheskikh lovushek nefti i gaza (Electrometric geology of sand bodies - lithological traps of oil and gas), Leningrad: Nedra Publ., 1984, 260 p.

7. Oreshkova M.Yu., Ol’neva T.V., Kompleksnyy podkhod k modelirovaniyu geometrizatsii otlozheniy paleoruslovykh sistem tyumenskoy svity Zapadno-Sibirskogo neftegazonosnogo basseyna (An integrated approach to modeling the geometrization of sediments of paleochannel systems of the Tyumen suite of the West Siberian oil and gas basin), Collected papers “Seysmorazvedka v Sibiri i za ee predelami” (Seismic exploration in Siberia and beyond), Proceedings of nauchno-prakticheskoy konferentsii, 2023, pp. 129–134.

The paper considers the features of changes in reservoir properties of productive formations of the lower subsuite of the Pokurskaya formation depending on their lithological and mineralogical composition, texture of rocks, filtration-capacitive and porometric characteristics. The feature of the studied formation is its high geological heterogeneity, both vertically and laterally. As a result of the complex analysis of geophysical well logs and laboratory studies of core, it was established that according to petrophysical properties productive deposits can be divided into several petrotypes. The petrotypes in this work are defined as separate groups of rocks characterized by common key parameters: porosity, clay content, residual water abundance, permeability. These coefficients are interrelated and depend on mineralogical and granulometric composition, pore space structure, wettability and other factors reflecting the conditions of sedimentation and subsequent secondary transformations. The analysis of the core sample collection in the section has identified five main petrotypes: massive rocks, layered rocks, clay rocks, carbonized (dense) and angular rocks. For further prediction of petrotypes in wells without core selection, qualitative and quantitative criteria on the standard set of geophysical well logging are justified. The criteria obtained can be used both to clarify the filtration and capacity properties of the section during geological modeling and to make operational decisions on adjusting the drilling trajectory when drilling horizontal wells.

References

1. Kasatkin V.V., Svetlov K.V., Miropol'tsev KF., Shilov Yu.I., Correlation of continental genesis strata: the case of the Pokur formation of the Beregovoye field (In Russ.), Aktual'nye problemy nefti i gaza, 2021, no. 4(35), pp. 13–20, DOI: https://doi.org/10.29222/ipng.2078-5712.2021-35.art2

2. Kontorovich A.E., Ershov S.V., Kazanenkov V.A. et al., Cretaceous paleogeography of the West Siberian sedimentary basin (In Russ.), Geologiya i geofizika = Russian Geology and Geophysics, 2014. V. 55, no. 5, pp. 745–776.

3. Privalova O.R., Taygina M.E., Asylgareev I.N., Integration of well logging surveys and core research data to substantiate the operation of productive intervals using the example of poorly studied Cenomanian carbonate deposit (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2024, no. 9, pp. 45–49,

DOI: https://doi.org/10.24887/0028-2448-2024-9-45-49

4. Amineva G.R., Burikova T.V., Savel'eva E.N. et al., Criteria for revealing petrophysical rock types using well logging in the Middle Carboniferous section of oil fields in North-Western Bashkortostan (In Russ.), Vestnik akademii nauk RB, 2020, V. 35, no. 2, pp. 26–35, DOI: https://doi.org/10.24411/1728-5283-2020-10203

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

In modern practice the allocation of reservoirs within productive formations is usually carried out using boundary values of porosity, permeability and oil saturation determined by the results of core research. At the same time back in the 80s V.D. Ilyin and other researchers proposed a model of the three-layer structure of natural reservoirs, which implies, that hydrocarbon deposits consist of reservoirs, «true» fluid seals and «false» ones (formations of dispersion). The object of the study is an oil field located in the northeastern part of the Timan-Pechora oil and gas province. The productive section of the studied field is represented by two layers: the lower one is located in the deposits of the Gzhelsky tier of the Upper Carboniferous, the upper one is in the deposits of the Asselsky tier of the Lower Permian. The basis for the study was a complex of geological and geophysical studies of 30 wells, the results of laboratory core studies of 6 wells, the results of well tests, as well as reservoir pressure measurements based on hydrodynamic logging data in 2 wells. This article presents the results confirming the possibility of a three-layer structure of natural reservoirs in carbonate rocks, a method for allocation fluid seals and formations of dispersion according to a complex of geological and geophysical studies and the results of laboratory core analysis, as well as substantiation of the allocating fluid seal. The materials for this publication were prepared in collaboration with Oil and Gas Research Institute of RAS.

References

1. Zhuravlev V.A., Korago E.A., Kostin D.A. et al., Gosudarstvennaya geologicheskaya karta Rossiyskoy Federatsii. Masshtab 1:1 000 000 (State geological map of the Russian Federation. Scale 1: 1,000,000), Seriya Severo-Karsko-Barentsevomorskaya. List R-39,40 – o. Kolguev – proliv Karskie Vorota. Ob"yasnitel'naya zapiska (Series North-Kara-Barents Sea. Sheet R-39.40 - Kolguev Island - Kara Gate. Explanatory letter), St. Petersburg: Publ. of Kartograficheskaya fabrika VSEGEI, 2014, 405 p.

2. Shaburova M.E., Orlov N.N., Allocation of improved filtration and reservoir properties zones using the example of an oil field in the Timan-Pechora oil and gas province (In Russ.), Ekspozitsiya Neft' Gaz, 2024, no. 4, pp. 16–21,

DOI: https://doi.org/10.24412/2076-6785-2024-4-16-21

3. Sotnikova A.G., Oil and gas accumulation zones and the priority directions of renewal of oil reserves in the carbonate complexes, Varandey-Adzvinsky aulacogen (In Russ.), Neftegazovaya geologiya. Teoriya i praktika, 2010, no. 5,

URL: http://www.ngtp.ru/rub/6/4_2010.pdf

4. Suvorova E.B., Lithology and sedimentary environments of the Upper Visean - Lower Permian strata of the Pechora offshore (In Russ.), Neftegazovaya geologiya. Teoriya i praktika, 2012, V. 7, no. 2,

URL: http://www.ngtp.ru/rub/2/25_2012.pdf

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, 258 p.

6. Il'in V.D. et al., Lokal'nyy prognoz neftegazonosnosti na osnove analiza stroeniya lovushek v trekhsloynom rezervuare: Metodicheskie rekomendatsii (Local forecast of oil and gas potential based on the analysis of the structure of traps in a three-layer reservoir: Methodological recommendations), Moscow: Publ. of VNIGNI, 1982, 52 p.

7. Il'in V.D. et al., Prognoz neftegazonosnosti lokal'nykh ob"ektov na osnove vyyavleniya lovushek v trekhchlennom rezervuare: Metodicheskie ukazaniya (Forecast of oil and gas potential of local objects based on detection of traps in a three-member reservoir: Methodological guidelines), Moscow: Publ. of VNIGNI, 1986, 68 p.

8. Larskaya E.S. et al., Regional'nyy i lokal'nyy prognoz neftegazonosnosti (Regional and local forecast of oil and gas potential), Moscow: Nedra Publ., 1987, 237 p.

9. Khitrov A.M, Il'in V.D., Savinkin P.T., Vydelenie, kartirovanie i prognoz neftegazonosnosti lovushek v trekhchlennom rezervuare: Metodicheskoe rukovodstvo (Identification, mapping and forecasting of oil and gas potential of traps in a three-member reservoir: Methodological guide), Moscow: Publ. of VNIGNI, 2002, 36 p.

