Pub Date : 2024-01-09DOI: 10.31660/0445-0108-2023-6-11-47-64
N. O. Matroshilov, A. M. Krylov, M. G. Kozlov, P. A. Lyhin, E. Usov, D. Tailakov, V. Ulyanov
In order to ensure efficient and safe operation of oil and gas fields, a tool is required to design production wells and surface infrastructure. It is important to take into account the physical processes that occur during production, as well as fluid properties and phase transitions. The "d-Flow" software package enables the creation of a comprehensive field model based on geological and field data to calculate hydraulic losses of pipelines and forecast hydrocarbon production. The fluid flow modelling is based on the calculation of multiphase friction with the wall of a well or a pipeline. The article discusses the implementation of four friction models: the Beggs-Brill model, the Gray model and its modification, and the Mukherjee-Brill model. The purpose of this work is to compare the predictions of friction models with the results obtained using commercial realizations of the same models. The results of the Schlumberger PIPESIM hydraulic simulator calculations were used as a benchmark for comparison with the "d-Flow" models. Numerical experiments were conducted to investigate two-phase flow under varying well geometry and flow regimes. The models used were compared, and the results showed that the predicted liquid holdup had an average relative error of 0.06%. In some cases, the error was as low as 0.02%. The predicted cumulative pressure drop in the well did not exceed 0.34% for all considered models. Based on the comparison results, we conclude that the "d-Flow" software package is suitable for calculating pressure drop in wells of different geometry and surface networks.
{"title":"Multiphase friction calculation peculiarities based on models implemented in the \"d-Flow\" software package","authors":"N. O. Matroshilov, A. M. Krylov, M. G. Kozlov, P. A. Lyhin, E. Usov, D. Tailakov, V. Ulyanov","doi":"10.31660/0445-0108-2023-6-11-47-64","DOIUrl":"https://doi.org/10.31660/0445-0108-2023-6-11-47-64","url":null,"abstract":"In order to ensure efficient and safe operation of oil and gas fields, a tool is required to design production wells and surface infrastructure. It is important to take into account the physical processes that occur during production, as well as fluid properties and phase transitions. The \"d-Flow\" software package enables the creation of a comprehensive field model based on geological and field data to calculate hydraulic losses of pipelines and forecast hydrocarbon production. The fluid flow modelling is based on the calculation of multiphase friction with the wall of a well or a pipeline. The article discusses the implementation of four friction models: the Beggs-Brill model, the Gray model and its modification, and the Mukherjee-Brill model. The purpose of this work is to compare the predictions of friction models with the results obtained using commercial realizations of the same models. The results of the Schlumberger PIPESIM hydraulic simulator calculations were used as a benchmark for comparison with the \"d-Flow\" models. Numerical experiments were conducted to investigate two-phase flow under varying well geometry and flow regimes. The models used were compared, and the results showed that the predicted liquid holdup had an average relative error of 0.06%. In some cases, the error was as low as 0.02%. The predicted cumulative pressure drop in the well did not exceed 0.34% for all considered models. Based on the comparison results, we conclude that the \"d-Flow\" software package is suitable for calculating pressure drop in wells of different geometry and surface networks.","PeriodicalId":240239,"journal":{"name":"Oil and Gas Studies","volume":"46 18","pages":""},"PeriodicalIF":0.0,"publicationDate":"2024-01-09","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"139442253","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
Pub Date : 2024-01-09DOI: 10.31660/0445-0108-2023-6-11-35-46
V. I. Lebedev, E. N. Musakaev, N. G. Musakaev, S. P. Rodionov
The active use of integrated modeling in reservoir engineering of oil fields has led to research to overcome the problems of its practical application. Typically, a 3D hydrodynamic model is used as a component characterizing the fluid flow in the reservoir. The downsides of the model are high computational complexity and low reliability of the initial data. Therefore, the objectives of the study are to construct an integrated reservoir-well model that does not have these drawbacks and to verify its adequacy. The article presents an integrated model for fast decision-making in the development of oil fields, as well as for analysis of the characteristics of the inter-well space, which doesn't require prior information about the reservoir. The integrated model is based on a representation of the analytical capacitance-resistance model (CRM), which considers shutdown periods of production wells. Oil flow rates are calculated using the Koval method. The pressure distribution in wells is calculated using a correlation similar to that used in the tNavigator software. A comparison was made between the calculation results obtained using the integrated model based on D-CRMP and the calculations in the tNavigator.
