Pub Date : 2023-05-30DOI: 10.17122/ngdelo-2023-2-86-91
Romeu Delgado Geyker, C. Buchillon
Cuba advances in the development of drilling long extended reach wells (ERD). An extended range well is defined as one that has a true horizontal deviation-vertical depth (MD/TVD) ratio of more than 2.0. This relationship is an indication of the high complexity of conducting or constructing these types of wells: the higher the ratio, the more complex the well. It is important to note that this is only a basic indicator of the difficulty of drilling and completion of the well. Most of the recently developed wells of this type are in the north-west fields of Cuba, between the provinces of Havana and Matanzas. The True Vertical Depth (TVD) is 1,500 to 2,000 meters, and the horizontal displacement is up to 8,000 meters. However, experience has shown that the quality of the cementation of the extended reach wells in Cuba does not correspond to what is required. Among the most common problems affecting the cementation work of oil wells we can find the poor condition of the well (deviation, well stability, layer of cuts, etc.); poor condition of the mud (high gel stability, high circulation or filtration losses, high solids content, loss of circulating material, incompatibility between drilling fluid and cement); loss of circulation; abnormal pressures (abnormally low pressures, high pressures, etc.). One of the most complex problems to solve by well construction is poor centralization: cement is unevenly distributed throughout the cladding, leaving the cuttings in place. The paper reveals the main problems identified in the cementing long extended reach wells in Cuba and some technological proposals for their solution.
{"title":"THE MAIN PROBLEMS IN THE CEMENTING LONG EXTENDED REACH WELLS IN CUBA","authors":"Romeu Delgado Geyker, C. Buchillon","doi":"10.17122/ngdelo-2023-2-86-91","DOIUrl":"https://doi.org/10.17122/ngdelo-2023-2-86-91","url":null,"abstract":"Cuba advances in the development of drilling long extended reach wells (ERD). An extended range well is defined as one that has a true horizontal deviation-vertical depth (MD/TVD) ratio of more than 2.0. This relationship is an indication of the high complexity of conducting or constructing these types of wells: the higher the ratio, the more complex the well. It is important to note that this is only a basic indicator of the difficulty of drilling and completion of the well. Most of the recently developed wells of this type are in the north-west fields of Cuba, between the provinces of Havana and Matanzas. The True Vertical Depth (TVD) is 1,500 to 2,000 meters, and the horizontal displacement is up to 8,000 meters. However, experience has shown that the quality of the cementation of the extended reach wells in Cuba does not correspond to what is required. Among the most common problems affecting the cementation work of oil wells we can find the poor condition of the well (deviation, well stability, layer of cuts, etc.); poor condition of the mud (high gel stability, high circulation or filtration losses, high solids content, loss of circulating material, incompatibility between drilling fluid and cement); loss of circulation; abnormal pressures (abnormally low pressures, high pressures, etc.). One of the most complex problems to solve by well construction is poor centralization: cement is unevenly distributed throughout the cladding, leaving the cuttings in place. The paper reveals the main problems identified in the cementing long extended reach wells in Cuba and some technological proposals for their solution.","PeriodicalId":9748,"journal":{"name":"Chemical and Petroleum Engineering","volume":"322 1","pages":""},"PeriodicalIF":0.3,"publicationDate":"2023-05-30","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"80286142","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 : 2023-05-30DOI: 10.17122/ngdelo-2023-2-127-138
V. Nekuchaev, A.V. Tarsin, P. V. Fedorov
The purpose of this work is to calculate the shear pressure gradient and shear radius of paraffinic oil in a stopped pipeline as functions of the longitudinal coordinate z along the axis of the stopped section, as well as the minimum shear pressure difference between the ends of the pipeline, taking into account the non-uniform cooling of oil over time in the radial direction, leading to a significant increase in static shear stress with distance from the center to the edge of the pipe. Using a simple mathematical model that describes the non-uniform cooling of oil along the radius r and along the longitudinal coordinate z along the pipe axis due to heat conduction, it is shown that with a smooth increase in start-up pressure at the beginning of a stopped pipeline section, the cooling oil can shift not along the pipe wall, but along its central part, the radius of which depends both on the oil cooling time and on the z coordinate along the pipeline axis. Calculations show that the process of cooling of the stopped oil can be conditionally divided into three stages. At the first time stage of cooling, the oil near the pipeline axis does not cool down to the temperature of the appearance of static shear stress, that is, it is actually Newtonian and there is no problem with starting this oil layer. At the third time stage of cooling, when the oil cools below the temperature of the onset of paraffin mass crystallization, that is, it turns into a viscous-plastic one in the entire volume of the oil