10. Khitrov A.M., Danilova E.M., Konovalova I.N., Popova M.N., Geological exploration risks of near-fault hydrocarbon deposits (In Russ.), Problemy ekonomiki i upravleniya neftegazovym kompleksom, 2023, no. 4, pp. 20–32,

DOI: https://doi.org/10.33285/1999-6942-2023-4(220)-20-32

Currently, when assessing the state of the raw material base and the general forecast for the development of oil production, specialists often deal with the concept of production by reserves, reflecting the guaranteed duration of involvement of current recoverable reserves in active development. However, these ranges of coverage can vary considerably. Modern reserve estimation approaches and improved production technologies can significantly affect the amount of available reserves and, accordingly, the probability indicator. An algorithm for forming justifications for finding arguments for conducting seismic surveys in order to reassess the reserves of objects with low multiplicity of reserves was developed in this work. Seven fields on the territory of the Republic of Bashkortostan were considered. A retrospective analysis of seismic surveys of previous years made it possible to verify the validity of their implementation in the form of the discovery of new deposits, expansion of existing ones or combining previously isolated ones into a single contour. Twenty-five structures for five fields with a potential increase in initial recoverable reserves were identified as a result of estimation of reserves coverage for the field as a whole and for borderline producing wells. In the most promising areas in terms of potential growth of reserves, seismic surveys were proposed to verify the remaining recoverable reserves.

References

1. Gayduk A.V., Tverdokhlebov D.N., Dan'ko E.A. et al., Effective seismic technologies for new geological discoveries in East Siberia (In Russ.), Geodinamika i

tektonofizika = Geodynamics & Tectonophysics, 2021, V. 12, no. 3S, pp. 683–702, DOI: http://doi.org/10.5800/GT-2021-12-3s-0547

2. Baymukhametov K.S., Viktorov P.F., Gaynullin K.Kh., Syrtlanov A.Sh., Geologicheskoe stroenie i razrabotka neftyanykh i gazovykh mestorozhdeniy Bashkortostana

(Geological structure and development of Bashkortostan oil and gas fields), Ufa: Publ. of RITs ANK Bashneft', 1997, 424 p.

3. Lozin E.V., On tectonics preconditions to form an oil and gas deposits (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2021, no. 4, pp. 18–22,

DOI: http://doi.org/10.24887/0028-2448-2021-4-18-22

4. Bembel' S.R., Modelirovanie slozhnopostroennykh zalezhey nefti i gaza v svyazi s razvedkoy i razrabotkoy mestorozhdeniy Zapadnoy Sibiri (Modeling of complex oil and gas deposits in connection with the exploration and development of oil fields in Western Siberia): thesis of geological and mineralogical science, Tyumen, 2011.

5. Lozin E.V., Geologiya i neftenosnost' Bashkortostana (Geology and oil content of Bashkortostan), Ufa: Publ. of BashNIPIneft', 2015, 704 p.

6. Kuz'michev O.B., Gazizov R.K., Vlasov S.V., Antonov M.S., The unified information system of geological and geophysical data is the basis of a multidisciplinary approach to the exploration and production of hydrocarbons (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2024, no. 2, pp. 8–13, DOI: http://doi.org/10.24887/0028-2448-2024-2-8-13

7. Muslimov R.Kh., The role of new geological ideas in the development of old oil-producing areas in the first quarter of the 21st century (In Russ.), Uchenye zapiski Kazanskogo gosudarstvennogo universiteta. Ser.: Estestv. Nauki, 2005, V. 147, URL: https://kpfu.ru/portal/docs/F600789687/147_01_est_5.pdf

The present work is devoted to the study of natural processes, such as inversions and excursions of the Earth's geomagnetic poles, which presumably can initiate processes that promote the formation of hydrocarbons (HC) and their subsequent geochemical transformation. The article contains scientific-deterministic substantiation of the necessity to test this hypothesis, which arose in the course of development of the concept of I.I. Nesterov (Corresponding Member of the RAS), devoted to the role of radical reactions in the formation of HC deposits when certain thermobaric and energetic conditions are reached, arising due to the discreteness of natural geomagnetic fields. The occasion for consideration of this problem is the results of laboratory experiments published from 2019 to 2023, indicating to the fact that the magnetic field can act as a catalyst in radical reactions. The paper highlights the problems associated with the classical sedimentary-migration theory of HC deposit formation, and offers an alternative view of the natural processes that lead to the formation of oil deposits. Conceptually, the study is based on the biogenic theory of HC origin, but denies the possibility of their migration over significant distances, confirming the in situ principle. A deep understanding of the mechanisms of oil and gas deposit formation can contribute to the development of effective technologies for their extraction, including non-standard solutions for the recovery of hard-to-recover reserves and the creation of new oil and gas reservoirs.

References

1. Nesterov I.I., Ushatinskiy I.N., Malykhin A.Ya. et al., Neftegazonosnost' glinistykh porod Zapadnoy Sibiri (Oil and gas potential of clay rocks in Western Siberia), Moscow: Nedra Publ., 1987, 256 p.

2. Tissot B.P., Welte D.H., Petroleum formation and occurrence, Springer-Verlag Telos, 1984, 699 p.

3. Hunt J.M., Petroleum geochemistry and geology, W.H. Freeman, 1996, 743 p.

4. Vassoevich N.B., Geokhimiya organicheskogo veshchestva i proiskhozhdenie nefti: izbrannye trudy (Geochemistry of organic matter and the origin of oil: Selected works), Moscow: Nauka Publ., 1986, 368 p.

5. Nesterov I.I., Problemy geologii nefti i gaza vtoroy poloviny KhKh veka (Problems of oil and gas geology in the second half of the twentieth century), Novosibirsk: Publ. of SB RAS, 2007, 608 p.

6. Nezhdanov A.A., Smirnov A.S., Flyuidodinamicheskaya interpretatsiya seysmorazvedochnykh dannykh (Fluid dynamic interpretation of seismic data), Tyumen: Publ. of TIU, 2021, 291 p.

7. Melenevskiy V.N., Modeling of catagenetic transformation of organic matter from a Riphean mudstone in hydrous pyrolysis experiments: Biomarker data (In Russ.), Geokhimiya = Geochemistry International, 2012, no. 5, pp. 470-482.

8. Nesterov I.I., Genesis and formation of hydrocarbon accumulations (In Russ.), Geologiya nefti i gaza, 2004, no. 2, pp. 38–47.

9. Nesterov I.I., Black shale oil (In Russ.), Izvestiya vysshikh uchebnykh zavedeniy. Neft' i gaz, 1997, no. 5, pp. 46–52.

10. Nesterov I.I., Pecherkin M.F., Urayskiy neftegazovyy kompleks Zapadnoy Sibiri: k 50-letiyu nachala dobychi nefti i gaza v Zapadnoy Sibiri i k 55-letiyu otkrytiya UNGK (The Urai oil and gas complex of Western Siberia: on the 50th anniversary of the start of oil and gas production in Western Siberia and on the 55th anniversary of the opening of the Urai oil and gas complex of Western Siberia), Tyumen: Siti-press Publ., 2015, 352 p.

11. Poluboyarov V.A., Andryushkova O.V., Bulynnikova M.Yu. et al., Changes in the structure and composition of organic substances under the influence of electron irradiation (In Russ.), Sibirskiy khimicheskiy zhurnal, 1992, no. 2, pp. 118–124.

12. Poluboyarov V.A., Andryushkova O.V., Gladyshev Yu.G. et al., Elektronnye paramagnitnye tsentry prirodnykh organicheskikh veshchestv pri pirolize (Electron paramagnetic centers of natural organic substances during pyrolysis), Novosibirsk: Publ. of Institute of Solid State Chemistry and Mineral Processing of the Siberian Branch of the USSR Academy of Sciences, 1988.

13. Nesterov I.I., Kashirtsev V.A., Melenevskiy V.N., Adamantanes of oils in West-Siberian Cenomanian deposits (In Russ.), Gornye vedomosti, 2011, no. 6(85),

pp. 82–88.

14. Nesterov I.I., Aleksandrov V.M., Ponomarev A.A. et al., Experimental studies of radical reactions of hydrocarbons conversion (In Russ.), Izvestiya vysshikh uchebnykh zavedeniy. Neft' i gaz, 2019, no. 4, pp. 57–69.

