Кафедра "Видобування нафти, газу та конденсату"

Постійне посилання колекціїhttps://repository.kpi.kharkov.ua/handle/KhPI-Press/927

Офіційний сайт кафедри http://web.kpi.kharkov.ua/dngik

Кафедра "Видобування нафти, газу та конденсату" була заснована в 2010 році для підготовки спеціалістів в нафтогазовій промисловості.

Характерною рисою діяльності кафедри "Видобування нафти, газу та конденсату" є постійний зв'язок з підприємствами та організаціями-замовниками фахівців. Випускники кафедри працюють у галузі видобування, транспортування, використання та реалізації нафти і газу, а також великої кількості сировини, отриманої при їх технологічній переробці.

Кафедра входить до складу Навчально-наукового інституту хімічних технологій та інженерії Національного технічного університету "Харківський політехнічний інститут".

У складі науково-педагогічного колективу кафедри працюють: 2 доктора технічних наук, 3 кандидата технічних наук; 2 співробітника мають звання професора, 1 – доцента, 1 – старшого наукового співробітника.

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Specifying the Methods to Calculate Thermal Efficiency of a Dual Production Well System "Fluid-Geoheat"
(2022) Fyk, M. I.; Biletskyi, V. S.; Abbood, M.; Desna, N. A.
Methods to calculate thermal efficiency of dual production well system “fluid-geoheat” have been specified for conditionally thin productive fluid-saturated seam in terms of radial planar filtration. It has been demonstrated that relative to a variant, ignoring Joule-Thompson effect, and variant of discrete Joule–Thomson coefficient substitution, calculation accuracy as for the well heat efficiency increases by 33% and 9% respectively. It has been proved that it is expedient for a conditionally thin seam to use effective temperature within the heat-exchange equitation with Fourier substitution as related to heat transfer while considering heat input in terms of unidirectional input to a virtual disk plate from the seam floor. In the context of the proposed calculation methods, increase in numerical estimations of thermal efficiency of a well results from the consideration of extra heat pumping owing to Joule-Thompson effect by rocks adjoining the productive formation.
Phenomenological model of an open-type geothermal system on the basis of oil-and-gas well
(2020) Fyk, M. I.; Biletskyi, V. S.
This paper relates to mining-well technologies. A theoretical and methodological approach is proposed to modeling geothermal well systems, which includes the development of: principal technological scheme of a geothermal system; schemes of transformation and movement of energy and a heat-transfer medium; the geothermal system phenomenological model; analysis of subprocesses and obtaining their mathematical models and, on this basis, the mathematical model of the geothermal model as a whole. An example of an advanced open-type geothermal well system is studied, which is based on the oil-and-gas well with one loop of circulation and the parallel connection of heat pumps at characteristic points of the system. The subprocesses of the developed phenomenological model are analysed and the characteristic features of their mathematical description are revealed; in particular, it is substantiated that the redistribution of heat power entering from a fluidsaturated bed is substantially dependent on the lateral wellbore geometry. Another important feature is to model the downhole heat pump and the modes in the scheme as a whole, which is based on the mass flow rate of a heat-transfer medium in its circulation loop. A generalized formula is presented for the heat power of the analysed advanced geothermal well system.
Resource evaluation of geothermal power plant under the conditions of carboniferous deposits usage in the Dnipro-Donetsk depression
(2018) Fyk, M. I.; Biletskyi, V. S.; Abbud, M.
The objective of the work is to substantiate the actualization of the problem of obtaining geothermal energy from oil and gas wells of oil and gas production facilities in the central-eastern part of the Dnieper-Donetsk Depression (DDD). The research methodology is based on the collection and statistical processing geophysical data of the DDD oil and gas deposits, the use of balance equations for energy and substance matter. The main result of the work is that the principal technological scheme of the geothermal system has been developed and the geothermal potential of oil and gas wells in the experimental zone has been analyzed. There have been considered the technological and ecological aspects of geothermal heat usage from depleted deposits of the DDD wells, which were disclosed into сarboniferous deposits productive horizons.
Improved thermogasodynamic model of a geothermal gas condensative deposit with production well
(2019) Fyk, M. I.; Biletskyi, V. S.; Al-sultan, M. B.; Abbood, M. H.
It is shown in the work that the wells-fluid are extracted from rocks by heat-retaining fluid from the open geothermal reservoir as from object with distributed cross-sectional parameters. This is due to the fact that the actual temperature distribution of the geothermal reservoir in dynamics affects the thermal properties of fluid-retaining rocks, which in turn affect the coefficient of heat exchange and heat transfer along the cross-section between the moving fluid, the fluid-retaining layer and adjacent rocks. The static temperature field of the original geothermal gradients in the case of outflow injection of the circulating coolant changes from the sides of the reservoir to the wellbore. A model of geothermal reservoir of gas-condensate well has been developed, which takes into account changes of thermal conductivity of rocks from the reservoir counture to the well bottom. The model includes refined equations of thermal energy balance for radial filtration of well production, containing convective and conductive components of heat exchange and heat flow. This allows, in comparison with the known methodological approaches, to clarify by 12-14% the forecast of heat extraction from a geothermal reservoir with a circulating coolant thrue the bottom and productive layer of a gas-condensate well.