pipeline, the calculation of the minimum pressure difference between the ends of the pipe required to start the oil pipeline can be carried out using a method that qualitatively coincides with the method described in [27]. Finally, in the second cooling time step, which occupies an intermediate position between the first and third steps, the pipeline can be divided into two sections in the longitudinal direction. The behavior of oil in the first section, adjacent to the beginning of the pipeline, resembles the behavior of oil in the entire pipeline at the end of the first stage of cooling, and in the second section, extending from the end of the first section to the end of the pipe, the oil behaves similarly to the oil in the entire pipeline in the third temporary stage of cooling. In this case, the boundary between the first and second sections of the pipe during the second temporary stage of cooling is displaced from the end of the pipeline to its beginning. It is shown that calculations of the shear pressure required to resume the pumping of cooled oil, which do not take into account the inhomogeneous cooling of oil in the pipe cross section, can overestimate the desired pressure value. This fact should be taken into account in practice when assessing the restart pressure and the safe shutdown time of a pipeline transporting highly pourable oils using the “hot” pumping method. All laboratory measurements of the thermal parameters of oil, as well as calc
{"title":"THE INFLUENCE OF INHOMOGENEOUS RADIAL PROFILE OF WAXY CRUDE OIL TEMPERATURE AND SHEAR STRESS IN A STOPPED PIPELINE ON THE RESTART PUMPING PRESSURE FOR «USA — UKHTA» MAIN PIPELINE","authors":"V. Nekuchaev, A.V. Tarsin, P. V. Fedorov","doi":"10.17122/ngdelo-2023-2-127-138","DOIUrl":"https://doi.org/10.17122/ngdelo-2023-2-127-138","url":null,"abstract":"The purpose of this work is to calculate the shear pressure gradient and shear radius of paraffinic oil in a stopped pipeline as functions of the longitudinal coordinate z along the axis of the stopped section, as well as the minimum shear pressure difference between the ends of the pipeline, taking into account the non-uniform cooling of oil over time in the radial direction, leading to a significant increase in static shear stress with distance from the center to the edge of the pipe. Using a simple mathematical model that describes the non-uniform cooling of oil along the radius r and along the longitudinal coordinate z along the pipe axis due to heat conduction, it is shown that with a smooth increase in start-up pressure at the beginning of a stopped pipeline section, the cooling oil can shift not along the pipe wall, but along its central part, the radius of which depends both on the oil cooling time and on the z coordinate along the pipeline axis. Calculations show that the process of cooling of the stopped oil can be conditionally divided into three stages. At the first time stage of cooling, the oil near the pipeline axis does not cool down to the temperature of the appearance of static shear stress, that is, it is actually Newtonian and there is no problem with starting this oil layer. At the third time stage of cooling, when the oil cools below the temperature of the onset of paraffin mass crystallization, that is, it turns into a viscous-plastic one in the entire volume of the oil pipeline, the calculation of the minimum pressure difference between the ends of the pipe required to start the oil pipeline can be carried out using a method that qualitatively coincides with the method described in [27]. Finally, in the second cooling time step, which occupies an intermediate position between the first and third steps, the pipeline can be divided into two sections in the longitudinal direction. The behavior of oil in the first section, adjacent to the beginning of the pipeline, resembles the behavior of oil in the entire pipeline at the end of the first stage of cooling, and \u0000in the second section, extending from the end of the first section to the end of the pipe, the oil behaves similarly to the oil in the entire pipeline in the third temporary stage of cooling. In this case, the boundary between the first and second sections of the pipe during the second temporary stage of cooling is displaced from the end of the pipeline to its beginning. \u0000It is shown that calculations of the shear pressure required to resume the pumping of cooled oil, which do not take into account the inhomogeneous cooling of oil in the pipe cross section, can overestimate the desired pressure value. This fact should be taken into account in practice when assessing the restart pressure and the safe shutdown time of a pipeline transporting highly pourable oils using the “hot” pumping method. All laboratory measurements of the thermal parameters of oil, as well as calc","PeriodicalId":9748,"journal":{"name":"Chemical and Petroleum Engineering","volume":"8 1","pages":""},"PeriodicalIF":0.3,"publicationDate":"2023-05-30","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"78718256","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 : 2023-05-30DOI: 10.17122/ngdelo-2023-2-99-104
T. Ibrahimli