15. Ponomarev A.A. et al., Impact of geomagnetic fields on the geochemical evolution of oil, Processes, 2022, V. 10, no. 11, DOI: http://doi.org/10.3390/pr10112376

16. Ponomarev A.A. et al., A new set of search criteria for oil deposits in oil-bearing sediments based on geochemical and geophysical information, Journal of Petroleum Science and Engineering, 2022, V. 208, DOI: http://doi.org/10.1016/j.petrol.2021.109794

17. Ponomarev A.A. et al., Magnetic field impact on geochemistry of soluble organic matter when heat-treating oil shales and search for analogies in nature, Physics and Chemistry of the Earth, Parts A/B/C, 2023, V. 129, DOI: http://doi.org/10.1016/j.pce.2022.103306

18. Ponomarev A.A. et al., Controversial issues of hydrocarbon field formation and the role of geomagnetic fields, International Journal of Geophysics, 2022, V. 2022,

no. 1, DOI: http://doi.org/10.1155/2022/2834990

The article introduces a method to calculate the depth for surface casing and inter-mediate casing setting in wells where gas, oil and water shows might occur. The described method refines and specifies the requirements of current regulations. The surface casing shoe depth must cover unstable rock formations prone to fluidity, prevent rock fractures during cement hydrotesting after drilling the casing shoe. It also enables to avoid rock fractures in open hole below the shoe due to internal pressure when replacing drilling fluid with reservoir fluids or mixed fluids from different layers. These rules are written as systems of equations and inequalities, covering cases where the well is filled with oil, gas and gas-liquid mixtures. Manual depth calculation is possible using these formulas, but it involves complex steps and sequential condition checks. To simplify this, a computer program was developed to automate the process of calculation. An example of a field in Western Siberia illustrates the method. It includes the surface casing depth calculation as well as pressure for testing the surface casing and its cement seal calculation. This approach is suitable for designing oil and gas wellbore construction. It enhances reliability and safety in challenging drilling conditions, offering a practical tool for engineers.

References

1. Federal norms and rules in the field of industrial safety “Pravila bezopasnosti v neftyanoy i gazovoy promyshlennosti” (Safety rules in the oil and gas industry),

URL: http://docs.cntd.ru/document/499011004

2. Instruktsiya po ispytaniyu obsadnykh kolonn na germetichnost' (Instructions for testing casing columns for tightness), Moscow: Publ. of VNIITneft', 1999, 36 p.

3. Instruktsiya po raschetu obsadnykh kolonn dlya neftyanykh i gazovykh skvazhin (Instructions for calculating casing columns for oil and gas wells), Moscow: Publ. of VNIITneft', 1997, 194 p.

4. Kayugin A.A., On a calculation of surface casing pipe RIH depth and the presence of several oiland water-saturated layers in the cross-section (In Russ.), Neft'. Gaz. Novatsii, 2018, no. 11, pp. 48–51.

5. Kayugin A.A., The features of surface casing setting depth choice in wells with several oil-gas-water saturated reservoirs (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2021, no. 8, pp. 40–43, DOI: https://doi.org/10.24887/0028-2448-2021-8-40-42

6. Kal'chenko A.A., Kayugin A.A., Ryabtsev E.A., An overview of the specialized software being developed by the drilling research department of the Tyumen branch of Surgutnipineft PJSC Surgutneftegaz (In Russ.), Neft'. Gaz. Novatsii, 2024, no. 9, pp. 66–71.

References

1. Oganov A.S., Raykhert R.S., Tsukrenko M.S., Problems of the quality of cleaning directional and horizontal wellbores from cuttings (In Russ.), Neftegaz.RU, 2015, no. 6, pp. 32-38.

2. Utility patent RU215132U1, Centrator-turbulizer for drill pipes, Inventors: Babichev I.N., D’yakonov A.A., Khuzina L.B., Nabiullin D.R., Khuzin B.A.

3. Nabiullin D.R., D’yakonov A.A., Khuzina L.B., Results of numerical simulation of washing liquid hydrodynamic flow near a centralizer-turbolizer (In Russ.), Stroitel’stvo neftyanykh i gazovykh skvazhin na sushe i na more, 2024, no. 4(376), pp. 10–14.

4. Nabiullin D.R., D’yakonov A.A., Khuzina L.B., Theoretical studies of the turbulizing ability of a turbine centralizer with various profiles (In Russ.), Stroitel’stvo neftyanykh i gazovykh skvazhin na sushe i na more, 2024, no. 3(375), pp. 10–16..

At the present stage of development of oil and gas fields of the Volga-Ural region, one of the most effective areas is the drilling of directional wells, including those with a horizontal wellbore end. The use of horizontal wells enables to reduce the amount of vertical well stock and increase the coefficient of extraction of hydrocarbons. When drilling directional and horizontal wells, many problems arise, one of the most common is sticking and tightening caused by the accumulation of cuttings in the well. The technology of hydromechanical cleaning using a centralizer - turbulator for drill pipes with a rotating element was developed at the Drilling Department of Almetyevsk State Technological University «Petroleum Higher School». The technology is based on the creation of a developed turbulent flow of liquid, preventing the accumulation of cuttings in the directional sections of a well. A theoretical model is substantiated, allowing to consider the flow of washing liquid in the vicinity of the centralizer using analytical methods, which enabled to reveal that the change in the direction of the flow significantly increases the turbulizing ability of the proposed technology of hydromechanical cleaning from cuttings of inclined sections of the well, a centralizer - turbulator for drill pipes with a rotating element, due to the increase in the local Reynolds number. A hydraulic calculation was carried out, which concluded that, at the place of installation of the centralizer-turbulator, there is a local decrease in the required flow rate of liquid for the removal of cuttings.

One of the important tasks in well construction is the isolation of the oil and gas reservoirs during drilling from the permeable layers in the upper and lower intervals. The most common technological method for solving this problem is to close the productive horizons with protective pipelines and harden the annular space with cement slurry. Due to the fact that the casing reinforcement is carried out at the last stage of well construction, the high-quality execution of the process is of particular importance. Minimizing any failure can lead to underestimation of the field potential, production losses, gas-oil-water manifestations, and the creation of griffins. The water-cement factor plays a major role in regulating the rheological parameters of the cement slurry. Thus, 22-23% of water is required for clinker hydration. To increase its fluidity, the amount of water is increased to 45-50% of dry cement. With the addition of light additives, this figure increases to 100-120%. During cementation, the processes of sedimentation and filtration in the cement slurry under high thermobaric conditions increase the permeability of the resulting stone, worsen the strength properties and ultimately violate the integrity of the structure. The article analyzes these processes and proposes to use a polymer with a high molecular content, a superplasticizer, metal nanoparticles and a lightweight nanostructured cement slurry based on modified multi-walled carbon nanotubes to improve the quality of cementation. The efficiency of preparation of lightweight cement slurry under drilling conditions and its application in strengthening intervals expected to be absorbed is shown.

References

1. Suleimanov B.A., Veliyev E.F., Aliyev A.A., Oil and gas well cementing for engineers, John Wiley & Sons, 2023, 272 r.

2. Veliyev E.F., Aliyev A.A., Comparative analysis of the geopolymer and Portland cement application as plugging material under conditions of incomplete displacement of drilling mud from the annulus, SOCAR Proceedings, 2022, no. 1, pp. 108–115, DOI: http://doi.org/10.5510/OGP20220100637

3. Tsement tamponazhnyy oblegchennyy marki PTsT III-Ob 5-50 (Lightweight cement tamping cement grade PCT III-Ob 5-50). URL: https://zbtm.ru/products/tamponazhnyie-materialyi-po-gost-1581-96/pczt-iii-ob-5-50

4. Moradi S.S.T., Nikolaev N.I., Sedimentation stability of oil well cements in directional wells, International Journal of Engineering, 2017, V. 30, no. 7, pp. 1105-1009.

5. Ovchinnikov V.P., Aksenova N.A., Ovchinnikov P.V., Fiziko-khimicheskie protsessy tverdeniya, rabota v skvazhine i korroziya tsementnogo kamnya (Physical and chemical hardening processes, work in the well and corrosion of cement stone), Tyumen: Neftegazovyy universitet Publ., 2007, pp. 62–63.