Examining the current of drilling mud in a power section of the screw down-hole motor
(Технологический центр, 2018) Biletskyi, V. S.; Vitryk, V.; Mishchuk, Y.; Fyk, M. I.; Dzhus, A.; Kovalchuk, Yu.; Romanyshyn, T.; Yurych, A.
By using the module Flow Simulation from the programming environment SolidWorks, we obtained parametric fields of turbulent flow of drilling mud in the subject of research – a power section of the screw down-hole motor (SDM). The subject of research is the characteristics of turbulence of the drilling mud flow. An analysis of the obtained model parametric fields of turbulent flow of drilling mud in the power section of SDM shows two distinctive regions that differ by the characteristics of turbulence in the drilling mud current. These sections are localized in the neighborhood of contact points "rotor-stator", and along the distance between these points. In the first section, the developed flow turbulence almost disappears; the dissipation of flow energy significantly decreases. In the second section, there is a developed turbulence of drilling mud, which causes increased dissipation of flow energy and a possible damage to the stator by a solid phase of drilling mud. Turbulent time scale in the second region reaches the minimum values of 0.001 s, and the metrical scale of pulsations is comparatively small – from 0.011 to 5.666 m, indicating the presence of small-scale turbulent vortices and the elevated dissipation of flow energy. Thus, the second section is the most vulnerable to a damage to the stator by a solid phase of drilling mud. An endoscopic examination of the surface of the SDM stator, which we conducted, revealed damage to its working surface, specifically deep scratches, guide scratches, cavities. Localization of damage is from the middle and to the tail part of the power section at a distance of 2.53−4.78 m from the beginning of the power section of SDM. The models obtained are recommended for using in hydraulic calculations of SDM, for choosing a rational mode of its operation.
Energy-saving intensification of gas-condensate field production in the East of Ukraine using foaming reagents
(Dnipro University of Technology, 2019) Shendrik, O.; Fyk, M. I. ; Biletskyi, V. S.; Kryvulia, S.; Donskyi, D.; Alajmeen, A.; Pokhylko, A.
Purpose. Development of recommendations on the use of foaming surfactants (FSs) in the overall task of increasing energy and resource conservation of wells at the final stages of the development of gas condensate fields (GCFs). Methods. To achieve the goal and solve the set tasks, following methods were used: active experiment method, regression and correlation analyzes of the obtained statistical data, comparative analysis of technological regulations for the intensification of well production. Findings. Recommendations on the use of the studied FSs for intensifying the extraction of gas-condensate fluids with the specification of the geological and field characteristics of exploited fields in Eastern Ukraine in terms of Shebelynske and Zakhidno-Khrestyshchenske GСF were developed. Originality. The dependence of the cross-correlation coefficient of the "additional gas production with the use of FSs – the number of well stimulation operations" upon the period of the influence of the FSs on the reservoir – well system, being of extreme nature, has been determined. It has been established that the effectiveness of the use of the additional part of productions debit depends linearly on the initial production rate and exponentially on the frequency of the well FS-treatment. Practical implications. It has been determined that the maximum manifestation of the impact of considered FSs on downhole fluid production is achieved after 2 months. Various techniques for the application of the FSs were tested, and the regulations for the corresponding field operations were specified. Optimization of the parameter charts and processing procedures in terms of the concentration of FSs, system connection of the foam injection pipeline to the well, the rational period of introduction of the FSs in the reservoir-well system results in the decrease of the total downtime of wells during the period of operation under conditions of intensification as well as methane pollutions during purges.
A methodology for calculating the productivity of a hydrocarbon-geothermal well
(2021) Fyk, M. I.; Biletskyi, V. S.; Desna, N. A.
The article deals with the development of a refined methodology for calculating the production rate of a hydrocarbon-geothermal well under a non-isothermal lifting mode. The proposed methodology compares favourably with the basic one by taking into account the mutual influence of pressure head losses and those of thermal energy. This problem was solved by taking into consideration the convective component of heat exchange in a vertical (inclined) pipe when assessing hydraulic pressure head losses due to viscous friction. The methodology was tested for the conditions of Kotelev gas condensate field. The discrepancy between the values calculated according to the basic and the proposed methodologies for the heat flow rate constitute 4-7 % on average, while for the fluid flow rate the discrepancy averages 2.5-8.5 %. The possibility was proved of optimizing the dual mode of operation of a hydrocarbon-geothermal well in terms of the combined thermal energy being produced and the caloric heat energy of the gas condensate combustion.
