The article describes the main features of the geological structure of the Jurassic-Cretaceous productive strata of the Karazhanbas field, located on the Buzachi Peninsula (Western Kazakhstan), and the effectiveness of thermal methods and their modifications to enhance oil recovery, which have been used in the field since the 80s of the last century. The use of thermal steam stimulation in the form of thermal slugs allows not only to cover most of the formation with thermal steam stimulation by switching to unheated water injection in a number of wells and transferring steam injection to other wells, but also to intensify the movement of the thermal slug in the formation during the cold water injection process. As a result, the steam-oil ratio when using thermal rims and increasing the steam injection rate can be several times less than with continuous slow steam injection. The use of thermal steam treatment allows increasing oil recovery by 3545% of the initial balance oil reserves. Testing and implementation of new equipment and technology, as well as the study of world experience in the development of high-viscosity oil are currently relevant for the development of the Karazhanbas field.
{"title":"Analysis of the steam-thermal treatment at the Karazhanbas field","authors":"A. S. Kozhash","doi":"10.54859/kjogi99698","DOIUrl":"https://doi.org/10.54859/kjogi99698","url":null,"abstract":"The article describes the main features of the geological structure of the Jurassic-Cretaceous productive strata of the Karazhanbas field, located on the Buzachi Peninsula (Western Kazakhstan), and the effectiveness of thermal methods and their modifications to enhance oil recovery, which have been used in the field since the 80s of the last century. The use of thermal steam stimulation in the form of thermal slugs allows not only to cover most of the formation with thermal steam stimulation by switching to unheated water injection in a number of wells and transferring steam injection to other wells, but also to intensify the movement of the thermal slug in the formation during the cold water injection process. As a result, the steam-oil ratio when using thermal rims and increasing the steam injection rate can be several times less than with continuous slow steam injection. The use of thermal steam treatment allows increasing oil recovery by 3545% of the initial balance oil reserves. Testing and implementation of new equipment and technology, as well as the study of world experience in the development of high-viscosity oil are currently relevant for the development of the Karazhanbas field.","PeriodicalId":17771,"journal":{"name":"Kazakhstan journal for oil & gas industry","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2021-12-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"81072402","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}
D. M. Zhexembin, B. Kurmetbek, A. M. Serikbaeva, B. Bekbauov
This work is devoted to the development of a user interface for a hydrodynamic simulator to control data entry and ease of launching calculations using the Qt cross-platform integrated development environment, as well as a tool for visualizing and post-processing the results of a hydrodynamic simulator for modeling oil production processes. The article presents the work on building a unified architecture of a hydrodynamic simulator project in the GitHub system with details of processing processes, names of branches and commits. Also added a license to the GitHub project for further use of the project in the form of open source software.
{"title":"Development of a user interface and a post-processing tool for a hydrodynamic simulator for modeling oil production processes","authors":"D. M. Zhexembin, B. Kurmetbek, A. M. Serikbaeva, B. Bekbauov","doi":"10.54859/kjogi99693","DOIUrl":"https://doi.org/10.54859/kjogi99693","url":null,"abstract":"This work is devoted to the development of a user interface for a hydrodynamic simulator to control data entry and ease of launching calculations using the Qt cross-platform integrated development environment, as well as a tool for visualizing and post-processing the results of a hydrodynamic simulator for modeling oil production processes. The article presents the work on building a unified architecture of a hydrodynamic simulator project in the GitHub system with details of processing processes, names of branches and commits. Also added a license to the GitHub project for further use of the project in the form of open source software.","PeriodicalId":17771,"journal":{"name":"Kazakhstan journal for oil & gas industry","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2021-12-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"81833330","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}
The Pre-Caspian Basin is the major oil and gas basin in Kazakhstan. It contains huge hydrocarbon reserves within pre-salt carbonate deposits. There had been numerous discoveries of oil and gas-condensate fields associated with pre-salt carbonate complexes in the Eastern part of the Caspian Basin. The object of this study is the second carbonate stratum (CS-II) of the Late Visean Early Moskovian age of the Eastern part of the Pre-Caspian Basin. The formation of the Eastern part of the Pre-Caspian Basin took place in the zone of the junction of the East European craton and folded structures of the Urals. These conditions predetermined the complexity of sedimentation processes, variety of lithological types of rocks and diagenesis processes with the formation of reservoir heterogeneity. CS-II will retain the leading role as the main reservoir of hydrocarbons and it has further potential for oil exploration in the region for two to three decades. It has been proven by the discovery of large oil and gas-condensate fields in the CS-II, such as Zhanazhol, Urikhtau, Kozhasai, Alibekmola, etc.