Large-scale experimental hydrogasodynamic studies of the flow of a two-phase gas-liquid mixture in a vertical pipeline were carried out. Based on the analysis of the results of these experimental studies, it was found that among the results obtained there are dependencies with theoretical bases by which theoretical hydrogasodynamic methods for studying multiphase flow in a vertical pipeline can be developed. The article provides a theoretical hydrogasodynamic study using dependencies describing a two-phase flow in a vertical pipeline of a round section, and it is confirmed by existing experiments. As a result of the gas-hydrodynamic study of pumping wells, in order to confirm the rational use of formation gas energy, a positive effect due to an increase in oil production rate and well process parameters, a relationship was established between well Q production rate, bottom-hole pressure of well P and production of formation gas V. Parameters can be modeled using three-term polynomials. During operation of wells in three modes (Qi, Vi or ∆Pi,Vi, where i = 1,2,3), processing of data obtained as a result of studies, indicators determined by existing research methods were obtained, and the technological mode ensuring layer-bylayer cooperation of the well system was selected. It is known that the motion of a two-phase flow of gas-liquid mixtures in a vertical pipe string is described on the basis of energy balance theory. The hydrogasodynamic characteristics of the drainage zone can be obtained in a real oil and gas well, as an experimental installation in the form of
{"title":"UNIVERSAL HYDROGAS-DYNAMIC PATTERNS OF THE DRAINAGE ZONE OF OIL AND GAS WELLS","authors":"T. Ibrahimli","doi":"10.17122/ngdelo-2023-2-99-104","DOIUrl":"https://doi.org/10.17122/ngdelo-2023-2-99-104","url":null,"abstract":"Large-scale experimental hydrogasodynamic studies of the flow of a two-phase gas-liquid mixture in a vertical pipeline were carried out. Based on the analysis of the results of these experimental studies, it was found that among the results obtained there are dependencies with theoretical bases by which theoretical hydrogasodynamic methods for studying multiphase flow in a vertical pipeline can be developed. The article provides a theoretical hydrogasodynamic study using dependencies describing a two-phase flow in a vertical pipeline of a round section, and it is confirmed by existing experiments. As a result of the gas-hydrodynamic study of pumping wells, in order to confirm the rational use of formation gas energy, a positive effect due to an increase in oil production rate and well process parameters, a relationship was established between well Q production rate, bottom-hole pressure of well P and production of formation gas V. Parameters can be modeled using three-term polynomials. During operation of wells in three modes (Qi, Vi or ∆Pi,Vi, where i = 1,2,3), processing of data obtained as a result of studies, indicators determined by existing research methods were obtained, and the technological mode ensuring layer-bylayer cooperation of the well system was selected. \u0000It is known that the motion of a two-phase flow of gas-liquid mixtures in a vertical pipe string is described on the basis of energy balance theory. The hydrogasodynamic characteristics of the drainage zone can be obtained in a real oil and gas well, as an experimental installation in the form of","PeriodicalId":9748,"journal":{"name":"Chemical and Petroleum Engineering","volume":"1 1","pages":""},"PeriodicalIF":0.3,"publicationDate":"2023-05-30","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"79778009","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 : 2023-05-30DOI: 10.17122/ngdelo-2023-2-139-150
I. M. Vanchugov, S. Vatuzov, K. S. Rezanov, R. A. Shestakov
The possibility of developing the liquefied natural gas (LNG) market in the Russian Federation can be realized by increasing the projects of low-tonnage LNG production. The development of LNG production projects at gas distribution stations should be a priority, since in this case it is possible to implement various production schemes: expander, throttle or cycle with a vortex pipe. To assess the efficiency of the use of low-tonnage LNG production at gas distribution stations (GDS), the dynamics of changes in maximum and minimum pressure values in the main gas pipeline, as well as the distribution of GDS by seasonal change in pressure drop and throughput are presented. To assess the operability and applicability of the work, a design model of the natural gas liquefaction throttle cycle was built and numerical modeling of its operation was carried out at seasonal fluctuations in pressures and GDS costs, which showed a strong dependence on these fluctuations and a low degree of natural gas liquefaction. In order to further modernize the liquefaction cycles of natural gas, modeling was carried out according to the turbo expander cycle, which also showed a dependence on seasonality, but a higher degree of liquefaction of natural gas, which during modeling reached more than 8%. The final stage was the construction of a design model of the combined technology — throttling and turbo expander cycles, as well as numerical modeling, which showed the possibility of increasing the liquefaction of natural gas at GDS to 19%, but the impact of seasonal fluctuations also remains significant. Summing up, it can be said that the work has worked out options for the transition from the throttle cycle to the throttle-expander and turbo-expander, as a result of which it was concluded that the operation of each cycle is effective, due to which it is possible to expand the LNG production network at the GDS at various input pressures, flow rates and the required degree of liquefaction of natural gas.