{"title":"Integrated model \"reservoir-well\" based on D-CRMP","authors":"V. I. Lebedev, E. N. Musakaev, N. G. Musakaev, S. P. Rodionov","doi":"10.31660/0445-0108-2023-6-11-35-46","DOIUrl":"https://doi.org/10.31660/0445-0108-2023-6-11-35-46","url":null,"abstract":"The active use of integrated modeling in reservoir engineering of oil fields has led to research to overcome the problems of its practical application. Typically, a 3D hydrodynamic model is used as a component characterizing the fluid flow in the reservoir. The downsides of the model are high computational complexity and low reliability of the initial data. Therefore, the objectives of the study are to construct an integrated reservoir-well model that does not have these drawbacks and to verify its adequacy. The article presents an integrated model for fast decision-making in the development of oil fields, as well as for analysis of the characteristics of the inter-well space, which doesn't require prior information about the reservoir. The integrated model is based on a representation of the analytical capacitance-resistance model (CRM), which considers shutdown periods of production wells. Oil flow rates are calculated using the Koval method. The pressure distribution in wells is calculated using a correlation similar to that used in the tNavigator software. A comparison was made between the calculation results obtained using the integrated model based on D-CRMP and the calculations in the tNavigator.","PeriodicalId":240239,"journal":{"name":"Oil and Gas Studies","volume":"21 3","pages":""},"PeriodicalIF":0.0,"publicationDate":"2024-01-09","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"139443770","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
Pub Date : 2024-01-09DOI: 10.31660/0445-0108-2023-6-11-88-97
E. Zhilyakov, I. Tomus, Z. Monakhova, S. A. Guzeeva, G. L. Petrov
Research into the criteria for selecting professionals to operate automated control systems for integrated oil and gas processing units involves evaluating the qualitative and quantitative characteristics of employees and applicants in this field. The operator of automated control systems plays a crucial role in ensuring the efficiency of oil and gas production, industrial safety, and labour protection at the enterprise. The process of professional selection complex and can be affected by various negative factors that affect the working capacity of the studied group. These factors include objective and subjective fatigue processes, as well as the activity of the central nervous system. The latter is dependent not only on a person's psychotype but also on the intensity of these factors. Additionally, extreme climatic and geographical working conditions, shift work, and harmful parameters in the production process can also be mentioned. The Professional Selection Programme was developed for an operator of the automated control system of the integrated oil and gas processing unit of LUKOIL-Western Siberia LLC, Kogalymneftegaz territorial production enterprise. The analysis of the data enabled us to establish the main requirements for this Programme and devise an algorithm for its implementation.
{"title":"Criteria approach to the professional selection of an operator of an automated control system for an integrated oil and gas processing unit at the Kogalymneftegaz territorial production enterprise","authors":"E. Zhilyakov, I. Tomus, Z. Monakhova, S. A. Guzeeva, G. L. Petrov","doi":"10.31660/0445-0108-2023-6-11-88-97","DOIUrl":"https://doi.org/10.31660/0445-0108-2023-6-11-88-97","url":null,"abstract":"Research into the criteria for selecting professionals to operate automated control systems for integrated oil and gas processing units involves evaluating the qualitative and quantitative characteristics of employees and applicants in this field. The operator of automated control systems plays a crucial role in ensuring the efficiency of oil and gas production, industrial safety, and labour protection at the enterprise. The process of professional selection complex and can be affected by various negative factors that affect the working capacity of the studied group. These factors include objective and subjective fatigue processes, as well as the activity of the central nervous system. The latter is dependent not only on a person's psychotype but also on the intensity of these factors. Additionally, extreme climatic and geographical working conditions, shift work, and harmful parameters in the production process can also be mentioned. The Professional Selection Programme was developed for an operator of the automated control system of the integrated oil and gas processing unit of LUKOIL-Western Siberia LLC, Kogalymneftegaz territorial production enterprise. The analysis of the data enabled us to establish the main requirements for this Programme and devise an algorithm for its implementation.","PeriodicalId":240239,"journal":{"name":"Oil and Gas Studies","volume":"42 50","pages":""},"PeriodicalIF":0.0,"publicationDate":"2024-01-09","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"139442225","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
Pub Date : 2024-01-09DOI: 10.31660/0445-0108-2023-6-11-65-77
E. V. Novitskaya, A. A. Shiryaev
This article provides an analysis of the process and optimization of horizontal wellbore tracking using geosteering control. Recently, the issue of high-quality and efficient drilling of wells through the reservoir and determining the position of the wellbore in the formations has been raised. In this regard, complex data analysis is used based on a 3D geological model and special software for well geosteering. In preparation for drilling a well, it is necessary to prepare voluminous, comprehensive information on previously drilled wells in a particular field and upload the results of seismic surveys. The article also describes an analysis of activities at various stages of drilling support, starting with geophysical reference and opening the target formation with the transport section. When drilling a horizontal section of a well, geosteering software is used while drilling wells, equipped with various tools, one of which is the 2D synthetic logging method. The method is based on the superposition of logging curves of a previously drilled reference vertical well and a directional well with a horizontal end currently being drilled. The two-dimensional synthetic logging method is the main and most optimal way to optimize the placement of wells with horizontal completion when drilling terrigenous reservoirs in Western Siberia.