前里海盆地是哈萨克斯坦主要的油气盆地。在盐下碳酸盐岩矿床中蕴藏着巨大的油气储量。在里海盆地东部，已经发现了许多与盐下碳酸盐岩复合体相关的油气凝析油田。研究对象为前里海盆地东部晚Visean - Early moscow时代第二碳酸盐岩地层(CS-II)。前里海盆地东部形成于东欧克拉通与乌拉尔褶皱构造交接处。这些条件决定了沉积过程的复杂性、岩石岩性类型的多样性和成岩作用过程与储层非均质性的形成。CS-II将继续作为主要的油气储层发挥主导作用，并在未来20至30年内具有进一步的石油勘探潜力。在CS-II地区发现了大型油气凝析油田，如Zhanazhol、Urikhtau、Kozhasai、Alibekmola等，证明了这一点。
{"title":"Lithological and facial features of organogenic structures of the second carbonate stratum of the eastern flang of the Pre-Caspian depression on Zharkamys uplift","authors":"A. Kan, L. Akhmetshina","doi":"10.54859/kjogi99678","DOIUrl":"https://doi.org/10.54859/kjogi99678","url":null,"abstract":"The Pre-Caspian Basin is the major oil and gas basin in Kazakhstan. It contains huge hydrocarbon reserves within pre-salt carbonate deposits. There had been numerous discoveries of oil and gas-condensate fields associated with pre-salt carbonate complexes in the Eastern part of the Caspian Basin. \u0000The object of this study is the second carbonate stratum (CS-II) of the Late Visean Early Moskovian age of the Eastern part of the Pre-Caspian Basin. The formation of the Eastern part of the Pre-Caspian Basin took place in the zone of the junction of the East European craton and folded structures of the Urals. These conditions predetermined the complexity of sedimentation processes, variety of lithological types of rocks and diagenesis processes with the formation of reservoir heterogeneity. \u0000CS-II will retain the leading role as the main reservoir of hydrocarbons and it has further potential for oil exploration in the region for two to three decades. It has been proven by the discovery of large oil and gas-condensate fields in the CS-II, such as Zhanazhol, Urikhtau, Kozhasai, Alibekmola, etc.","PeriodicalId":17771,"journal":{"name":"Kazakhstan journal for oil & gas industry","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2021-12-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"85492663","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}
B. Imanbayev, N. S. Zhaparov, D. M. Maksut, M. Utepov
In order to study and control microbiological contamination with sulfate-reducing bacteria of oilfield fluids we have monitored the performance of bactericidal reagents at the Uzen field. Water samples were taken at the equipped control points for the content of SRB cells before and after the injection of the bactericide. Due to the increase in the content of hydrogen sulfide in November December 2020 at the fields of Ozenmunaygas JSC, a technical inspection of the NSM-4 facility and the reagent injection unit was carried out by KazNIPImunaygas together with specialists from the structural divisions of the Department for Oil Treatment and Production Services of OMG and the Office on chemistry and OMG. Further, KazNIPI performed laboratory tests to determine the miscibility of the bactericide with seawater at different temperatures. Based on the results of the studies performed, following recommendations were developed: seawater tank biocide treatment recommendation, biocide injection system and injection point improvement in order to ensure proper mixing of the biocide with seawater. We also recommended to perform field trial of new biocides in order to avoid the development of bactericide resistance in the bacteria.