{"title":"MODERNIZATION OF THE NATURAL GAS LIQUEFACTION CYCLE AT GAS DISTRIBUTION STATIONS","authors":"I. M. Vanchugov, S. Vatuzov, K. S. Rezanov, R. A. Shestakov","doi":"10.17122/ngdelo-2023-2-139-150","DOIUrl":"https://doi.org/10.17122/ngdelo-2023-2-139-150","url":null,"abstract":"The possibility of developing the liquefied natural gas (LNG) market in the Russian Federation can be realized by increasing the projects of low-tonnage LNG production. The development of LNG production projects at gas distribution stations should be a priority, since in this case it is possible to implement various production schemes: expander, throttle or cycle with a vortex pipe. To assess the efficiency of the use of low-tonnage LNG production at gas distribution stations (GDS), the dynamics of changes in maximum and minimum pressure values in the main gas pipeline, as well as the distribution of GDS by seasonal change in pressure drop and throughput are presented. To assess the operability and applicability of the work, a design model of the natural gas liquefaction throttle cycle was built and numerical modeling of its operation was carried out at seasonal fluctuations in pressures and GDS costs, which showed a strong dependence on these fluctuations and a low degree of natural gas liquefaction. In order to further modernize the liquefaction cycles of natural gas, modeling was carried out according to the turbo expander cycle, which also showed a dependence on seasonality, but a higher degree of liquefaction of natural gas, which during modeling reached more than 8%. The final stage was the construction of a design model of the combined technology — throttling and turbo expander cycles, as well as numerical modeling, which showed the possibility of increasing the liquefaction of natural gas at GDS to 19%, but the impact of seasonal fluctuations also remains significant. Summing up, it can be said that the work has worked out options for the transition from the throttle cycle to the throttle-expander and turbo-expander, as a result of which it was concluded that the operation of each cycle is effective, due to which it is possible to expand the LNG production network at the GDS at various input pressures, flow rates and the required degree of liquefaction of natural gas.","PeriodicalId":9748,"journal":{"name":"Chemical and Petroleum Engineering","volume":"21 1","pages":""},"PeriodicalIF":0.3,"publicationDate":"2023-05-30","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"81777899","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 : 2023-05-30DOI: 10.17122/ngdelo-2023-2-17-24
V. Gusakov, A. Korolev, R. Yagudin, V. V. Bokarev, P.I. Baturin, A. Telin
Silencing of wells in the conditions of the Jurassic facilities developed by «Kharampurneftegaz» LLC is complicated by a number of negative factors, such as low permeability of the hydrophilic reservoir collector, high gas factor, low reservoir pressure, which significantly reduce the success of underground repair of wells (URW). To eliminate the influence of these complications in URW, an approach to silencing technology has been developed, which consists in combining several types of technological fluids, which, when used together, can eliminate the risks of reducing the production potential of wells after repair. So, to prevent gas manifestations during the URW, a blocking liquid based on the polymer «Biopol» and surfactant (gas-blocking compound, GasoBC) has been developed, acting due to its viscoelastic properties (polymer) and foaming ability in contact with gas (surfactant). A buffer liquid designed to prevent swelling of clay cement, reduce interfacial tension and restore phase permeability in oil was developed on the basis of a 6% HCl solution with the addition of a surfactanthydrophobizer (buffer hydrochloric acid liquid, BufHA). Blocking silencing compound (BSС) based on a Biopol polymer solution with a suspended suspension of microcalcite (BSС-microcalcite) and halite (BSС-halite) allows to prevent the absorption of silencing fluid at reduced reservoir pressure in wells with hydraulic fracturing. Pilot field testing of the technology of silencing wells with multiple complications was carried out at 23 wells, where GasoBС block packs were used 21 times, BufHA — 9 times, BSC-halite and BSC-microcalcite — 14 and 9 times, respectively. 8 typical silencing plans have been compiled for various parameters of wells. The results of research and development works are fixed in the Instructions of «Kharampurneftegaz» LLC on the topic «Selection of blocking silencing compounds during well repair».
