The given paper provides data on the fingerprints of Azerbaijani oils using biomarkers (GC/MS) and microelement composition (ICP/MS), as well as the main geochemical parameters of oil, such as CPI, Ki, QI, ITC, Ts/Tm, Pr/Ph, etc., and data on correlation dependencies of geochemical parameters on the horizon at particular oilfield. Characterization of oil accumulations belonging to the mid-Pliocene in the Caspian Sea in terms of hydrocarbons - biomarkers and geochemical parameters makes it possible to predict the composition and the predominant type of oil in the field with similar geological structure.

Keywords: oil biomarkers; chromatographymass spectrometry; mass spectrometry with inductively coupled plasma; oil fingerprint.

References

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The article describes the results of a study of changes in the composition and hydrogeochemical parameters of individual areas and fields of the Bukhara-Khiva region based on well materials. Vertical zonality of hydrogeochemical parameters associated with deep fluid flow and heat and mass transfer is noted. The manifestation of tectonodynamic conditions in the Mesozoic-Cenozoic history of the region, which served as a prerequisite for the formation of weakened zones (channels of deep heat and mass transfer) in the field of tensile stresses for the vertical migration of fluids and juvenile gases, is noted. A hydrogeological criterion for identifying zones of deep heat and mass transfer and vertical fluid migration is proposed.

Keywords: wells; oil and gas; formation waters; fluids; hydrogeochemical indicators of formation waters; heat and mass transfer.

References

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The Paleogene-Miocene oil shales studied in the paper were taken from the outcrops and ejecta of mud volcanoes in Shamakhi-Gobustan and Absheron regions. The geological age, mineralogy, and chemical composition of the samples were studied by analytical investigations. Minerals found oil shales were described in detail in the relevant categories. Some appropriate classifications were made in connection with the chemical composition of samples. The indices such as CIA, CIW, PIA, "RR = SiO₂/Al₂O₃" - chemical weathering index, the diagrams like "(Al₂O - K₂O) – CaO – Na₂O", "A-CN-K", and also reflecting mobility characteristics of elements, and estimates on large-ion lithophile elements were used to study the paleoweathering characteristics.

Keywords: oil shale; geochemistry; mineral; paleoweathering.

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The optimal ratios of the components of the WC–Co‒CrB₂ system have been established, at which a finely dispersed structure is formed with a simultaneous improvement in physical and mechanical properties. It is shown that the introduction of CrB₂ (in concentration C_CrB2 = 4% wt) leads to a twofold increase in fracture toughness (from K_Ic = 4.4 MPa ∙ m^1/2 to K_Ic = 9.8 MPa ∙ m^1/2) with a slight decrease hardness (from H = 15.1 to 13.9 GPa), as well as to an increase in the ultimate bending (from σ = 2000 to 2500 MPa) and compression (from σ = 5300 to 6000 MPa) strength of sintered composite specimens. Creation of the WC–Co‒CrB₂ composite materials with improved mechanical and operational properties is essential for optimizing the designs of drilling tools for various technological purposes, increasing their reliability, energy saving, and improving operational properties.

Keywords: composite; composition; concentration; structure; hardness; fracture toughness.

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The article discusses the possibility of diagnosing the multiphase flow regime in the multilayered reservoir by using DTS (distributed temperature sensing) data. The analysis of the theoretical and actual curves of temperature build up and drawdown, corresponding to the main modes of multiphase flow of formation fluids are given in this article. The possibility of diagnosis of the multiphase flow regime is found based on analysis and interpretation of the characteristics of temperature build-up and drawdown in different intervals of the reservoir at the start of the well or shut in, or by changing opening degree of the choke. The possibility of diagnosing water breakthrough (WBT) intervals, based on the analysis of the changes in temperature curves according to the DTS is shown. For a more detailed analysis and interpretation of temperature change curves in the wells more frequent DTS measurements are required. It is necessary to conduct a comparative analysis of the dynamics of the temperature and pressure redistribution in the productive zone of the well, with the results of geophysical logging, production logging, taking samples of reservoir fluids from different zones of productive layers in the multilayered reservoir, moisture metering, hydrometry and others.

Keywords: well; monitoring; multilayer reservoir; temperature profile; distributed temperature sensor; multiphase flow regime.