{"title":"Methods of combating biogenic hydrogen sulfur at the Uzen and Karamandibas oilfield","authors":"B. Imanbayev, N. S. Zhaparov, D. M. Maksut, M. Utepov","doi":"10.54859/kjogi99709","DOIUrl":"https://doi.org/10.54859/kjogi99709","url":null,"abstract":"In order to study and control microbiological contamination with sulfate-reducing bacteria of oilfield fluids we have monitored the performance of bactericidal reagents at the Uzen field. \u0000Water samples were taken at the equipped control points for the content of SRB cells before and after the injection of the bactericide. \u0000Due to the increase in the content of hydrogen sulfide in November December 2020 at the fields of Ozenmunaygas JSC, a technical inspection of the NSM-4 facility and the reagent injection unit was carried out by KazNIPImunaygas together with specialists from the structural divisions of the Department for Oil Treatment and Production Services of OMG and the Office on chemistry and OMG. Further, KazNIPI performed laboratory tests to determine the miscibility of the bactericide with seawater at different temperatures. \u0000Based on the results of the studies performed, following recommendations were developed: seawater tank biocide treatment recommendation, biocide injection system and injection point improvement in order to ensure proper mixing of the biocide with seawater. We also recommended to perform field trial of new biocides in order to avoid the development of bactericide resistance in the bacteria.","PeriodicalId":17771,"journal":{"name":"Kazakhstan journal for oil & gas industry","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2021-12-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"82990088","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}
The problem associated with low-resistance reservoirs in the fields of Western Siberia has been relevant since the end of the last century. According to the materials of geophysical well surveys (GIS), productive low-resistance reservoirs are often interpreted as water-saturated, as a result of which they are not used in the further operation of the well. The aim of the research is to illustrate the use of such parameters as statistical intensities of secondary changes in rocks (superimposed-epigenetic processes) as indicators of oil and gas saturation of low-resistance sand reservoirs at the unique field of the Surgut arch. The analysis is based on the method of statistical interpretation of the data of geophysical studies of wells developed by I. A. Melnik, who has achieved great success in studying this problem. Comparison of the results of these calculations with the results of processing the seismic data of the surface of the reflecting horizons confirmed the effectiveness of the proposed algorithm. The dependence of the intensity of secondary pyritization on tectonic disturbances and the distance to them was also determined. Recommendations for testing new intervals are given.
{"title":"Justification and prerequisites for the allocation of low-resistance reservoirs as a tool for searching for missed deposits on the example of the Surgut arch field","authors":"I. A. Nikitin","doi":"10.54859/kjogi99683","DOIUrl":"https://doi.org/10.54859/kjogi99683","url":null,"abstract":"The problem associated with low-resistance reservoirs in the fields of Western Siberia has been relevant since the end of the last century. According to the materials of geophysical well surveys (GIS), productive low-resistance reservoirs are often interpreted as water-saturated, as a result of which they are not used in the further operation of the well. The aim of the research is to illustrate the use of such parameters as statistical intensities of secondary changes in rocks (superimposed-epigenetic processes) as indicators of oil and gas saturation of low-resistance sand reservoirs at the unique field of the Surgut arch. The analysis is based on the method of statistical interpretation of the data of geophysical studies of wells developed by I. A. Melnik, who has achieved great success in studying this problem. Comparison of the results of these calculations with the results of processing the seismic data of the surface of the reflecting horizons confirmed the effectiveness of the proposed algorithm. The dependence of the intensity of secondary pyritization on tectonic disturbances and the distance to them was also determined. Recommendations for testing new intervals are given.","PeriodicalId":17771,"journal":{"name":"Kazakhstan journal for oil & gas industry","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2021-12-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"86007798","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}
Y. Seitkhaziyev, R. Uteyev, M. K. Mustafaev, Sh. Liu, N. Sarsenbekov, A. K. Dosmukhambetov
This article presents the results of fingerprinting of 128 oil samples derived from all production wells of three Akshabulak group fields to determine the types of oils. Based on the results of this analysis, four groups of oils were identified: The first group includes oils (red) of the lower hydrocarbon pay zones (III-IV-V) in Akshabulak Central, the upper zones of the I southern dome of Akshabulak Central and all pay zones of the northern dome at Akshabulak South. The second group of oils (green) was identified in the wells exploiting pay zone I in the northern dome of Akshabulak Central, while oils (blue) in the productive horizons of Akshabulak East and paleochannel sediments of Akshabulak Central form the third group. The fourth group includes one oil sample with different genesis from well № 37, which penetrates paleo-channel № 13 at South Akshabulak. Biomarker analysis was carried out for 39 oil samples, according to which the oils were formed in terrigenous (clayey) organic matter, deposited in lacustrine environment. In terms of thermal parameters, the oils of the Eastern Akshabulak are less mature than the oils of the Central Akshabulak and the South Akshabulak, despite their relative deeper depths. Based on the work performed, the conclusion presents the prospective hydrocarbon accumulation zones suitable for increasing hydrocarbon resources and reserves in the future. However it should be noted that the results of the studies performed provide valuable information only when integrated with the corresponding geological and seismic data.