{"title":"WELL SILENCING TECHNOLOGIES IN CONDITIONS OF MULTIPLE COMPLICATIONS","authors":"V. Gusakov, A. Korolev, R. Yagudin, V. V. Bokarev, P.I. Baturin, A. Telin","doi":"10.17122/ngdelo-2023-2-17-24","DOIUrl":"https://doi.org/10.17122/ngdelo-2023-2-17-24","url":null,"abstract":"Silencing of wells in the conditions of the Jurassic facilities developed by «Kharampurneftegaz» LLC is complicated by a number of negative factors, such as low permeability of the hydrophilic reservoir collector, high gas factor, low reservoir pressure, which significantly reduce the success of underground repair of wells (URW). To eliminate the influence of these complications in URW, an approach to silencing technology has been developed, which consists in combining several types of technological fluids, which, when used together, can eliminate the risks of reducing the production potential of wells after repair. So, to prevent gas manifestations during the URW, a blocking liquid based on the polymer «Biopol» and surfactant (gas-blocking compound, GasoBC) has been developed, acting due to its viscoelastic properties (polymer) and foaming ability in contact with gas (surfactant). A buffer liquid designed to prevent swelling of clay cement, reduce interfacial tension and restore phase permeability in oil was developed on the basis of a 6% HCl solution with the addition of a surfactanthydrophobizer (buffer hydrochloric acid liquid, BufHA). Blocking silencing compound (BSС) based on a Biopol polymer solution with a suspended suspension of microcalcite (BSС-microcalcite) and halite (BSС-halite) allows to prevent the absorption of silencing fluid at reduced reservoir pressure in wells with hydraulic fracturing. \u0000Pilot field testing of the technology of silencing wells with multiple complications was carried out at 23 wells, where GasoBС block packs were used 21 times, BufHA — 9 times, BSC-halite and BSC-microcalcite — 14 and 9 times, respectively. \u00008 typical silencing plans have been compiled for various parameters of wells. The results of research and development works are fixed in the Instructions of «Kharampurneftegaz» LLC on the topic «Selection of blocking silencing compounds during well repair».","PeriodicalId":9748,"journal":{"name":"Chemical and Petroleum Engineering","volume":"174 1","pages":""},"PeriodicalIF":0.3,"publicationDate":"2023-05-30","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"76918721","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 : 2023-05-30DOI: 10.17122/ngdelo-2023-2-6-16
N. Zakirov, V. Alexandrov, A. K. Yagafarov, V. Spasibov, Zh.S. Popova
In the practice of any exploration or oil producing enterprise, the parameters of a productive or potentially promising geological target are estimated using a method of temporary tracking and recording of a change in level/pressure based on the classical principle of sequential change of stationary states. Its main drawback against the background of wide practical application is the incorrect determination of the reliable value of the productivity coefficient (Kprod) for complex reservoir rocks, especially those with strong texture heterogeneity, which in reality is not enough to draw up high-quality and most importantly real design technological documents for the integrated development of oil and gas fields. Hence the large degree of conventionality of the results obtained during office processing, as well as various opinions among specialists on the problems of interpretation of hydrodynamic studies of wells. The special literature on oilfield geology and hydrodynamic studies contains numerous attempts by different researchers from various sides to overcome this (significant in the opinion of the authors of the article) drawback of using the above method, but so far there have been no noticeable positive "shifts" in this direction. Everything rests on the bulkiness and complexity of the proposed analytical solutions. Based on many years of research, the authors of the article give their vision of solving this problem. The proposed modified grapho-analytical method of calculation in low-flow non-permeation wells that penetrated reservoir rocks with oils with Newtonian properties makes it possible to estimate the reliable value of the productivity factor of the reservoirs (Kprod) in the conditions of the formation pressure deficit that exists everywhere in the fields of the West Siberian oil and gas basin (with stationary flat-radial filtration).