Geothermal heat use to eliminate hydrate formations in oil deposit injection wells
(2021) Fyk, M. I.; Biletskyi, V. S.; Abbood, M.; Anzian, F.
The article is devoted to an actual issue: the development of internal downhole heat exchangers technology to combat hydration in injection wells. Purpose: development of conceptual solutions for the use of geothermal coolant in the internal well heat exchanger of the injection well. A scheme of an internal downhole heat exchanger with a geothermal heat carrier has been developed, and includes a supply line of a geothermal carrier through the heat exchange surface of the injection well into the productive reservoir of the oil field. The scheme provides targeted utilization of thermobaric energy of a geothermal source to combat hydration in the injection well. A mathematical apparatus for describing the process of heat utilization and heat exchange in injection well is proposed. It is established that the capacity of one geothermal well discovered at the oil depths in the Dnipro-Donetsk basin is sufficient to eliminate hydration in 1-3 injection wells, and determines the feasibility of their joint work.
Improvement of an engineering procedure for calculating the nonisothermal transportation of a gasliquid mixture
(Технологический центр, 2019) Fyk, M. I.; Biletskyi, V. S.; Fyk, I.; Bondarenko, Volodymyr; Mohammed, Bassam Al-Sultan
The study that we conducted into the process of transportation of a gas-condensate mixture from a well bottom to the separation production plant has revealed the features of isothermal and non-isothermal flow. It was proved that during non-isothermal flow, hydraulic losses in the product pipeline are significantly affected by throttle effect and energy accommodation effect. The influence of velocity and volumetric flow rate of the gas-liquid mixtures on hydraulic resistance and pressure drop on a section of product pipeline, taking into consideration non-isothermal flow was analyzed. It was found that the assessment of hydraulic resistance and pressure drop in the proposed dependences converges with standardized ones by 95 %. The result was obtained based on the developed system of equations of the mathematical model for non-isothermal non-stationary one-dimensional motion of the gas-liquid mixture of hydrocarbons in the pipeline. The proposed system beneficially differs from the known ones by the fact that it takes into consideration the inner convective heat exchange, estimated by the combined effect of Joule-Thomson. A distinctive feature of the improved procedure for calculation was the introduction of temperature correction and accommodation coefficient in the calculation of hydraulic resistance of a pipeline as a system with distributed parameters. Due to this, it became possible to improve the procedure for the calculation of non-isothermal transportation of a homogeneous gas-condensate mixture. Based on the analysis of calculation curves by the known procedures (formulas of Thomas Colebrooke, Leibenson and VNIIgas) for isothermal and non-isothermal processes and the proposed procedure, rational areas of their applications were shown. All calculations were performed at the velocity of a gas-liquid flow within the range 0–50 m/s, pipe roughness of 0.01–0.05 mm and their diameter of 100–300 mm, the data from actual production pipelines of Novotroitsk oil-gas condensate field were used. Comparison of the theoretical and industrial experiments showed sufficient for engineering practice accuracy of calculation of pressure drop on the stretches of oil and gas lead lines and allowed recommending the developed analytical dependences for the introduction in industrial engineering.
Theoretical and applied aspects of using a thermal pump effect in gas pipeline systems
(Технологический центр, 2018) Fyk, M. I.; Fyk, I.; Biletskyi, V. S.; Oliynyk, Max; Kovalchuk, Yulia; Hnieushev, Volodymyr; Shapchenko, Yevhen
Based on the classical method for calculating parameters of gas pipelines using electrohydraulic analogy, a mathematical model of the object, the process of gas transmission in an industrial pipeline, has been developed. The study subject was the change of gas temperature after its passing through a throttling device which brings about thermal pump effect in the receiving strand of the gas pipeline. It was proposed to use gas-dynamic thermal pumps to minimize the risk of plug and hydrate formation in the gas pipeline of Kharkivtransgaz Co. It was shown that the change of the ground body temperature by ±10 °C in the 20 km long gas transmission section of the multi-strand pipeline system causes a change of gas pressure by 5−15 %. A theoretical-empirical formula for determining the Joule-Thomson coefficient was derived which allows one to estimate the thermal pump effect on the energy and thermobaric parameters of nonstationary gas transmission processes. It was determined that the integral coefficient of performance (COP) for the network system of multi-strand pipelines including gas-dynamic thermal pumps varies within the range of 1.00‒1.09 depending on the ambient temperature (0−20 °C). The principles of constructing the topology of the diagram of the gas pipeline with bridges and branches which, due to the use of the thermal pump effect, ensures a minimal risk of plugging and hydration consist in activation and regulation of the energy-transforming and heat exchange processes in the sections of the network system. This is achieved by introduction of additional throttling devices in front of the bridges and branches of the pipeline and by checking for proximity and bordering with critical temperatures of plug and hydrate formation.