{"title":"Fingerprinting and biomarker analysis of oil from Akshabulak group for determining oil types","authors":"Y. Seitkhaziyev, R. Uteyev, M. K. Mustafaev, Sh. Liu, N. Sarsenbekov, A. K. Dosmukhambetov","doi":"10.54859/kjogi99712","DOIUrl":"https://doi.org/10.54859/kjogi99712","url":null,"abstract":"This article presents the results of fingerprinting of 128 oil samples derived from all production wells of three Akshabulak group fields to determine the types of oils. Based on the results of this analysis, four groups of oils were identified: The first group includes oils (red) of the lower hydrocarbon pay zones (III-IV-V) in Akshabulak Central, the upper zones of the I southern dome of Akshabulak Central and all pay zones of the northern dome at Akshabulak South. The second group of oils (green) was identified in the wells exploiting pay zone I in the northern dome of Akshabulak Central, while oils (blue) in the productive horizons of Akshabulak East and paleochannel sediments of Akshabulak Central form the third group. The fourth group includes one oil sample with different genesis from well № 37, which penetrates paleo-channel № 13 at South Akshabulak. \u0000Biomarker analysis was carried out for 39 oil samples, according to which the oils were formed in terrigenous (clayey) organic matter, deposited in lacustrine environment. In terms of thermal parameters, the oils of the Eastern Akshabulak are less mature than the oils of the Central Akshabulak and the South Akshabulak, despite their relative deeper depths. Based on the work performed, the conclusion presents the prospective hydrocarbon accumulation zones suitable for increasing hydrocarbon resources and reserves in the future. However it should be noted that the results of the studies performed provide valuable information only when integrated with the corresponding geological and seismic data.","PeriodicalId":17771,"journal":{"name":"Kazakhstan journal for oil & gas industry","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2021-12-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"89097890","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}
Development of modern inversion transformations in seismic data interpretation area is associated with strive of getting full insight on structure of the explored and developed accumulations using simple, fast and efficient methods. Nature of current seismic inversion methods is variable; therefore, choice of inversion technology conditioned by target that needs to be achieved, as well as, reservoir parameters, amount and quality of data. Of course, time limits set to find optimal solution must be taken into account, since they are guided by industry needs. In the present paper, we reviewed implementation of the stochastic inversion method based on pseudo-wells that are estimated for a trace of extended elastic inversion (EEI) for purpose to find best-fitting solution for a given trace based on an example for an oil field located within South Torgay sedimentary basin. This method could be interesting for mapping of specified litho-types, clarification of the geological model, precise placement of the appraisal well drilling locations etc. Method and productivity were evaluated based on time and existing computing power.
{"title":"Implementation of stochastic inversion method using pseudo-wells based on an example from oil field located in South Torgay sedimentary basin","authors":"A. Sadykov","doi":"10.54859/kjogi99689","DOIUrl":"https://doi.org/10.54859/kjogi99689","url":null,"abstract":"Development of modern inversion transformations in seismic data interpretation area is associated with strive of getting full insight on structure of the explored and developed accumulations using simple, fast and efficient methods. Nature of current seismic inversion methods is variable; therefore, choice of inversion technology conditioned by target that needs to be achieved, as well as, reservoir parameters, amount and quality of data. Of course, time limits set to find optimal solution must be taken into account, since they are guided by industry needs. \u0000In the present paper, we reviewed implementation of the stochastic inversion method based on pseudo-wells that are estimated for a trace of extended elastic inversion (EEI) for purpose to find best-fitting solution for a given trace based on an example for an oil field located within South Torgay sedimentary basin. This method could be interesting for mapping of specified litho-types, clarification of the geological model, precise placement of the appraisal well drilling locations etc. \u0000Method and productivity were evaluated based on time and existing computing power.","PeriodicalId":17771,"journal":{"name":"Kazakhstan journal for oil & gas industry","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2021-12-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"84794710","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}
V. Shishkin, A. Zholdybayeva, V. Z. Khazhitov, A. B. Niyazbayeva, D. A. Sidorov, A. Kurmankulov
High-viscosity oils classified as hard-to-recover oil reserves, where they differ from traditional oils with increased viscosity in reservoir conditions. There is about 0.7 billion tons of high-viscosity oils in Kazakhstan. Development of fields with high-viscosity oils is an urgent task for oil and gas engineers not only in Kazakhstan but also all over the world. This article is concerned with estimation of the efficiency of known in the oil and gas industry technologies aimed at intensifying production and increasing oil recovery in fields with hard-to-recover reserves. One of the types of such technologies is thermal recovery. This paper presents cyclic steam simulation. Estimation of the efficiency of the cyclic steam simulation based on the hydrodynamic model of the East Moldabek deposit of Kenbai filed. As a result of modeling, the current state of field development has been analyzed, reservoir simulation model has been history matched and different production forecast estimations have been made.