{"title":"TO THE QUESTION OF ACCURACY OF EVALUATION OF THE PRODUCTIVITY FACTOR OF LOW-PRODUCTION WELLS","authors":"N. Zakirov, V. Alexandrov, A. K. Yagafarov, V. Spasibov, Zh.S. Popova","doi":"10.17122/ngdelo-2023-2-6-16","DOIUrl":"https://doi.org/10.17122/ngdelo-2023-2-6-16","url":null,"abstract":"In the practice of any exploration or oil producing enterprise, the parameters of a productive or potentially promising geological target are estimated using a method of temporary tracking and recording of a change in level/pressure based on the classical principle of sequential change of stationary states. Its main drawback against the background of wide practical application is the incorrect determination of the reliable value of the productivity coefficient (Kprod) for complex reservoir rocks, especially those with strong texture heterogeneity, which in reality is not enough to draw up high-quality and most importantly real design technological documents for the integrated development of oil and gas fields. Hence the large degree of conventionality of the results obtained during office processing, as well as various opinions among specialists on the problems of interpretation of hydrodynamic studies of wells. The special literature on oilfield geology and hydrodynamic studies contains numerous attempts by different researchers from various sides to overcome this (significant in the opinion of the authors of the article) drawback of using the above method, but so far there have been no noticeable positive \"shifts\" in this direction. Everything rests on the bulkiness and complexity of the proposed analytical solutions. \u0000Based on many years of research, the authors of the article give their vision of solving this problem. The proposed modified grapho-analytical method of calculation in low-flow non-permeation wells that penetrated reservoir rocks with oils with Newtonian properties makes it possible to estimate the reliable value of the productivity factor of the reservoirs (Kprod) in the conditions of the formation pressure deficit that exists everywhere in the fields of the West Siberian oil and gas basin (with stationary flat-radial filtration).","PeriodicalId":9748,"journal":{"name":"Chemical and Petroleum Engineering","volume":"86 1","pages":""},"PeriodicalIF":0.3,"publicationDate":"2023-05-30","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"88931791","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 : 2023-05-30DOI: 10.17122/ngdelo-2023-2-44-55
B. Grigoryev, A.S. Buravtsov, D. Vernigora
A group of Valazhin formations, located in Russia’s Arctic region, makes up highly productive oil, gas and condensate fields, which generally do not require any flow stimulation technologies at the initial stages of their development. However, their development history has shown that the wells’ productivity index decreases over time. The reasons for the increase in the skin factor had remained disputable for a long time before they were finally identified while optimizing flow stimulation fluids. One should keep in mind the extreme reactivity of mud acid systems, which may cause a decrease in the productivity of the formations treated with them, unless sufficient study is done. The highly sensitive formations in these fields require careful attention to the study of acid systems, which should be done on core samples, since the formations have a heterogeneous lithological structure and reservoir properties. These formations also demonstrate significant facies variation, interlayering of different thickness and pinching-out. Seven productive formations are distinguished within the horizon, separated by shale layers up to 5–7 meters thick. This paper is devoted to the discovery of factors that reduce the filtration properties of the formation after acid treatments with various types of acid compositions and urges the oil and gas community to pay attention to the importance of full range of laboratory studies prior to acid system implementation. The paper describes methods for preventing the precipitation of insoluble chemical compounds and preventing the occurrence of migration of fines and suspended particles after acid treatments. The optimal acid composition was selected for treating the near-wellbore formation zone based on laboratory experiments. And two treatments were performed in oil wells with increase in productivity index in 3 times and above.