{"title":"Geosteering, application of synthetic logging to horizontal wellbore sections","authors":"E. V. Novitskaya, A. A. Shiryaev","doi":"10.31660/0445-0108-2023-6-11-65-77","DOIUrl":"https://doi.org/10.31660/0445-0108-2023-6-11-65-77","url":null,"abstract":"This article provides an analysis of the process and optimization of horizontal wellbore tracking using geosteering control. Recently, the issue of high-quality and efficient drilling of wells through the reservoir and determining the position of the wellbore in the formations has been raised. In this regard, complex data analysis is used based on a 3D geological model and special software for well geosteering. In preparation for drilling a well, it is necessary to prepare voluminous, comprehensive information on previously drilled wells in a particular field and upload the results of seismic surveys. The article also describes an analysis of activities at various stages of drilling support, starting with geophysical reference and opening the target formation with the transport section. When drilling a horizontal section of a well, geosteering software is used while drilling wells, equipped with various tools, one of which is the 2D synthetic logging method. The method is based on the superposition of logging curves of a previously drilled reference vertical well and a directional well with a horizontal end currently being drilled. The two-dimensional synthetic logging method is the main and most optimal way to optimize the placement of wells with horizontal completion when drilling terrigenous reservoirs in Western Siberia.","PeriodicalId":240239,"journal":{"name":"Oil and Gas Studies","volume":"8 3","pages":""},"PeriodicalIF":0.0,"publicationDate":"2024-01-09","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"139443553","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
Pub Date : 2024-01-08DOI: 10.31660/0445-0108-2023-6-11-25-34
Yu. S. Kuznetsov, S. R. Ganiev, D. Sultanov, V. N. Fedorov, S. N. Bastrikov
The article presents the results of field experiments and field tests of wave technology for bottomhole cleaning and clogging of permeable formations. Acceleration of well construction time and avoidance of plugging (especially in gas wells) is extremely important nowadays. It is widely acknowledged that rock fractures occur due to the alternating motion of the flushing fluid, and it has significant implications for accelerating drilling processes and maintaining wellbore stability. This can be achieved through the wave motion of the flushing fluid. The experiments were conducted on a specialized installation that simulates downhole conditions, enabling the modeling of downhole processes. We created and tested various designs of wave generators to flush holes of bits with different types and sizes. Experimental evidence suggests that wave technology can aid in bottomhole cleaning and the creation of a colmatation screen. The wave action helps to keep the bottomhole zone and well walls clean, and significantly reduces the penetration of drilling fluid filtrate into the rock. The use of wave technology for bottomhole cleaning and permeable formation ringing shows great potential for oil and gas well construction. The sealing of the borehole space is crucial in the construction of Underground Gas Storage facilities.