References

1. Mirzajanzadeh, A. Kh., Aliev, N. A., Yusifzade, Kh. B., et al. (1997). Fragments on development of offshore oil and gas fields. Baku: Elm.
2. Veliyev, E. F. (2021). Polymer dispersed system for in-situ fluid diversion. Prospecting and Development of Oil and Gas Fields, 1(78), 61-72.
3. Suleimanov, B. A., Veliyev, E. F., Naghiyeva, N. V. (2021). Colloidal dispersion gels for in-depth permeability modification. Modern Physics Letters B, 35(01), 2150038.
4. Suleimanov, B. A., Guseynova, N. I., Veliyev, E. F. (2017, October). Control of displacement front uniformity by fractal dimensions. SPE-187784-MS. In: SPE Russian Petroleum Technology Conference. Society of Petroleum Engineers.
5. Suleimanov, B. A., Veliyev, E. F., Naghiyeva, N. V. (2020). Preformed particle gels for enhanced oil recovery. International Journal of Modern Physics B, 34(28), 2050260.
6. Veliyev, E. F., Aliyev, A. A. (2021, October). Propagation of nano sized CDG deep into porous media. SPE-207024-MS. In: SPE Annual Caspian Technical Conference. Society of Petroleum Engineers.
7. Veliyev, E. F. (2021). A combined method of enhanced oil recovery based on ASP technology. Prospecting and Development of Oil and Gas Fields, (4 (81)), 41-48.
8. Veliyev, E. F., Aliyev, A. A., Mammadbayli, T. E. (2021). Machine learning application to predict the efficiency of water coning prevention. SOCAR Proceedings, 1, 104-113.
9. Suleimanov, B. A., Veliyev, E. F., Aliyev, A. A. (2021). Impact of nanoparticle structure on the effectiveness of pickering emulsions for eor applications. ANAS Transactions, (1), 82-92.
10. Veliyev, E. F. (2021). Prediction methods for coning process. Azerbaijan Oil Industry, (3), 18-25.
11. Balakirov, Yu. A. (1970). Thermodynamic studies of oil and gas filtering in deposit. Moscow: Nedra.
12. Rider, M. H., Kennedy, M. (2011). The geological interpretation of well logs. Sutherland: Rider-French.
13. Brown, G. (2009). Downhole temperatures from optical fiber. Schlumberger Oilfield Review, 20(4), 34-39.
14. (2009). The essentials of fiber-optic distributed temperature analysis. Schlumberger Educational Services.
15. Brown, G., Algeroy, J., Lovell, J., et al. (2010). Permanent monitoring: taking it to the reservoir. Schlumberger Oilfield Review, 22(1), 34-41.
16. Brown, G., Storer, D., McAllister, K., et al. (2003, October). Monitoring horizontal producers and injectors during cleanup and production using fiber-optic-distributed temperature measurements. SPE-84379-MS. In: SPE Annual Technical Conference and Exhibition. Society of Petroleum Engineers.
17. Brown, G. A., Kennedy, B., Meling, T. (2000, October). Using fibre-optic distributed temperature measurements to provide real-time reservoir surveillance data on Wytch Farm field horizontal extended-reach wells. SPE-62952-MS. In: SPE Annual Technical Conference and Exhibition. Society of Petroleum Engineers.
18. Fryer, V., Shu Xing, D., Otsubo, Y., et al. (2005, April). Monitoring of real-time temperature profiles across multizone reservoirs during production and shut-in periods using permanent fiber-optic distributed temperature systems. SPE-92962-MS. In: SPE Asia Pacific Oil and Gas Conference and Exhibition. Society of Petroleum Engineers.
19. Denney, D. (2012). DTS Technology: Improving Acid Placement. Journal of Petroleum Technology, 64(6), 22-25.
20. Gorgi, B., Medina, E., Gleaves, J., et al. (2014, November). Wellbore monitoring in carbonate reservoirs: value of DTS in acid stimulation through coiled tubing. SPE-171933-MS. In: Abu Dhabi International Petroleum Exhibition and Conference. Society of Petroleum Engineers.
21. Villesca, J., Glasbergen, G., Attaway, D. J. (2011, June). Measuring fluid placement of sand consolidation treatments using DTS. SPE-144432-MS. In: SPE European Formation Damage Conference. Society of Petroleum Engineers.
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23. Tabatabaei, M., Tan, X., Hill, A. D., Zhu, D. (2011, October-November). Well performance diagnosis with temperature profile measurements. SPE-147448-MS. In: SPE Annual Technical Conference and Exhibition. Society of Petroleum Engineers
24. Malikov, H. Kh., Suleymanov, A. A., Mammadli, N. F. (2017, November). Diagnosing multiphase flow regime in multilayered reservoir by distributed temperature sensor data. SPE-189034-MS. In: SPE Annual Caspian Conference and Exhibition. Society of Petroleum Engineers.
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The process of stationary movement of a gas-liquid mixture in the lifting pipe of a gas-lift well is considered. To describe this two-phase flow, a mathematical model is proposed that includes the equation of flow motion and the continuity equation for each phase. The presented model is transformed to a single nonlinear ordinary differential equation with respect to pressure. Within the framework of the obtained model, the task is set to determine the hydraulic resistance coefficient of a two-phase flow according to an additionally specified condition with respect to pressure. An additional condition, presented in the form of a nonlinear algebraic equation, is transformed into an ordinary differential equation with respect to an unknown coefficient of hydraulic resistance by applying the method of differentiation by parameter. The solution of the resulting Cauchy problem is determined by the finite difference method. Based on the proposed computational algorithm, numerical experiments were carried out for model data.