{"title":"INHIBITION OF PARTICLE MIGRATION: A KEY FACTOR IN INTENSIFYING INFLOW FROM THE VALANGINO RESERVOIRS","authors":"B. Grigoryev, A.S. Buravtsov, D. Vernigora","doi":"10.17122/ngdelo-2023-2-44-55","DOIUrl":"https://doi.org/10.17122/ngdelo-2023-2-44-55","url":null,"abstract":"A group of Valazhin formations, located in Russia’s Arctic region, makes up highly productive oil, gas and condensate fields, which generally do not require any flow stimulation technologies at the initial stages of their development. However, their development history has shown that the wells’ productivity index decreases over time. The reasons for the increase in the skin factor had remained disputable for a long time before they were finally identified while optimizing flow stimulation fluids. One should keep in mind the extreme reactivity of mud acid systems, which may cause a decrease in the productivity of the formations treated with them, unless sufficient study is done. The highly sensitive formations in these fields require careful attention to the study of acid systems, which should be done on core samples, since the formations have a heterogeneous lithological structure and reservoir properties. These formations also demonstrate significant facies variation, interlayering of different thickness and pinching-out. Seven productive formations are distinguished within the horizon, separated by shale layers up to 5–7 meters thick. This paper is devoted to the discovery of factors that reduce the filtration properties of the formation after acid treatments with various types of acid compositions and urges the oil and gas community to pay attention to the importance of full range of laboratory studies prior to acid system implementation. The paper describes methods for preventing the precipitation of insoluble chemical compounds and preventing the occurrence of migration of fines and suspended particles after acid treatments. The optimal acid composition was selected for treating the near-wellbore formation zone based on laboratory experiments. And two treatments were performed in oil wells with increase in productivity index in 3 times and above.","PeriodicalId":9748,"journal":{"name":"Chemical and Petroleum Engineering","volume":"95 1","pages":""},"PeriodicalIF":0.3,"publicationDate":"2023-05-30","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"79456781","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 : 2023-05-30DOI: 10.17122/ngdelo-2023-2-76-85
Z. Ismagilova, D. Gulyaev, I. Valiullin, L. Zinurov, T.A. Khusnullina, V. Krichevskiy
Due to the large number of production and injection wells in the field, it is a difficult task to take into account the interconnection and mutual influence of all wells with each other. In this regard, it is advisable to use a proxy reservoir model, which allows to quickly calculate the main development indicators.These algorithms make it possible to predict the production characteristics of wells over the next years, as well as to optimally redistribute the volume of injected fluid between injection wells with minimal costs and high payback. The article calculated 8 cases in which the parameters of well operation control, well commissioning times, the nature of well operation and the change in production well modes on the forecast changed.
{"title":"STUDYING WAYS TO INCREASE THE RELIABILITY OF CRM-APPROACHES IN THE ANALYSIS OF THE HISTORY OF THE WELLS OF SYSTEMS BY INVOLVING ADDITIONAL INFORMATION","authors":"Z. Ismagilova, D. Gulyaev, I. Valiullin, L. Zinurov, T.A. Khusnullina, V. Krichevskiy","doi":"10.17122/ngdelo-2023-2-76-85","DOIUrl":"https://doi.org/10.17122/ngdelo-2023-2-76-85","url":null,"abstract":"Due to the large number of production and injection wells in the field, it is a difficult task to take into account the interconnection and mutual influence of all wells with each other. In this regard, it is advisable to use a proxy reservoir model, which allows to quickly calculate the main development indicators.These algorithms make it possible to predict the production characteristics of wells over the next years, as well as to optimally redistribute the volume of injected fluid between injection wells with minimal costs and high payback. The article calculated 8 cases in which the parameters of well operation control, well commissioning times, the nature of well operation and the change in production well modes on the forecast changed.","PeriodicalId":9748,"journal":{"name":"Chemical and Petroleum Engineering","volume":"19 1","pages":""},"PeriodicalIF":0.3,"publicationDate":"2023-05-30","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"73752982","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 : 2023-05-30DOI: 10.17122/ngdelo-2023-2-159-171
Y. Badin, M. Budaragin, A. N. Kiselev
The article provides a calculated justification for the occurrence of damage to process pipelines of delayed coking plants based on checking the strength conditions. Using the software package of finite element analysis ANSYS, based on estimates of temperature deformations of pipelines and coke drums, the calculation of the stress-strain state of pipeline elements is carried out. The results of computational studies indicate the types and locations of damage and show the possibility of preventing damage due to local strengthening of elements of pipelines with an increase in wall thickness. Based on the results obtained, reconstruction measures are proposed in order to prevent damage.