{"title":"Experimental and field studies of wave technology for bottomhole cleaning and clogging of permeable formations","authors":"Yu. S. Kuznetsov, S. R. Ganiev, D. Sultanov, V. N. Fedorov, S. N. Bastrikov","doi":"10.31660/0445-0108-2023-6-11-25-34","DOIUrl":"https://doi.org/10.31660/0445-0108-2023-6-11-25-34","url":null,"abstract":"The article presents the results of field experiments and field tests of wave technology for bottomhole cleaning and clogging of permeable formations. Acceleration of well construction time and avoidance of plugging (especially in gas wells) is extremely important nowadays. It is widely acknowledged that rock fractures occur due to the alternating motion of the flushing fluid, and it has significant implications for accelerating drilling processes and maintaining wellbore stability. This can be achieved through the wave motion of the flushing fluid. The experiments were conducted on a specialized installation that simulates downhole conditions, enabling the modeling of downhole processes. We created and tested various designs of wave generators to flush holes of bits with different types and sizes. Experimental evidence suggests that wave technology can aid in bottomhole cleaning and the creation of a colmatation screen. The wave action helps to keep the bottomhole zone and well walls clean, and significantly reduces the penetration of drilling fluid filtrate into the rock. The use of wave technology for bottomhole cleaning and permeable formation ringing shows great potential for oil and gas well construction. The sealing of the borehole space is crucial in the construction of Underground Gas Storage facilities.","PeriodicalId":240239,"journal":{"name":"Oil and Gas Studies","volume":"57 8","pages":""},"PeriodicalIF":0.0,"publicationDate":"2024-01-08","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"139447814","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
Pub Date : 2024-01-08DOI: 10.31660/0445-0108-2023-6-11-24
R. R. Alekberov, A. A. Volf
The prerequisite for this study is the difficulty in interpreting data after stimulation of the bottomhole formation zone has been carried out. The objectives of this work are the applicability and interpretation of Step-rate-test (SRT) data to evaluate suitable injection regimes in multilayered, unconsolidated and weakly consolidated reservoirs and the demonstration of the correlation between injection rate and pressure in a graphical format. We investigated the stability of the reservoir structure to pressure gradients by increasing pressure and injecting fluid through the injection well stock. We concluded that this stability does not improve over time. This means that the practical significance of this method lies in its ability to alter the pressure gradient when injecting fluid to maintain a constant flow rate. The constancy of the pressure gradient has a major impact on the stimulation of the bottomhole formation zone and therefore it can be concluded that the reservoir properties in the bottomhole formation zone are dynamic in nature and can change over time. It should be noted that the study found that a change in pore pressure within the loose rock can also affect the phase (effective) permeability, which in turn can affect the required pressure gradients during injection.
{"title":"An interpretation of data after performing Step-rate-test in multi-layered, unconsolidated and weakly consolidated reservoirs","authors":"R. R. Alekberov, A. A. Volf","doi":"10.31660/0445-0108-2023-6-11-24","DOIUrl":"https://doi.org/10.31660/0445-0108-2023-6-11-24","url":null,"abstract":"The prerequisite for this study is the difficulty in interpreting data after stimulation of the bottomhole formation zone has been carried out. The objectives of this work are the applicability and interpretation of Step-rate-test (SRT) data to evaluate suitable injection regimes in multilayered, unconsolidated and weakly consolidated reservoirs and the demonstration of the correlation between injection rate and pressure in a graphical format. We investigated the stability of the reservoir structure to pressure gradients by increasing pressure and injecting fluid through the injection well stock. We concluded that this stability does not improve over time. This means that the practical significance of this method lies in its ability to alter the pressure gradient when injecting fluid to maintain a constant flow rate. The constancy of the pressure gradient has a major impact on the stimulation of the bottomhole formation zone and therefore it can be concluded that the reservoir properties in the bottomhole formation zone are dynamic in nature and can change over time. It should be noted that the study found that a change in pore pressure within the loose rock can also affect the phase (effective) permeability, which in turn can affect the required pressure gradients during injection.","PeriodicalId":240239,"journal":{"name":"Oil and Gas Studies","volume":"34 5","pages":""},"PeriodicalIF":0.0,"publicationDate":"2024-01-08","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"139445717","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
Pub Date : 2023-11-18DOI: 10.31660/0445-0108-2023-5-117-130
S. F. Mambetov, Y. Zemtsov
Currently, numerous enhanced oil recovery reagents and application technologies have been developed in the domains of flow rejection and injection profile levelling. The choice of stimulation methods is reliant on the geological and physical conditions of the reservoir. Therefore, the accuracy of this choice has a direct impact on the efficiency of implementing enhanced oil recovery technologies.The current availability of low-volume chemical enhanced oil recovery reagents for high-temperature reservoirs is limited, and their effectiveness varies. This article presents the results of a pilot study from 2018 to 2021 aimed at improving oil recovery in high-temperature reservoirs. The study involves evaluating approved levelling technologies for injection profiles that use thermotropic compositions "Complex 377" and "EOR701R", as well as the polymer composition "EOR909R". The geological and physical conditions of their approbation, as well as the primary injection parameters and resulting findings, are provided.This information will be valuable to professionals engaged in enhanced oil recovery methods for oil reservoirs, as well as those working on the implementation of physical and chemical methods for the same purpose.