Keywords: gas lift; two-phase flow; hydraulic resistance coefficient; parameter differentiation method; finite difference method.

References

1. Veliyev, E. F. (2021). Polymer dispersed system for in-situ fluid diversion. Prospecting and Development of Oil and Gas Fields, 1(78), 61-72.
2. Suleimanov, B. A., Veliyev, E. F., Naghiyeva, N. V. (2021). Colloidal dispersion gels for in-depth permeability modification. Modern Physics Letters B, 35(01), 2150038.
3. Suleimanov, B. A., Guseynova, N. I., Veliyev, E. F. (2017, October). Control of displacement front uniformity by fractal dimensions. SPE-187784-MS. In: SPE Russian Petroleum Technology Conference. Society of Petroleum Engineers.
4. Suleimanov, B. A., Veliyev, E. F., Naghiyeva, N. V. (2020). Preformed particle gels for enhanced oil recovery. International Journal of Modern Physics B, 34(28), 2050260.
5. Veliyev, E. F. (2021). Prediction methods for coning process. Azerbaijan Oil Industry, 3, 18-25.
6. Suleimanov, B. A., Veliyev, E. F., Aliyev, A. A. (2021). Impact of nanoparticle structure on the effectiveness of pickering emulsions for eor applications. ANAS Transactions, (1), 82-92.
7. Veliyev, E. F. (2021). Application of amphiphilic block-polymer system for emulsion flooding. SOCAR Proceedings, (3), 78-86.
8. Veliyev, E. F., Aliyev, A. A., Mammadbayli, T. E. (2021). Machine learning application to predict the efficiency of water coning prevention. SOCAR Proceedings, 1, 104-113.
9. Suleimanov, B. А. (1997). Slip effect during filtration of gassed liquid. Colloid Journal, 59(6), 749-753.
10. Suleimanov, B. А. (2011). Sand plug washing with gassy fluids. SOCAR Proceedings, 1, 30-36.
11. Suleimanov, B. А., Azizov, Kh. F. (1995). Specific features of the flow of a gassed liquid in a porous body. Colloid Journal, 57(6), 818-823.
12. Mirzadzhanzadeh, A. Kh., Ametov, I. M., Khasaev, A. M., Gusev, V. I. (1986). Technology and technics of oil extraction. Moscow: Nedra.
13. Silash, A. P. (1980). Extraction and transport of oil and gas. Moscow: Nedra.
14. Shoham, O. (2006). Mechanistic modeling of gas-liquid two-phase flow in pipes. USA: Society of Petroleum Engineers.
15. Mokhov, M. A., Sakharov, V. A. (2008). Flowing and gas-lift well operation. Moscow: Nedra.
16. Leonov, E. G., Isaev, V. I. (1987). Drilling hydroaeromechanics. Moscow: Nedra.
17. Aliev, F. A., Ismailov, N. A. (2013). Inverse problem to determine the hydraulic resistance coefficient in the gas lift process. Applied and Computational Mathematics, 3, 306–313.
18. Ramazanova, E. E., Gurbanov, R. S., Nasibov, N. B. (2010). A new approach to the study of gas-lift wells in the regime of steady withdrawals. Oil Industry, 6, 83-85.
19. Abdullayev, V. J. (2021). New approach for two-phase flow calcuation of artifical lift. SOCAR Proceedings, 1, 49–55.
20. Gamzayev, Kh. M., Yusifov, S. I. (1998). Simulation of gas-lift. Azerbaijan Oil Industry, 4, 32-33.
21. Kadivar, A., Nemati, E. (2017). A computation fluid dynamic model for gas lift process simulation in a vertical oil well. Journal of Theoretical and Applied Mechanics, 1, 49-68.
22. Ortega, J., Reinboldt, V. (1975). Iterative methods for solving nonlinear systems of equations with many variables. Moscow: Mir.
23. Samarsky, A. A., Gilin, A. V. (1989). Numerical methods. Moscow: Nauka.