6. Shamilov V.M., Babayev E.R., Kalbaliyeva E.S., Shamilov F.V., Polymer nanocomposites for enhanced oil recovery, Materials Today: Proceedings, 2017, V. 4, pp. 70–74, DOI: https://doi.org/10.1016/j.matpr.2017.09.169

7. Shamilov V.M., Babaev E.R., Polymer nanocomposites based on carboxymethylcellulose and nanoparticles (Al and Cu) for enhanced oil recovery (In Russ.), Territoriya Neftegaz = Territoriya Neftegaz, 2017, no. 3, pp. 34–38.

8. Shamilov V.M., Babayev E.R., Development of multifunctional composite mixtures based on watersoluble surfactant, polymer and metallic nanopowder as agents of oil displacement (In Russ.), Territoriya Neftegaz = Oil and Gas Territory, 2016, no. 6, pp. 60–63.

9. Shamilov V.M., Babaev E.R., Mammadova P.Sh. et al., Some aspects of the use of carbon nanotubes for enhanced oil recovery (In Russ.), SOCAR Proceedings Special Issue, 2023, no. 1, pp. 115–120, DOI: http://doi.org/10.5510/OGP2023SI100863

10. Pesterev S.V., Fatkhutdinov I.Kh., Datskov A.V., New additives for effective solutions of technological tasks in well cementing (In Russ.), Burenie i neft', 2010, no. 11, pp. 32–34.

11. Gurbanov R.A. et al., Nanotekhnologii v burenii (Nanotechnology in drilling), Baku, 2012, 132 p.

12. Karpov A.I., Results of research in the area of nanotechnologies and nanomaterials. Part 6 (In Russ.), Nanotekhnologii v stroitel'stve: nauchnyy Internet-zhurnal, 2014, V. 6, no. 6, pp. 80-95, DOI: https://doi.org/10.15828/2075-8545-2014-6-6-80-95

13. Korolev E.V., Smirnov V.A., Al'bakasov A.I., Inozemtsev A.S., Some aspects of mixture design for multicomponent composites (In Russ.), Nanotekhnologii v stroitel'stve: nauchnyy Internet-zhurnal, 2011, no. 6, pp. 32–43.

14. Suleimanov B.A., Veliyev E.F., The effect of particle size distribution and the nano-sized additives on the quality of annulus isolation in well cementing, SOCAR Proceedings, 2016, no. 1, pp. 4–10.

15. Abdullayev A.I., Hamashayeva M.J., Shamilov F.V. et al., Application of aluminum nanoparticles in reagents for oil viscosity reduction, SOCAR Proceedings Special Issue, 2024, no. 1, pp. 17–21, DOI: https://doi.org/10.5510/ogp2024si100956

16. Khuzin A.F., Gabidullin M.G., Suleymanov N.M., Togulev P.N., The influence of nanoadditive bases on carbon nanotubes to the strength of cement stone (In Russ.), Izvestiya KGASU, 2011, no. 2(16), pp. 185–189.

17. Abdullaev A.I. et al., Prospects of new technologies in oil and gas well cementing (In Russ.), Territoriya Neftegaz = Oil and Gas Territory, 2016, no. 4, pp. 27–31.

18. Peng Zhang, Jia Su, Jinjun Guo, Shaowei Hu, Influence of carbon nanotube on properties of concrete: A review, Construction and buildings material, 2023, V. 369,

no. 10, DOI: https://doi.org/10.1016/j.conbuildmat.2023.130388

19. C.G.N. Marcondes, M.H.F. Medeiros, J. Marques Filho, P. Helene, Carbon Nanotubes in Portland cement concrete: Influence of dispersion on mechanical properties and water absorption, Revista ALCONPAT, 2015, V. 5 (2), pp. 96–113, DOI: https://doi.org/10.21041/ra.v5i2.80

20. Kai Cui, Jun Chang, Feo L. et al., Developments and applications of carbon nanotube reinforced cement-based composites as functional building materials, Frontiers in Materials, 2022, V. 9, DOI: https://doi.org/10.3389/fmats.2022.861646

21. Certificate of authorship 2014 0126, Oblegchennyy tamponazhnyy rastvor (Light-weight backfill mortar), authors: Shamilov V.M., Ismailov F.S., Guliyev I.B.

22. Patent US9499439B2. Highly dispersed carbon nanotube-reinforced cement-based materials, Inventors: Shah S.P., Konsta M., Metaxa Z.S.

Since 2015, Zarubezhneft JSC has been testing the steam-thermal effect on carbonate formation M saturated with native bitumen at the pilot area of the Boca de Jaruco field (the Republic of Cuba). In 2020-2021 4 horizontal wells were drilled as a part of the second stage of pilot work. Taking into account the presence of a dense system of fractures and small distances between wells (30-100 m), special attention is paid to monitoring and control of wells. During the implementation of the pilot project, various technologies were tested at the fields. This article summarizes practical experience related to the perception of reservoir behavior, monitoring of reservoir parameters (including implementation of reservoir simulation) which enabled to change well operation strategy and to increase energy efficiency of the horizontal wells. Due to the negative results of the first steam cycling stimulations (CSSs) of horizontal wells, a decision was made to change the operation strategy. The new strategy concerned the choice of steam injection volumes in cycles and was based on the principle of gradually increasing injection from smaller to larger volumes (mini-CSS strategy). Since 2021, the achieved results of the pilot project confirmed the feasibility of choosing the mini-CSS strategy. The obtained results of the pilot project confirmed the feasibility of choosing this strategy, which enabled to achieve the planned indicators for the project as a whole by the end of 2024. Field development plan was implemented in 2024 and project will move to the commercial stage of exploitation starting from 2025.

References

1. Afanasev I.S., Yudin E.V., Azimov T.A. et al., Technology for the thermal treatment of the productive formations of the Boca de Jaruco field: Challenges, opportunities, prospects (In Russ.), SPE 176699-RU, 2015, DOI: https://doi.org/10.2118/176699-MS

2. Afanas'ev I.S., Solov'ev A.V., Petrashov O.V. et al., Selection of well exploitation strategy based on field data obtained during pilot steam stimulation of bitumen carbonate reservoir of Boca de Jaruco field (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2023, no. 2, pp. 24–27, DOI: https://doi.org/10.24887/0028-2448-2023-2-24-27

3. Osipov A.V., Esaulov A.O., Ibragimova M.V. et al., The results of pilot steam stimulations of heavy oil saturated fractured carbonate reservoir, Boca de Haruko field

(In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2018, no. 9, pp. 58–61, DOI: https://doi.org/10.24887/0028-2448-2018-9-58-61

4. Melikov R., Korel'skiy E., Myl'nikov D. et al., 4D geomekhanicheskoe modelirovanie razrusheniya pokryshki dlya ucheta teplopoter' i optimizatsii dobychi vysokovyazkoy nefti (4D geomechanical modeling of tire failure to account for heat loss and optimize high-viscosity oil production), Proceedings of Russian Energy Industry Conference, 2023, pp. 1176–1190.