{"title":"CAUSES OF DAMAGE TO PROCESS PIPELINES OF DELAYED COKING UNITS AND MEASURES TO PREVENT THEM","authors":"Y. Badin, M. Budaragin, A. N. Kiselev","doi":"10.17122/ngdelo-2023-2-159-171","DOIUrl":"https://doi.org/10.17122/ngdelo-2023-2-159-171","url":null,"abstract":"The article provides a calculated justification for the occurrence of damage to process pipelines of delayed coking plants based on checking the strength conditions. Using the software package of finite element analysis ANSYS, based on estimates of temperature deformations of pipelines and coke drums, the calculation of the stress-strain state of pipeline elements is carried out. The results of computational studies indicate the types and locations of damage and show the possibility of preventing damage due to local strengthening of elements of pipelines with an increase in wall thickness. Based on the results obtained, reconstruction measures are proposed in order to prevent damage.","PeriodicalId":9748,"journal":{"name":"Chemical and Petroleum Engineering","volume":"57 2","pages":""},"PeriodicalIF":0.3,"publicationDate":"2023-05-30","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"72408968","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 : 2023-05-30DOI: 10.17122/ngdelo-2023-2-105-113
I. Ganiev, G. Z. Kalimullina, F. K. Mingalishev, R. Valeev, A. M. Belykh
Recovering residual oil reserves and reducing the level of water cut in produced wells at minimal cost are urgent tasks for mature fields. In such conditions, the use of tertiary methods of reservoir stimulation is relevant, among which a significant share is occupied by chemical methods of enhanced oil recovery. The principle of using flow diverting technologies is to supply small rims of chemical reagents to the reservoir through the reservoir pressure maintenance system, aimed at reducing the permeability of water-flushed zones by installing a waterinsulating barrier in them and redirecting water filtration flows to reservoir zones that were not previously covered by flooding. In this paper, we consider the possibility of using the technology of water-swellable preformed particle polymer systems as flow-diverting reagents to increase oil recovery from reservoirs with complicated geological and physical conditions that limit the use of many reagents used in EOR. On the example of a reagent sample, which is a pre-crosslinked acrylamide polymer, which contains particles of clay powder (up to 40% wt.), The paper shows the results of laboratory study and experience in applying the technology based on the preformed particle polymer systems at one of the objects of the Ural-Volga region, the reservoirs of which are presented carbonate rocks. The filtration experiment showed that the injection of the preformed particle polymer systems leads to a significant redistribution of fluid flows from a more highly permeable model to a less permeable one. As a result of the research, the main features of the applicability of technology based on the preformed particle polymer systems have been identified. The analysis of the conducted field work was carried out by determining the change in the injectivity profile of the treated injection wells and estimating the additionally produced oil from the reacting production wells. Based on the results of the analysis, additional laboratory studies were carried out, on the basis of which ways were proposed to increase the efficiency of injection well treatments with preformed particle polymer systems.
{"title":"EXPERIENCE IN USING PRE-CROSSLINKED POLYMER SYSTEMS FOR ENHANCED OIL RECOVERY IN CARBONATE RESERVOIRS","authors":"I. Ganiev, G. Z. Kalimullina, F. K. Mingalishev, R. Valeev, A. M. Belykh","doi":"10.17122/ngdelo-2023-2-105-113","DOIUrl":"https://doi.org/10.17122/ngdelo-2023-2-105-113","url":null,"abstract":"Recovering residual oil reserves and reducing the level of water cut in produced wells at minimal cost are urgent tasks for mature fields. In such conditions, the use of tertiary methods of reservoir stimulation is relevant, among which a significant share is occupied by chemical methods of enhanced oil recovery. The principle of using flow diverting technologies is to supply small rims of chemical reagents to the reservoir through the reservoir pressure maintenance system, aimed at reducing the permeability of water-flushed zones by installing a waterinsulating barrier in them and redirecting water filtration flows to reservoir zones that were not previously covered by flooding. \u0000In this paper, we consider the possibility of using the technology of water-swellable preformed particle polymer systems as flow-diverting reagents to increase oil recovery from reservoirs with complicated geological and physical conditions that limit the use of many reagents used in EOR. \u0000On the example of a reagent sample, which is a pre-crosslinked acrylamide polymer, which contains particles of clay powder (up to 40% wt.), The paper shows the results of laboratory study and experience in applying the technology based on the preformed particle polymer systems at one of the objects of the Ural-Volga region, the reservoirs of which are presented carbonate rocks. The filtration experiment showed that the injection of the preformed particle polymer systems leads to a significant redistribution of fluid flows from a more highly permeable model to a less permeable one. As a result of the research, the main features of the applicability of technology based on the preformed particle polymer systems have been identified. The analysis of the conducted field work was carried out by determining the change in the injectivity profile of the treated injection wells and estimating the additionally produced oil from the reacting production wells. Based on the results of the analysis, additional laboratory studies were carried out, on the basis of which ways were proposed to increase the efficiency of injection well treatments with preformed particle polymer systems.","PeriodicalId":9748,"journal":{"name":"Chemical and Petroleum Engineering","volume":"134 1","pages":""},"PeriodicalIF":0.3,"publicationDate":"2023-05-30","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"82709337","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}
京公网安备 11010802042870号
京ICP备2023020795号-1
扫码关注我们
求助内容：
应助结果提醒方式：