The paper presents a new well construction in order to eliminate the unpleasant complications associated with the appearance of sand flow in the Electric Submersible Pumps (ESP), which is widely used in oil wells in the final stage of reservoir development. The new design is based on the combination of ESP with a Mixer based on the principle of ejector and centrifugal. The combined well construction limits the ESP to be in contact with the sand flow and prevents potential erosion and other complications. The design was modeled and tested in the laboratory condition.

Keywords: field; layer; pump; well construction; sand production; sand separator.

References

1. Abdus, S., Mohammad, N. (2013). Flow analyses inside jet pumps used for oil wells. International Journal of Fluid Machinery and Systems, 6(1), 1-10.
2. Abasova, S. M., Habibov, I. A. (2012). Elektrik merkezdenqachma nasoslarinda istismar zamani yaranan imtinalarin tehlili. «Xezerneftqazyataq – 2012» elmi–tecrubi konfrans, Baki.
3. Diaz de Bonilla, S. G., Chen, H.-Y. (2019, July). Analytical and numerical studies of sand erosion in electrical submersible pump (ESP) systems. URTEC-2019-599-MS. In: SPE/AAPG/SEG Unconventional Resources Technology Conference. Society of Petroleum Engineers.
4. Lyamaev, B. F. (1988). Hydrojet pumps and units. Leningrad: Mashinostroyeniye.
5. Azizov, A. H., Qarayev, M. A., Heydarov, H. A., Agammadov, S. A. (2010). Hecmi hidravlik mashinlar. Bakı: ADNA.
6. Haiwen, Z., Jianjun, Z., Zulin, Z., et al. (2019, May). Wear and its effect on electrical submersible pump ESP performance degradation by sandy flow: experiments and modeling. OTC-29480-MS. In: Offshore Technology Conference. Society of Petroleum Engineers.
7. Haiwen, Z., Jianjun, Z., Zulin, Z., et al (2019, March). Experimental study of sand erosion in multistage electrical submersible pump ESP: performance degradation, wear and vibration. IPTC-19264-MS. In: International Petroleum Technology Conference. Society of Petroleum Engineers.
8. Noui-Mehdi, M. N., Bukhamseen, A. Y. (2019). Advanced signal analysis of an electrical-submersible-pump failure owing to scaling. SPE Production & Operation, 34(02), 394–399.
9. Topolnikov, A. S., Urazakov, K. R., Vahitova, R. I., Saracheva, D. A (2013). The method of calculation of parameters of jet pump attached to joint operation with submersible electric pump. Oil and Gas Business, 4, 201-211.
10. Mishchenko, I. T., Gumerskiy, Kh. Kh., Mar'enko, V. P. (1996). Jet pumps for oil production. Moscow: Neft i Gaz Publ.
11. Mallela, R., Chatterjee, D. (2011). Numerical investigations of the effect of geometry on the performance of jet pump. Journal of Mechanical Engineering Science, 225, 1-12.
12. Ahmed, F. F., Hemidov, N. N., Bayramov, E. E. (2019). Lay sularinin tecridi proseslərinde sement dashinin elastikberk xasselerinin qiymetlendirilmesi. «Neftin Qazin Geotexnoloji Problemleri ve Kimya» Elmi-Tedqiqat Institutunun Elmi Eserleri. Baki: Azerkitab-212 MMC.