5. Jiang Q., Yuan J., Russel-Houston J. et al., Evaluation of recovery technologies for the Grosmont carbonate reservoirs, Proceedings of PETSOC-2009, V. 067,

DOI: https://doi.org/10.2118/2009-067

6. Annual Presentation Saleski Thermal Pilot AER Approval 11337, LARICINA ENERGY LTD., 2014

7. Minkhanov I.F., Chalin V.V., Tazeev A.R. et al., Integrated modeling of the catalytic aquathermolysis process to evaluate the efficiency in a porous medium by the example of a carbonate extra viscous oil field, Catalysts, 2023, no. 13, DOI: http://doi.org/10.3390/catal13020283

8. Safina R.E., Usmanov S.A., Minkhanov I.F. et al., Efficiency estimation of super-viscous oil recovery by in-situ catalytic upgrading in cyclic steam stimulation: from laboratory screening to numerical simulation (In Russ.), Georesursy, 2023, no. 4, pp. 106–114, DOI: http://doi.org/10.18599/grs.2023.4.7

The article is devoted to improving the effectiveness of the use of displacement characteristics (DC) in the assessment of recoverable oil reserves and the analysis of the technological effectiveness of geological and technological measures (GTM). A universal displacement characteristic (UDC) is proposed, which is a combined model consolidating several known DC with various weighting coefficients. The method of constructing the UDC includes determining constant coefficients for each elementary DC, solving the problem of minimizing deviations of calculated values from actual ones, and selecting optimal weighting coefficients. An algorithm was implemented that enables to automatically build and analyze nine different UDC. The program accepts field data of oil and liquid production, reservoir oil and water densities, as well as time intervals for stable development as input data. During execution, the program determines the optimal set of weights for each type of DC and builds the resulting UDC, minimizing the standard deviation from the actual data. Testing of the proposed method on synthetic and retrospective data showed more accurate results compared to traditional methods, which is confirmed by the high correlation coefficient of the UDC in all tests of the analyzed period. The method of UDC ensures objectivity and accuracy in assessing the effectiveness of GTM and predicting technological indicators for the development of oil fields, which indicates potential applicability in the real practice of oil field management.

References

1. RD 30-9-1069-84. Metodicheskoe rukovodstvo po opredeleniyu nachal'nykh izvlekaemykh zapasov nefti v zalezhakh, nakhodyashchikhsya v pozdney stadii razrabotki (pri vodonapornom rezhime) (Methodological guidelines for determining initial recoverable oil reserves in deposits in the late stage of development (under water drive regime)), put into effect by Order of the USSR Ministry of Oil Industry No. 341 dated 06.06.1984, Moscow: Publ. of Minnefteprom, 1983, 63 p.

2. Antonov M.S., Gumerova G.R., Rafikova Yu.I. et al., Improving the efficiency of monitoring oil fields development on the basis of standard displacement characteristics (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2019, no. 4, pp. 44–48, DOI: https://doi.org/10.24887/0028-2448-2019-4-44-48

3. Amelin I.D., Determination of recoverable oil reserves based on displacement characteristics, taking into account the exploitation of deposits to the limit of profitability (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 1982, no. 5, pp. 7–9.

4. Sazonov B.F., Sovershenstvovanie tekhnologii razrabotki neftyanykh mestorozhdeniy pri vodonapornom rezhime (Perfection of technology of development of oil deposits at a water-pressure mode), Moscow: Nedra Publ., 1973, 238 c.

5. Karachurin N.T., Nechetkie podkhody k resheniyu obratnykh zadach v sistemakh dobychi nefti i gaza (Fuzzy approaches to solving inverse problems in oil and gas production systems): thesis of candidate of physical and mathematical science, Ufa, 1997.

6. Mishchenko K.P. Tikhomirova E.A., Otsenka prognoznoy sposobnosti kharakteristik vytesneniya nefti dlya operativnogo analiza pokazateley razrabotki mestorozhdeniya (In Russ.), Mezhdunarodnyy nauchno-issledovatel'skiy zhurnal, 2022, no. 6(120), pp. 158-163, DOI: https://doi.org/10.23670/IRJ.2022.120.6.023

7. RD 153-39.1-004-96. Metodicheskoe rukovodstvo po otsenke tekhnologicheskoy effektivnosti i primeneniya metodov uvelicheniya nefteotdachi (Guidelines for assessing the technological effectiveness of enhanced oil recovery methods), Moscow: Publ. of VNIIneft, 88 p.

8. Danilina N.I., Dubrovskaya N.S., Kvasha O.P. et al., Chislennye metody (Numerical methods), Moscow: Vysshaya shkola Publ., 1976, 368 p.

9. Maksimov M.I., The method for calculating recoverable oil in the final stage of exploitation of oil reservoirs under oil displacement by water (In Russ.), Geologiya nefti i gaza, 1959, no. 3, pp. 42–47.

10. Pirverdyan A.M., Nikitin P.I., Listengarten L.B., Danelyan M.G., On the forecast of oil and associated water production in the development of bedded heterogeneous reservoirs (In Russ.), Azerbaydzhanskoe neftyanoe khozyaystvo, 1970, no. 11, pp. 19–22.

11. Shchekaturova I.Sh., Sitdikov R.I., Basyrov M.A. et al., From routine processes to automation of field development design (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2024, no. 9, pp. 75–79, DOI: https://doi.org/10.24887/0028-2448-2024-9-75-79

The development of multilayer deposits is complicated by both behind-the-casing circulations between layers along a low-quality cement ring and along a single layer with an aquifer. In production wells, the occurrence of circulations leads to premature water encroachment of the produced product, and in injection wells - to uncontrolled injection of water into unproductive layers. The paper considers the problem of behind-the-casing circulation in oil fields. Methodological approaches to determining the analytical dependencies of the effect of acid treatments on the occurrence of behind-the-casing circulation are presented. For this purpose, an analysis and generalization of the experience of implementing well acid treatment technologies were carried out with the identification of complicating factors influencing the occurrence of behind-the-casing circulation. The supposed reasons for the formation of behind-the-casing circulation in wells with a division into technical, technological and geological factors are formed. The research methods are based on the analysis of information from production data of wells exploiting carbonate deposits, as well as the results of studies using mathematical statistics methods. Based on the results of the analysis of the work performed, the technological parameters of the influence on the occurrence of behind-the-casing circulation in wells were determined, which can be used to optimize the technology of acid treatments and reduce the probability of behind-the-casing circulation.

References

1. Aleshkin S.V., Khan'zhin S.A., Belosludtsev A.V., The problem of outside circulation at the wells of the Volga-Ural region (In Russ.), Burenie i neft', 2023, S2, pp. 73–75.

2. Nabiullin A.Sh., Sinitsyna T.I., Vorontsov S.Yu., Studying the causes of casing leakages in production wells. Developing preventive methods for casing protection (In Russ.), Ekspozitsiya Neft' Gaz, 2023, no. 8, pp. 88-93,

DOI: https://doi.org/10.24412/2076-6785-2023-8-88-93

3. Garipova L.I., Abusalimov E.M., Solov'ev V.A. et al., Analysis of the influence of geological and technological factors on the efficiency of selective treatments of carbonate reservoirs (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2024, no. 9, pp. 122–126, DOI: https://doi.org/10.24887/0028-2448-2024-9-122-126

4. Krasnov D.Yu., Dodova M.I., Mitigation of cross flow risks in cases with reservoir chemical treatments (In Russ.), Neft'. Gaz. Novatsii, 2018, no. 9, pp. 42–47.

5. Gmurman V.E., Teoriya veroyatnostey i matematicheskaya statistika (Theory of probability and mathematical statistics), Moscow: Vysshaya shkola Publ., 2003, 478 p.

As a part of one of the projects on downhole microseismic monitoring of hydraulic fracturing in a horizontal well, an assessment of the quality of monitoring was carried out. The main goal was to assess the information value of the results obtained and increase their reliability. Observations were made by an acquisition typical for monitoring projects in Russia - the nearest well was used, geophones were located in its vertical part, the primary task was to determine the geometry of the resulting hydraulic fracturing cracks. The quality assessment included an analysis of materials of various work stages. The authors highlight the problems of the quality of the initial data and the importance of selecting the correct well for the location of geophones - not only the geometric proximity is important, but also the quality of the cementing. The article marks the possibility of assessing the quality of the installation of geophones immediately before the start of work, in two ways - by the method of borehole seismic interferometry and by recordings of ground sources. The authors show the importance of monitoring the results of data processing - the final versions of event localization differed significantly from the initial ones, which required an analysis of internal data processing materials. Independent processing of the materials partially confirmed the reliability of the obtained result; the crack height is determined most reliably for the observed data quality, and the estimated crack lengths or half-lengths are strongly influenced by the quality of the observed materials.