{"title":"New in the range of reagents and technologies for chemical enhanced oil recovery in high-temperature reservoirs","authors":"S. F. Mambetov, Y. Zemtsov","doi":"10.31660/0445-0108-2023-5-117-130","DOIUrl":"https://doi.org/10.31660/0445-0108-2023-5-117-130","url":null,"abstract":"Currently, numerous enhanced oil recovery reagents and application technologies have been developed in the domains of flow rejection and injection profile levelling. The choice of stimulation methods is reliant on the geological and physical conditions of the reservoir. Therefore, the accuracy of this choice has a direct impact on the efficiency of implementing enhanced oil recovery technologies.The current availability of low-volume chemical enhanced oil recovery reagents for high-temperature reservoirs is limited, and their effectiveness varies. This article presents the results of a pilot study from 2018 to 2021 aimed at improving oil recovery in high-temperature reservoirs. The study involves evaluating approved levelling technologies for injection profiles that use thermotropic compositions \"Complex 377\" and \"EOR701R\", as well as the polymer composition \"EOR909R\". The geological and physical conditions of their approbation, as well as the primary injection parameters and resulting findings, are provided.This information will be valuable to professionals engaged in enhanced oil recovery methods for oil reservoirs, as well as those working on the implementation of physical and chemical methods for the same purpose.","PeriodicalId":240239,"journal":{"name":"Oil and Gas Studies","volume":"78 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2023-11-18","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"139261238","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
Pub Date : 2023-11-18DOI: 10.31660/0445-0108-2023-5-107-116
M. Fattahov, E. Babushkin, M. Buyanova, V. G. Vaulin, T. Sadykov, A. Shalyapina
One of the key tasks in oil and gas well development today is to optimize the cost of various technical processes, including the preparation of drilling muds. The article explores technological remedies to decrease the concentration of potassium chloride, which is the main inhibitor of the hydration of clay rocks, in the composition of drilling mud used for horizontal well drilling. Additionally, it was demonstrated that the drilling mud left after the initial drilling of the productive formation could be reused. Due to the fact that the interval of the horizontal section of wells is represented mainly by sandstone, the composition of the drilling mud must be refined so that the use of inhibitor reagents can be reduced. Reuse of spent drilling muds in the construction of horizontal wells reduces the consumption of multi-tonnage components without impairing the processability of the flushing fluid used. The implementation of this approach will enable the achievement of economic benefits through a reduction in expenses for the preparation of drilling mud and in the amount of drilling waste generated.
{"title":"Cost reduction in the construction of horizontal wells by optimizing the polymer-chloride drilling mud and its reuse","authors":"M. Fattahov, E. Babushkin, M. Buyanova, V. G. Vaulin, T. Sadykov, A. Shalyapina","doi":"10.31660/0445-0108-2023-5-107-116","DOIUrl":"https://doi.org/10.31660/0445-0108-2023-5-107-116","url":null,"abstract":"One of the key tasks in oil and gas well development today is to optimize the cost of various technical processes, including the preparation of drilling muds. The article explores technological remedies to decrease the concentration of potassium chloride, which is the main inhibitor of the hydration of clay rocks, in the composition of drilling mud used for horizontal well drilling. Additionally, it was demonstrated that the drilling mud left after the initial drilling of the productive formation could be reused. Due to the fact that the interval of the horizontal section of wells is represented mainly by sandstone, the composition of the drilling mud must be refined so that the use of inhibitor reagents can be reduced. Reuse of spent drilling muds in the construction of horizontal wells reduces the consumption of multi-tonnage components without impairing the processability of the flushing fluid used. The implementation of this approach will enable the achievement of economic benefits through a reduction in expenses for the preparation of drilling mud and in the amount of drilling waste generated.","PeriodicalId":240239,"journal":{"name":"Oil and Gas Studies","volume":"25 2","pages":""},"PeriodicalIF":0.0,"publicationDate":"2023-11-18","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"139262232","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
Pub Date : 2023-11-17DOI: 10.31660/0445-0108-2023-5-77-91
E. V. Panikarovskii, M. V. Raspopova, M. V. Ryazapov, A. A. Biletsky
When leaving the drilling of gas wells at the fields of Western Siberia, various methods and technologies are employed for their development, such as the secondary opening of productive formations. While undertaking the secondary opening, it is essential to maintain the reservoir properties of the bottomhole formation zone. Liquids for perforation work must be employed for this purpose. Simultaneously, it is recommended to use salt-based perforating liquids treated with CMC-700 and sulfacell, on a hydrocarbon basis (diesel fuel and gas condensate) and on acidic compositions with a high permeability recovery coefficient for carrying out perforation work at equilibrium and depression. After conducting laboratory experiments, we have selected perforating liquids with a permeability recovery coefficient of over 96 % and perforating liquids based on acid compositions with a permeability recovery coefficient of over 180 %.