The features of the impact of high-amplitude short pressure pulses on perforation channels in the bottomhole zone of the well are analyzed. It is shown that in the channels formed in the rock with the use of cumulative perforation and having a conical shape, there is an increase in pressure pulses when a certain condition is fulfilled, which limits the duration of this pulse. It has been established that in the negative phase of the pressure pulse, destruction of the cured rock layers adjacent to the walls of the perforation channel can occur, which improves the filtration-capacitive properties of the bottomhole zone of the well. It is shown that when using explosive charges of low mass, pressure pulses are formed with parameters similar to those of pulses generated by electric discharges in the wellbore. To apply the technology of explosive action with low-mass charges on the bottomhole zone, the standard equipment used for cumulative perforation of wells can be used. A method for screening pressure pulses is proposed, which increases the effectiveness of their impact on the bottomhole zone of the well and simultaneously reduces the excessive load on the casing pipes above the productive formation.

Keywords: bottomhole zone of a well; perforation channels; electric discharge impact; low-mass charges; reflecting screen.

References

1. Gulyi, G. A. (1990). Scientific foundation of discharge-pulse technologies. Kiev: Naukova dumka.
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8. Svalov, A. M. (2017). Novyj podhod k primeneniyu tekhnologij elektrorazryadnogo vozdejstviya na prizabojnye zony skvazhin. Tekhnologii Nefti i Gaza, 5, 24-29.

A new composition for controlling build up of paraffin has been developed. Preference was given to naphthenic acids, polypropylene glycol, caustic potassium and copper nanoparticles with size of 50 nm, bulk weight 5 g/cm³, specific surface area 12 m²/g. The optimal concentration of the hydrophobic reagent and its application technology under field conditions are recommended. The developed reagent is used in oil production, namely for ARPD control, in individual wells in Azerbaijan.

Keywords: well; wax deposition; inhibitor; nanoparticle; electrokinetic potential.

References

1. Veliyev, E. F., Aliyev, A. A. (2021, October). Propagation of nano sized CDG deep into porous media. SPE-207024-MS. In: SPE Annual Caspian Technical Conference. Society of Petroleum Engineers.
2. Suleimanov, B. A., Latifov, Y. A., Veliyev, E. F., Frampton, H. (2017, November). Low salinity and low hardness alkali water as displacement agent for secondary and tertiary flooding in sandstones. SPE-188998-MS. In: SPE Annual Caspian Technical Conference and Exhibition. Society of Petroleum Engineers.
3. Panakhov, G. M., Suleimanov, B. A. (1995). Specific features of the flow of suspensions and oii disperse systems. Colloid Journal, 57(3), 386-390.
4. Suleimanov, B. А., Askerov, М. S., Valiyev, G. А. (2000). Potential of re-development of horizon PK-5 (north) of Surakhany field. Azerbaijan Oil Industry, (5), 16-21.
5. Veliyev, E. F. (2021). Polymer dispersed system for in-situ fluid diversion. Prospecting and Development of Oil and Gas Fields, 1(78), 61-72.
6. Suleimanov, B. A., Veliyev, E. F., Naghiyeva, N. V. (2021). Colloidal dispersion gels for in-depth permeability
   modification. Modern Physics Letters B, 35(01), 2150038.
7. Suleimanov, B. A., Guseynova, N. I., Veliyev, E. F. (2017, October). Control of displacement front uniformity by fractal dimensions. SPE-187784-MS. In: SPE Russian Petroleum Technology Conference. Society of Petroleum Engineers.
8. Suleimanov, B. A., Veliyev, E. F., Naghiyeva, N. V. (2020). Preformed particle gels for enhanced oil recovery. International Journal of Modern Physics B, 34(28), 2050260.
9. Veliyev, E. F. (2021). A combined method of enhanced oil recovery based on ASP technology. Prospecting and Development of Oil and Gas Fields, (4 (81)), 41-48.
10. Veliyev, E. F., Aliyev, A. A., Mammadbayli, T. E. (2021). Machine learning application to predict the efficiency of water coning prevention. SOCAR Proceedings, 1, 104-113.
11. Suleimanov, B. A., Veliyev, E. F., Aliyev, A. A. (2021). Impact of nanoparticle structure on the effectiveness of pickering emulsions for EOR applications. ANAS Transactions, (1), 82-92.
12. Ismailov, R. G., Veliev, E. F. (2021). Emulsifying composition for increase of oil recovery efficiency of high viscous oils. Azerbaijan Oil Industry, (5), 22-28.
13. Sorokin, A., Havkin, A. (2007). Physical and chemical mechanism of production asphalted, resinous and of paraffin formations in the wells. Drilling and Oil, 10, 30-31.
14. Ivanova, L.V., Burov, E. A., Koshelev, V. N. (2011). Asphaltene-resin-paraffin deposits in the processes of oil production, transportation and storage. Oil and Gas Business, 1.
15. Glushchenko, V. N., Shipiguzov, L. M., Yurpalov, I. A. (2007). Estimation of an efficiency of asphaltene-tarparaffin deposits inhibitors. Oil Industry, 5, 84-87.
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17. Lebedev, N. A., Yudina, T. V., Safarov, R. R., et al. (2002). The development of the complex reagent based on phenolformaldehyde resin. Oilfield Engineering, 4, 34-38.