References

1. Egorov A.A., Domestic flagship product "Rosneft" - "RN-GRID" simulator simulation of hydraulic facing (HF) (In Russ.), Avtomatizatsiya i IT v neftegazovoy oblasti, 2021, no. 2, pp. 12–27.

2. 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.

3. Rutledge J.T., Phillips W.S., Hydraulic stimulation of natural fractures as revealed by induced microearthquakes, carthage cotton valley gas field, east texashydraulic stimulation of natural fractures, Geophysics, 2003, V. 68, pp. 441–452, DOI: http://doi.org/10.1190/1.1567214

4. Toropov K.V., Sergeychev A.V., Murtazin R.R. et al., Experience in microseismic monitoring of multi-stage fracturing by RN-Yuganskneftegas LLC (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2016, no. 11, pp. 23-26.

5. Cipolla C., Maxwell S., Mack M., Engineering guide to the application of microseismic interpretations, SPE-152165-MS, 2012, DOI: http://doi.org/10.2118/152165-MS

6. Konopelko A., Sukovatyy V., Mitin A., Rubtsova A., Microseismic monitoring of multistage hydraulic fracturing in complex reservoirs of the Volgo-Urals Region of Russia, SPE-176710-RU, 2015, DOI: http://doi.org/10.2118/176710-MS

7. Dohmen T., Zhang J.J., Blangy J.P., Stress shadowing effect key to optimizing spacing of multistage fracturing, The American Oil&Gas Reporter, 2015, pp. 72–78.

8. Maxwell S., Microseismic imaging of hydraulic fracturing: Improved engineering of unconventional shale reservoirs, Society of Exploration Geophysicists, 2014,

DOI: http://doi.org/10.1190/1.9781560803164

9. Yaskevich S.V. et al., Downhole microseismic data interpretation for media anisotropy evaluation with limited acquisition geometry in Western Siberia, Interpretation, 2022, V. 10, no. 3, DOI: http://doi.org/10.1190/int-2021-0098.1

10. Maxwell S., Reynolds F., Guidelines for standard deliverables from microseismic monitoring of hydraulic fracturing, Microseismic Subcommittee of the CSEG Chief Geophysicists Forum, 2012, V. 1, pp. 1–7.

11. Yaskevich S.V., Duchkov A.A., Myasnikov A.V., Microseismic monitoring - current state and data unificationproblems (In Russ.), Karotazhnik, 2018, no. 4, pp. 93–100.

12. Hardage B.A., An examination of tube wave noise in vertical seismic profiling data, Geophysics, 1981, V. 46, no. 6, pp. 892–903, DOI: https://doi.org/10.1190/1.1441228

13. Shekhtman G.A., Narskiy N.V., Reasons responsive for vertical seismic profiling data quality (In Russ.), Tekhnologii seysmorazvedki, 2011, no. 2, pp. 59–69.

14. Yaskevich S.A., Duchkov A., Myasnikov A., A case study on receiver-clamping quality assessment from the seismic-interferometry processing of downhole seismic noise recordings, Geophysics, 2019, V. 84, no. 3, pp. B195–B203, DOI: https://doi.org/10.1190/geo2018-0293.1

15. Yaskevich S.V. et al., On the receiver coupling diagnostics in the downhole microseismic monitoring scenarios (In Russ.), Tekhnologii seysmorazvedki, 2017, no. 3,

pp. 75–84.

16. Vaezi Y., Van der Baan M., Interferometric assessment of clamping quality of borehole geophones, Geophysics, 2015, V. 80, no. 6, pp. WC89–WC98,

DOI: http://doi.org/10.1190/geo2015-0193.1

The hydrocarbon offshore field development is associated with a high level of uncertainty and risks due to natural and climatic conditions, technical and technological limitations, high capital and operating costs. In offshore conditions, monitoring and management of hydrocarbon field development also becomes a non-trivial task. One of such tasks is production allocation per reservoirs. This is necessary for monitoring and accounting of recoverable reserves by layers, localization of residual reserves, planning and implementation of the infill drilling and well intervention programs in order to manage and optimize field development. At the same time, production logging is not always technically possible or economically justified in marine conditions. This is due to the limited operational availability of a drilling rig on the platform, complex well trajectories and completions, and the high costs for well interventions in marine conditions. This work summarizes the results of oil geochemical analysis performed to monitor and manage Piltun-Astokhskoye field development. The field study using oil geochemical analysis covers the period from 1999 to 2023. As a part of the work done, the geochemical characteristics of oil of Piltun-Astokhskoye reservoirs were studied and the possibility of separation of oil from different reservoirs with gas chromatography was proved. The solution of this problem is a fundamental condition for quantitative production allocation using oil geochemical analysis.

References

1. Dashkov R.Yu., Gafarov T.N., Singurov A.A. et al., Features of control over field development from offshore platforms (In Russ.), Gazovaya promyshlennost', 2022,

no. 7(835), pp. 28-38.

2. Slentz L.W., Geochemistry of reservoir fluids as a unique approach to optimum reservoir management, SPE-9582-MS, 1981, DOI: https://doi.org/10.2118/9582-MS

3. McCaffrey M.A., Ohms D.H., Werner M. et al., Geochemical allocation of commingled oil production or commingled gas production, SPE-144618-MS, 2011,

DOI: https://doi.org/10.2118/144618-MS

4. Xing Lingbo, Teerman S., Descant F., Time lapse production allocation using oil fingerprinting for production optimization in deepwater Gulf Mexico, SPE-193601-MS, 2019, DOI: https://doi.org/10.2118/193601-MS

5. Russkikh E.V., Murinov K.Yu., Using the chromatographic analysis for comparison of oil compositions and separation of production of wells, exploiting multilayer objects (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2017, no. 10, pp. 28–32, DOI: https://doi.org/10.24887/0028-2448-2017-10-28-32

6. Seytkhaziev E.Sh., Eltay G.G., Pangereeva Sh.S., Sarsenbekov N.D., Quantitative allocation of commingled production of crude oils from wells in Uzen field using geochemical analysis (In Russ.), Neft' i gaz, 2019, no. 4(112), pp. 87–113.

7. Shipaeva M.S., Talipova K.R., Sudakov V.A. et al., Flow Profile Estimating in production wells based on chemical composition of fluids (an example on Volga.Ural Petroleum and gas Province) (In Russ.), Georesursy, 2023, no. 25(4), pp. 121–127, DOI: https://doi.org/10.18599/grs.2023.4.9

8. Peters K., Walters C., Moldowan J., The biomarker guide. Biomarkers and isotopes in the environment and human history, Cambridge: Cambridge University Press, 2005, 471 p., DOI: https://doi.org/10.1017/CBO9780511524868

9. Pavlov D.V., Vasil'ev A.S., Oil fingerprinting technology for well and reservoir management (In Russ.), SPE-187781-MS, 2017, DOI: https://doi.org/10.2118/187781-MS

10. Edman J.D., Burk M.K., Geochemistry in an integrated study of reservoir compartmentalization at Ewing Bank 873, SPE-57470-PA, 1999,

DOI: https://doi.org/10.2118/57470-PA

11. Mullins O.C., Forsythe J.C., Pomerantz A.E., Downhole fluid analysis and gas chromatography; a powerful combination for reservoir evaluation, Petrophysics, 2018,

no. 59(05), pp. 649–671, DOI: https://doi.org/10.30632/PJV59N5-2018a6

12. James B., Patience R., A case study in using compositional grading to improve reservoir characterization, Journal of Canadian Petroleum Technology, 2008, V. 47(07), DOI: https://doi.org/10.2118/08-07-33

The article considers the study of backflow surfactants in compositions with nanoparticles (NP) used to improve the backflow of hydraulic fracturing fluid, in order to accelerate the well's output to the technological mode after hydraulic fracturing, as well as increase the starting flow rate of the well by reducing the interfacial tension at the water–oil boundary and improving the wettability of the rock. It was found that the surfactant of the reverse inflow in concentrations of 2 and 2,5 kg/m3 demonstrates the best results in solubility and interfacial activity at the water–oil boundary. The combined use of surfactants with NP makes it possible to achieve a significant reduction in interfacial tension due to the synergistic effect, while NP solutions themselves are ineffective. Optimal combinations of surfactants and NP ensure a decrease in interfacial tension to 0,005 mN/m. It can be seen from the results that the combined use of surfactants with NP enables to achieve lower values of interfacial tension due to the interaction between NP and surfactants, which indicates a synergistic effect. The nature of the change in the interfacial tension depends on a number of parameters; however there is a general tendency to decrease the interfacial tension in the presence of a selected concentration of NP.