{"title":"A study of perforation fluids for secondary opening of productive formations at the Bovanenkovo oil and gas condensate field","authors":"E. V. Panikarovskii, M. V. Raspopova, M. V. Ryazapov, A. A. Biletsky","doi":"10.31660/0445-0108-2023-5-77-91","DOIUrl":"https://doi.org/10.31660/0445-0108-2023-5-77-91","url":null,"abstract":"When leaving the drilling of gas wells at the fields of Western Siberia, various methods and technologies are employed for their development, such as the secondary opening of productive formations. While undertaking the secondary opening, it is essential to maintain the reservoir properties of the bottomhole formation zone. Liquids for perforation work must be employed for this purpose. Simultaneously, it is recommended to use salt-based perforating liquids treated with CMC-700 and sulfacell, on a hydrocarbon basis (diesel fuel and gas condensate) and on acidic compositions with a high permeability recovery coefficient for carrying out perforation work at equilibrium and depression. After conducting laboratory experiments, we have selected perforating liquids with a permeability recovery coefficient of over 96 % and perforating liquids based on acid compositions with a permeability recovery coefficient of over 180 %.","PeriodicalId":240239,"journal":{"name":"Oil and Gas Studies","volume":"8 10","pages":""},"PeriodicalIF":0.0,"publicationDate":"2023-11-17","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"139264488","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
Pub Date : 2023-11-17DOI: 10.31660/0445-0108-2023-5-67-76
E. Levitina, E. Inyakina, N. M. Paklinov
In the development of gas fields, reservoir pressure can be used to estimate gas reserves by means of the material balance methodology and to calculate drained reserves. This provides an indication of the effectiveness of the development system. The authors of the article suggest a methodology for determining drained reserves in wells without reservoir pressure measurements. This approach is useful if the well stock is put into operation concurrently or within a brief period of time. Numerical modelling and analysis of field development data have led the authors to conclude that the current flow rate of wells, the hydrodynamic parameters of the productive formation and the interference of nearby wells are the most significant factors controlling the amount of drained reserves. The use of this technique will improve the understanding of the current processes occurring in the reservoir, clarify the assessment of the energy of the deposit and the value of the initial gas reserves, and also create an additional source of information for timely and more accurate decision-making in field development. Adopting this methodology can improve the understanding of ongoing processes in the reservoir, enhance evaluations of reservoir energy and initial gas reserve sizes, and provide additional information resources for making decisions on field development in a more timely and precise manner.
{"title":"An estimation of reservoir pressure dynamics and recoverable gas reserves based on the data of production well surveys","authors":"E. Levitina, E. Inyakina, N. M. Paklinov","doi":"10.31660/0445-0108-2023-5-67-76","DOIUrl":"https://doi.org/10.31660/0445-0108-2023-5-67-76","url":null,"abstract":"In the development of gas fields, reservoir pressure can be used to estimate gas reserves by means of the material balance methodology and to calculate drained reserves. This provides an indication of the effectiveness of the development system. The authors of the article suggest a methodology for determining drained reserves in wells without reservoir pressure measurements. This approach is useful if the well stock is put into operation concurrently or within a brief period of time. Numerical modelling and analysis of field development data have led the authors to conclude that the current flow rate of wells, the hydrodynamic parameters of the productive formation and the interference of nearby wells are the most significant factors controlling the amount of drained reserves. The use of this technique will improve the understanding of the current processes occurring in the reservoir, clarify the assessment of the energy of the deposit and the value of the initial gas reserves, and also create an additional source of information for timely and more accurate decision-making in field development. Adopting this methodology can improve the understanding of ongoing processes in the reservoir, enhance evaluations of reservoir energy and initial gas reserve sizes, and provide additional information resources for making decisions on field development in a more timely and precise manner.","PeriodicalId":240239,"journal":{"name":"Oil and Gas Studies","volume":"73 4","pages":""},"PeriodicalIF":0.0,"publicationDate":"2023-11-17","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"139263023","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
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