The article deals with the regulation of the rheophysical properties of multicomponent mixtures on the basis of the purposeful application of a new direction in science-rheotechnology. The data of rotoviscometry once again confirmed that the sequence of mixing the constituent components of the oil-water-sand mixture directly affects the rheology of the newly formed systems. The method of changing the order of entering the constituent components shows the prospects for increasing the efficiency of the processes of extraction, collection and transport of oils and their mixtures based on the creation of new rheological methods based on the regulation of the rheophysical properties of the heterophase systems under consideration.

Keywords: constituent components of the mixture; rheology; structural viscosity; anomalous index; graph-analytical method.

References

1. Gumbatov, G. G., Bagirov, O. T., Sariyev, S. K., et.al. (2002). Regulation of technogenic processes to increase the production capacity of wells. Baku: Maarif.
2. Safieva, R. Z., Sunyaev, R. Z. (2007). Physico-chemical properties of oil dispersed systems oil and gas technologies. Moscow-Izhevsk: Institute of Computer Research. Research Center «Regular and Chaotic Dynamics».
3. Sattarov, R. M. (1982). Scientific basis for diagnosing and determining the properties of rheologically complex systems used in oil and gas production. Doctoral Dissertation Thesis. Baku.
4. Mirzajanzade, A. Kh., Khasanov, M. M., Bakhtizin, R. N. (1999). Sketches on the modeling of complex systems in oil production. Ufa: Gilem.
5. Suleimanov, B. A., Panahov, G. M., Abbasov, E. M. (1996). On the influence of the formation of an emulsion in reservoir conditions on the operation of oil producing wells. Azerbaijan Oil Industry, 5, 26-29.
6. Suleymanov, B. A. (1997). Theoretical and practical foundations of the use of heterogeneous systems to improve the efficiency of technological processes in oil production. Doctoral Dissertation Thesis. Baku: ASUOI.
7. Fortier, A. (1971). Mechanics of suspensions. Moscow: Mir.
8. Ismayilov, F. S., Ismayilov, G. G., Safarov, N. M., et al. (2014).Transportation method of high viscosity oils through the pipeline. Patent of the Republic of Azerbaijan İ 2004 0032.
9. Ismayilov, G. G., Safarov, N. M. (2011). To the question of studying the effect of free-flowing fillers on the rheological properties of oil-water emulsions. Proceedings of High Technical Educational Institutions of Azerbaijan, 3(73), 26-32.
10. Ismayilov, G. G., Safarov, N. M. (2013, November). On the prospects for the use of rheological technologies in processes of oil and gas production on the basis of «Mirzadjanzadeh emulsions». In: The international scientific conference dedicated to the 85th anniversary of the academician A.Kh. Mirzajanzadeh. Baku: ASUOI.
11. Ismayilov, G. G., Safarov, N. M. (2010). Rheotechnology of viscous-free systems (monography). Baku: MSM.
12. Ismayilov, G. G., Safarov, N. M. (2011). Rheotechnology of heterogeneous systems and its reflection, in effects manifested during oil and gas production. News of ANAS (Series of Earth Sciences), 4, 49-55.
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14. Ismayilov, F. S., Ismayilov, G. G., Safarov, N. M. (2010). Loose chimney sweeps (about perspectives of application of viscous-free systems in oil production). Oil of Russia, 10, 84-85.
15. Panahov, G. M. (1995). Development and implementation of new composite systems in oil and gas production. Doctoral Dissertation Thesis. Baku.