References

1. Asadi M., Woodroof R.A., Comparative study of flowback analysis using polymer concentrations and fracturing-fluid tracer methods: A field study, SPE-101614-PA, 2008, DOI: http://doi.org/10.2118/101614-PA

2. Dong X., Trembly J., Bayless D., Techno-economic analysis of hydraulic fracking flowback and produced water treatment in supercritical water reactor, Energy, 2017,

V. 133, pp. 777–783, DOI: http://doi.org/10.1016/j.energy.2017.05.078

3. Zelenev A.S., Ellena L.B., Microemulsion technology for improved fluid recovery and enhanced core permeability to gas, SPE-122109-MS, 2009,

DOI: http://doi.org/10.2118/122109-MS

4. King G.E., Hydraulic fracturing 101: What every representative, environmentalist, regulator, reporter, investor, university researcher, neighbor and engineer should know about estimating frac risk and improving frac performance in unconventional gas and oil wells, SPE-152596-MS. – 2012. – DOI: http://doi.org/10.2118/152596-MS

5. Sharma M.M., Manchanda R., The role of induced un-propped (IU) fractures in unconventional oil and gas wells, SPE-174946-MS, 2015,

DOI: http://doi.org/10.2118/174946-MS

6. Tianbo Liang et al., Formation damage due to drilling and fracturing fluids and its solution for tight naturally fractured sandstone reservoirs, Geofluids, 2017, V. 45,

DOI: http://doi.org/10.1155/2017/9350967

7. Tianbo Liang et al., Computed-tomography measurements of water block in low-permeability rocks: Scaling and remedying production impairment, SPE-189445-PA, 2018, DOI: http://doi.org/10.2118/189445-PA

8. Musina D.N., Vagapov B.R., Sladkovskaya O.Yu., Ibragimova D.A., Modern technologies for enhanced oil recovery based on surfactants (In Russ.), Vestnik tekhnologicheskogo universiteta, 2016, no. 12, pp. 63-67.

9. Volkov A.V., The use of surfactants to increase oil recovery (In Russ.), Nauchnyy forum. Sibir’, 2019, no. 2, pp. 22-24.

10. Wang J. et al., Study on the mechanism of nanoemulsion removal of water locking damage and compatibility of working fluids in tight sandstone reservoirs, ACS Omega, 2020, no. 6(5), pp. 2910–2919, DOI: http://doi.org/10.1021/acsomega.9b03744

11. Yekeen N. et al., Nanoparticles applications for hydraulic fracturing of unconventional reservoirs: A comprehensive review of recent advances and prospects, Journal of Petroleum Science and Engineering, 2019, V. 178, pp. 41–73, DOI: http://doi.org/10.1016/j.petrol.2019.02.067

12. Chen Fu et al., The gelation of hydroxypropyl guar gum by nano-ZrO2, Polymers for Advanced Technologies, 2018, no. 1(29), pp. 587–593,

DOI: http://doi.org/10.1002/pat.4168

13. Giraldo L.J. et al., The effects of SiO2 nanoparticles on the thermal stability and rheological behavior of hydrolyzed polyacrylamide based polymeric solutions, Journal of Petroleum Science and Engineering, 2017, V. 159, pp. 841–852, DOI: http://doi.org/10.1016/j.petrol.2017.10.009

14. Zhang Z. et al., Boric acid incorporated on the surface of reactive nanosilica providing a nano-crosslinker with potential in guar gum fracturing fluid, Journal of Applied Polymer Science, 2017, no. 27, DOI: http://doi.org/10.1002/app.45037

15. He Y. et al., Study on a nonionic surfactant/nanoparticle composite flooding system for enhanced oil recovery, ACS Omega, 2021, no. 16(6), pp. 11068–11076,

DOI: http://doi.org/10.1021/acsomega.1c01038

16. Zhu H., Xia J.H., Sun Z.G. et al., Application of nanometer-silicon dioxide in tertiary oil recovery, Acta Pet. Sin., 2006, V. 27, pp. 96–99.

The article presents the estimated results of the project implemented at Zarubezhneft JSC related to standardization of surface facilities design. Optimization factors of design solutions are described. The main optimization facilities were identified: well sites for the drilling period (depending on the type of drilling rig, waste collection organization and number of wells), linear objects (highways, pipelines, power lines), uniform requirements for 3D design were developed. The calculated effects of the introduction of typification of design solutions in terms of reducing the cost and timing of designing single wells and well clusters (for the drilling period and for the period of operation), linear objects such as highways, pipelines, and high-voltage lines are presented. 426 technical drawings were developed, including: 18 site options for the drilling period, depending on the type of drilling rig, waste management approach, number of wells; 6 options for field pipelines depending on diameter; 3 options for power transmission lines depending on voltage class; 5 options for roads by category; 5 options for well pad facilities depending on the number of wells per pad (1/8/12). The reduction of the cost of design solutions with typification of design solutions ranged from 1,7 to 12,7 %, depending on the facility's capacity, location, geological, climatic and other factors. The average estimated reduction in the cost of design solutions is 6,9 %. Typifications of design solutions are implemented into projects of Subsidiaries of the Company and included in design documentation.

References

1. Andreeva N.N., Bugriy O.E., Dubovitskaya E.A. et al., Normativnoe obespechenie proektirovaniya obustroystva mestorozhdeniy uglevodorodov (Regulatory support of the design of oil and gas fields facilities), Moscow: Publ. of Gubkin University, 2015, 303 p.

2. GOST R 58367-2019. Engineering process for onshore oil fields. Technological design.

3. Town-planning code of the Russian Federation of December 29, 2004 No. 190-FZ.

4. Russian Federal Law No. 123-FZ of 22 July 2008, "Technical regulations on fire safety requirements".

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

6. Russian Federal Law No.116-FZ of 21.07.1997, “On industrial safety of hazardous production facilities”.

7. Federal norms and rules in the field of industrial safety “Rules for the safe operation of technological pipelines” approved by Rostekhnadzor Order No. 444 dated December 21, 2021.

8. Federal norms and rules in the field of industrial safety "Safety rules in the oil and gas industry" approved by order of the Federal Environmental, Industrial and Nuclear Supervision Service No. 534 dated December 15, 2020.

When pumping water-gas mixtures into a formation to enhance oil recovery, various equipment configurations are used with pumps, compressors, mixers, dispersers, etc. Previous studies showed the feasibility of using associated gas to enhance oil recovery using pump-ejector water-gas treatment technologies. The characteristics of liquid-gas ejectors, being key elements in these technologies, have not yet been fully studied. The characteristics of ejectors are affected by the processes of suppression of coalescence of gas bubbles in liquid, which depend on the absolute pressure in the flow, the concentration and composition of dissolved electrolyte salts, the foaming properties of the liquid, etc. In order to experimentally evaluate the parameters of liquid-gas ejectors under changing operating conditions, bench studies were conducted for various pressure values in front of the nozzle and in the receiving chamber. When processing the experimental data, the parameter of the dimensionless relative average integral feed was used, taking into account the decrease in the volumetric gas flow rate as the pressure in the flow part of the ejector increases. These studies showed that in order to increase the efficiency of water-gas treatment in the pump-ejector systems, it is advisable to use liquid-gas ejectors with geometric ratios of the mixing chamber diameter to the diameter of the diaphragm nozzle in the range from 1,73 to 2,73. The values of the maximum efficiency of the ejectors range from 37,4 to 40,7 %, the average integral injection coefficients range from 1,4 to 3,9, the relative dimensionless pressure drops range from 0,09 to 0,21.