In the presented work, the possibility of using modified multi-walled carbon nanotubes (MWCNTs) as reagents for increasing the oil recovery factor is considered. Carbon nanotubes were obtained by the method of chemical combination from the gas phase. Ethylene was used as the raw material. Further, the nanotubes were modified to obtain a stable aqueous MWCNT ash, subsequently used as an additive to the polyacrylamide solution.

Keywords: nanotechnologies; multi-walled carbon nanotubes; oil recovery enhancement.

References

1. Veliyev, E. F. (2021). Polymer dispersed system for in-situ fluid diversion. Prospecting and Development of Oil and Gas Fields, 1(78), 61-72.
2. Suleimanov, B. A., Veliyev, E. F., Naghiyeva, N. V. (2021). Colloidal dispersion gels for in-depth permeability modification. Modern Physics Letters B, 35(01), 2150038.
3. Suleimanov, B. A., Guseynova, N. I., Veliyev, E. F. (2017, October). Control of displacement front uniformity by fractal dimensions. SPE-187784-MS. In: SPE Russian Petroleum Technology Conference. Society of Petroleum Engineers.
4. Suleimanov, B. A., Veliyev, E. F., Naghiyeva, N. V. (2020). Preformed particle gels for enhanced oil recovery. International Journal of Modern Physics B, 34(28), 2050260.
5. Veliyev, E. F., Aliyev, A. A. (2021, October). Propagation of nano sized CDG deep into porous media. SPE-207024-MS. In: SPE Annual Caspian Technical Conference. Society of Petroleum Engineers.
6. Suleimanov, B. A., Veliyev, E. F., Aliyev, A. A. (2021). Impact of nanoparticle structure on the effectiveness of pickering emulsions for eor applications. ANAS Transactions, (1), 82-92.
7. Suleimanov, B. A., Veliyev, E. F. (2016). The effect of particle size distribution and the nano-sized additives on the quality of annulus isolation in well cementing. SOCAR proceedings, 4, 4-10.
8. Suleimanov, B. A., Dyshin, O. A., Veliyev, E. F. (2016, October). Compressive strength of polymer nanogels used for enhanced oil recovery EOR. SPE-181960-MS. In: SPE Russian Petroleum Technology Conference and Exhibition Society of Petroleum Engineers.
9. Veliyev, E. F., Aliyev, A. A., Mammadbayli, T. E. (2021). Machine learning application to predict the efficiency of water coning prevention. SOCAR Proceedings, 1, 104-113.
10. Shamilov, V. M., Babayev, E. R., Aliyeva, N. F. (2017). Polymer nanocomposites based on carboxymethylcellulose and nanoparticles (Al and Cu) for enhanced oil recovery. Oil and Gas Territory, 3, 14-15.
11. Suleimanov, B. A., Ismaylov, F. S., Veliyev, E. F. (2014). On the metal nanoparticles effect on the strength of polymer gels based on carboxymethyl cellulose, applying at oil recovery. Oil Industry, 1, 86-88.
12. Alsaba, M. T., Al Dushaishi M. F., Abbas A. K. (2020). A comprehensive review of nanoparticles applications in the oil and gas industry. Journal of Petroleum Exploration and Production Technology, 10, 1389-1399.
13. Shamilov, V. M. (2020). Potential applications of carbon nanomaterials in oil recovery. SOCAR Proceedings, 3, 90-107.
14. Feng, Y., Liu, S., Liu, H., et al. (2018). Study on mechanical performance of set cement modified with CNT. Drilling Fluid and Completion Fluid, 35(6), 93-97.
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The article is devoted to enhanced oil recovery (EOR) by displacement of residual oil with chemical agents in hard to recover reservoirs. SOCAR Oil Refinery alkaline waste (AW) is used as chemical product for EOR in the researches. Researches were carried out on pure AW and its solutions in different densities. 10% solution of water with AW decreases interfacial tension from 27 mN/m to 1.0 mN/m. PH value respectively increases from 7.5 to 9.5. Then, the researches were performed in simulated reservoir model. Primarly, the interlayer was created from solutions with AW in different densities, and then the displacement was carried out. Final oil recovery rate was 0.453 during oil displacement without AW. This ratio was respectively 0.54, 0.571 and 0.573 during displacement of oil with 5%, 10%, 15% solutions of AW. EOR with AW solution was carried out in QLD₄ horizon in Goshanohur area of Balakhany-Sabunchu-Ramana oil field. 2500 tons incremental oil was produced.