References

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

pp. 104–105.

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

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

4. Agrawal G., Verma V., Gupta S. et al., Novel approach for evaluation of simultaneous water and gas injection pilot project in a Western offshore field, India, SPE-178122, 2015, DOI: http://doi.org/10.2118/178122-MS

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

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

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

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

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

10. Drozdov A.N., Generalization of characteristics of liquid-gas ejectors (In Russ.), Ekspress informatsiya. Tekhnika i tekhnologiya dobychi nefti i obustroystvo neftyanykh mestorozhdeniy, 1991, no 9, pp. 18–22.

The article presents an innovative approach to oil and gas field infrastructure planning by integrating neural networks with geospatial analysis. The core solution relies on applying the pre-trained Segment Anything Model (SAM), which was specifically fine-tuned for high-precision segmentation of satellite imagery. The paper describes a methodology for fine-tuning of SAM using a specialized dataset of satellite images obtained via the Google Earth Engine platform and annotated with vector data from OpenStreetMap. The primary objective of this fine-tuning is to enhance the model’s capability to accurately identify infrastructure elements and natural landscape features, such as forests, water bodies, roads, and buildings. The key stage of the approach involves generating integrated desirability maps, which reflect the cumulative impact of various limiting factors, including cultural heritage sites, protected natural areas, sanitary protection zones, etc. A system of weighting coefficients was developed to quantify the significance of each factor in constructing these desirability maps. This approach enables automated identification and evaluation of limiting factors, significantly reducing time requirements and increasing decision-making accuracy. The methodology was successfully tested on the Mishkinskoe oil field site, demonstrating the automated placement of well pads and routing of linear communications, taking into account pipeline capacities and cost indicators of designated areas. The results underscore the high effectiveness of the proposed approach in optimizing the infrastructure planning of oil and gas fields.

References

1. Kirillov A., Mintun E., Ravi N. et al., Segment anything, Proceedings of 2023 IEEE/CVF International Conference on Computer Vision (ICCV), Paris, France,

01-06 October 2023, DOI: https://doi.org/10.1109/ICCV51070.2023.00371

2. Dosovitskiy A., Beyer L., Kolesnikov A. et al., An image is worth 16x16 words: Transformers for image recognition at scale, arXiv preprint, 2021,

DOI: http://doi.org/10.48550/arXiv.2010.11929

3. Google Earth Engine. Earth Engine API Documentation. Google Developers, URL: https://developers.google.com/earth-engine/apidocs

4. OpenStreetMap. Open Database of Geospatial Data, URL: https://www.openstreetmap.org/

5. Boeing G., OSMnx: New Methods for acquiring, constructing, analyzing, and visualizing complex street networks, Computers, Environment and Urban Systems, 2017, V. 65, pp. 126-139, DOI: https://doi.org/10.1016/j.compenvurbsys.2017.05.004

6. Sapozhnikov Ya.E., Mironova A.V., Optimization of field development and surface field construction system and the use of artificial intelligence methods (In Russ.), Neft’.Gaz.Novatsii, 2024, no. 4, pp. 66–70.

The article deals with assessment of cracked oil pipelines and addresses the problem of defect initiation. When testing main pipelines for strength or when the pressure is increased during operation (in order to maintain pumping volumes when decommissioning intermediate stations), cracks sitting in the pipe body before the pressure increase may steadily propagate (initiate). When assessing a defect hazard in order to determine the safety factor of defective pipeline against fracturing pressure, it is necessary to take into account the possibility of crack initiation. The defect initiation also reduces the fatigue life in line with the stage of crack propagation. During the pipeline strength tests, it is necessary to take into account the possibility of crack initiation when determining the interval for re-testing in order to assess the size range of cracks that could initiate during tests and remain in the pipeline thereafter. The paper presents the results of assessing the steady propagation of longitudinal part-through cracks in pipes of main oil pipeline under increasing pressure and under cyclic loads with a constant pressure range using a subcritical fracture diagram. It also presents the results of assessing the influence of crack initiation on the safety factor of a cracked pipeline against fracturing pressure and cyclic durability.

References

1. Haines H., Kiefner J., Rosenfeld M., Study questions specified hydrotest hold time's value, Oil and Gas Journal, 2012, V. 110, pp. 110-116.

2. Kiefner J.F., Maxey W.A., Hydrostatic testing - 1: Pressure ratios key to effectiveness; in-line inspection complements, Oil and Gas Journal, 2000, V. 98.

3. Rosenfeld M., Hydrostatic pressure spike testing of pipelines: Why and when, The Journal of Pipeline Engineering, 2014, V. 10, pp. 229-240.

4. Kiefner J., Maxey W., The benefits and limitations of hydrostatic testing, Proceedings of API Pipeline Conference, San Antonio, 2001, V. 4.

5. Parton V.Z., Morozov E.M., Mekhanika uprugoplasticheskogo razrusheniya: Osnovy mekhaniki razrusheniya (The mechanics of elastoplastic fracture: Fundamentals of fracture mechanics), Moscow: LKI Publ., 2008, 352 p.

6. Sapunov V.T., Prochnost' povrezhdennykh truboprovodov. Tech' i razrushenie truboprovodov s treshchinami (Strength of damaged pipelines. Leakage and destruction of pipelines with cracks), Moscow: KomKniga Publ., 2005, 192 p.

The technology of using reinforced thermoplastic (RTP) and thermoplastic composite pipes (TCP) as a part of field pipelines is actively developing worldwide and in Russia. The intensive development of the technology application is facilitated by the development and implementation of national standards for production, design and inspection of field pipelines made of RTP/TCP. With all the variety of design, two main groups can be distinguished: polymer pipes with bonded layers (TCP) and polymer pipes with unbonded layers (RTP). Each of these technologies has its advantages, disadvantages and application restrictions. When conducting a feasibility study for construction of pipelines made of RTP/TCP, it is necessary to consider the cost of a pipe based on length, the cost of construction and installation work, and the cost of owning the pipeline during its standard operation period. The supply of RTP/TCP with ready-made measuring lengths from 140 to 1600 m, as well as an operation period up to 25 years, is their clear calculable advantage. Incalculable advantages include their resistance to asphaltene-resin-paraffin deposits and the possibility of re-laying. The main disadvantage of RTP/TCP can be attributed to the current lack of technology for checking the condition of all pipe layers of the existing pipeline. The most promising areas for the development of RTP/TCP technology are production of pipes with an integrated electric heating system for transporting gas-liquid mixtures in conditions of subzero temperatures or for highly viscous oil; production of pipes with a heat-insulating layer, with non-metallic reinforcement using RTP technology.

References

1. Rynok neftepromyslovykh polimernykh armirovannykh trub v 2021-2027. Real'nost' i perspektivy (Oilfield polymer reinforced pipes market in 2021-2027. Reality and prospects), URL: https://teo.ru/analiz/publ_34.htm

2. Zelenin A.A., Experience of using pipelines made of innovative and alternative materials in LUKOIL PJSC (In Russ.), Inzhenernaya praktika, 2020, no. 5–6,

URL: https://glavteh.ru/opyt-primeneniya-truboprovodov-iz-inn/

3. Khalbashkeev A., Polymer reinforced pipes – the material of the future? (In Russ.), Neftegazovaya promyshlennost', 2024, no. 1, URL: https://nprom.online/technology/polimernye-armirovannye-truby-material-budushhego/

4. Potapov B.V., Marchenko S.V., Potapov A.B., An approach to advanced research in the field of technical diagnostics of oil and gas field pipelines made of reinforced polymer pipes (In Russ.), Truboprovodnyy transport: teoriya i praktika, 2023, no. 1, pp. 19–26.