Keywords: enhanced oil recovery; residual oil; oil displacement; oil field; well.

References

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The positive effects of applying the technology for simultaneous separate operation (hereinafter referred to as SSO) include the reduction in capital investments for the construction of wells for each of the operational facilities, the cutback of operating costs and the development period of a multi-layer horizon, the increase in hydrocarbon production and the final oil recovery period from profitable operation of wells. In addition, the use of this technology contributes to increasing the utilization rate of downhole equipment and enhancing the reliability of the downhole device. The simultaneous separate operation technology is economically efficient due to the production of additional oil, a high profitability index and a low payback period.

Keywords: azimuth, zenith angle; off-vertical; well profile; doublelift tubing; liner filter; packers; valves.

References

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On the basis of large-scale gas-hydrodynamic balance models, the problem of optimizing the cyclic development of underground gas storage (UGS) facilities has been formulated and solved. An algorithm has been developed that allows optimal control of the UGS development process, taking into account the limitations on the flow rates of certain wells. For its implementation, a specific model structure of the Kalmaz UGS facility was selected. It is shown that optimal regulation of the values of flow rates and depressions of wells ensures minimal flooding of well products during the extraction of total gas, the values of reception and repression of wells ensure maximum removal of the gas-water boundary from the bottom of the well during the injection of total gas.

Keywords: optimization; underground gas storage; extraction; injection; flow rate; depression; repression.

References

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Portland cement is traditionally used in cementing of oil and gas wells. However, Portland cement has a number of shortcomings. The most important of these are the formation of microannuli between the cement plug and the rock or casing, as well as the formation of cracks and permeable channels in the cement matrix. Recent research shows that geopolymer can be a perspective alternate to portlandcement by overcoming beforementioned issues. The article comparatively analyzes the changes in the parameters of plugging materials containing geopolymer and Portland cement while contamination with water-based drilling mud. The results show that geopolymerbased solutions are more resistant to contamination with water-based drilling mud than Portland cement-based solutions. Thus, mixing Portland cement slurry with water-based drilling mud increases its viscosity and fluid loss, and sharply reduces its compressive strength. However, when a geopolymer solution is mixed with a water-based drilling fluid, its viscosity is almost unchanged, its fluid loss is reduced, and reduction in its compressive strength is less than in Portlandcement based material.

Keywords: portland cement; geopolymer; fly ash; cementing; water based mud; mud contamination.

References

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The operation modes of an extensional subsea pipeline of multiphase fluid at the initial stage of the offshore gas condensate field development under the conditions of liquid accumulation are studied. By means of the dynamic simulation of the slug flow mode, the frequency and volume of liquid plugs removed from the pipeline are analyzed as a function of the gas flow rate. It is demonstrated that with a decrease of the gas flow rate, the steadystate hydraulic calculations predict significantly lower values of the liquid volume flow rate at the pipeline outlet compared to the results of the dynamic simulation. The dynamics of the liquid removal from the pipeline with an increase of the gas flow rate is studied. It is shown that the surge liquid volume increases sharply at a rapid growth of the gas flow rate, which leads to restrictions on the increase in the well flow rate.

Keywords: subsea pipeline; natural gas; multiphase fluid; liquid accumulation; slug flow.

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