{"title":"Estimation of the efficiency of the cyclic steam simulation with high viscosity oil wells based on the hydrodynamic model of the East Moldabek deposit, Kenbai field","authors":"V. Shishkin, A. Zholdybayeva, V. Z. Khazhitov, A. B. Niyazbayeva, D. A. Sidorov, A. Kurmankulov","doi":"10.54859/kjogi99704","DOIUrl":"https://doi.org/10.54859/kjogi99704","url":null,"abstract":"High-viscosity oils classified as hard-to-recover oil reserves, where they differ from traditional oils with increased viscosity in reservoir conditions. There is about 0.7 billion tons of high-viscosity oils in Kazakhstan. Development of fields with high-viscosity oils is an urgent task for oil and gas engineers not only in Kazakhstan but also all over the world. This article is concerned with estimation of the efficiency of known in the oil and gas industry technologies aimed at intensifying production and increasing oil recovery in fields with hard-to-recover reserves. One of the types of such technologies is thermal recovery. This paper presents cyclic steam simulation. Estimation of the efficiency of the cyclic steam simulation based on the hydrodynamic model of the East Moldabek deposit of Kenbai filed. \u0000As a result of modeling, the current state of field development has been analyzed, reservoir simulation model has been history matched and different production forecast estimations have been made.","PeriodicalId":17771,"journal":{"name":"Kazakhstan journal for oil & gas industry","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2021-12-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"75656366","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}
The success of a development strategy for any field depends on the degree of knowledge of the geological structure of its main reservoirs. As the area is drilled out, the concept of the structure of the hydrocarbon accumulation is refined, but in the case of a complex structure of the void space of the reservoirs and the lithological heterogeneity of the section over the area, geological uncertainties and risks during the subsequent placement of wells remain high. For these reasons, one of the main problems in hydrocarbon production is predicting rock types and the distribution of fluids throughout the reservoir away from wells, since the determination of rock properties is a major source of uncertainty in reservoir modeling studies [1, 2]. The proposed project will demonstrate algorithms based on machine learning methods that allow predicting the distribution of lithology and the uncertainty of lithofacies variability in the section.
{"title":"Lithofacial analysis and possibilities for prediction of properties on geophysical research and seismic exploration data by methods of machine learning","authors":"E. Kolbikova","doi":"10.54859/kjogi99690","DOIUrl":"https://doi.org/10.54859/kjogi99690","url":null,"abstract":"The success of a development strategy for any field depends on the degree of knowledge of the geological structure of its main reservoirs. As the area is drilled out, the concept of the structure of the hydrocarbon accumulation is refined, but in the case of a complex structure of the void space of the reservoirs and the lithological heterogeneity of the section over the area, geological uncertainties and risks during the subsequent placement of wells remain high. For these reasons, one of the main problems in hydrocarbon production is predicting rock types and the distribution of fluids throughout the reservoir away from wells, since the determination of rock properties is a major source of uncertainty in reservoir modeling studies [1, 2]. The proposed project will demonstrate algorithms based on machine learning methods that allow predicting the distribution of lithology and the uncertainty of lithofacies variability in the section.","PeriodicalId":17771,"journal":{"name":"Kazakhstan journal for oil & gas industry","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2021-12-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"83569418","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}
Oils with anomalous properties are characterized by large values of density, viscosity, high content of paraffinic hydrocarbons and asphaltene-resinous substances (up to 30%), high pour point (3538C), which increases the likelihood of complications in the processes of production, field gathering and oil treatment. Therefore, for many countries with cold climatic conditions, the problem of improving the low-temperature properties of oils is one of the most pressing problems in the production and transportation of hard-to-recover oils. Recent studies show that the rates of heating / cooling processes have a great influence on the rheological properties of natural oil mixtures during heat treatment. The experience of operating oil fields shows that in oil gathering and transportation systems, due to the water cut of oils and the aggressiveness of formation waters, persistent oil emulsions are often formed, which complicate the commercial preparation of oils. The article presents the results of studies of the influence of the water cut factor on the transportation of well products, as well as the effect of the cooling rate on the pour point of oil emulsions. Laboratory studies have shown that an increase in the water content in emulsions of more than 40% leads to a significant increase in viscosity over the entire temperature range. It is also shown that an increase in water cut increases the pour point of oil by 7-14С.
{"title":"Influence of water cut and rates of cooling on oil flow","authors":"F. Ismayilova","doi":"10.54859/kjogi99714","DOIUrl":"https://doi.org/10.54859/kjogi99714","url":null,"abstract":"Oils with anomalous properties are characterized by large values of density, viscosity, high content of paraffinic hydrocarbons and asphaltene-resinous substances (up to 30%), high pour point (3538C), which increases the likelihood of complications in the processes of production, field gathering and oil treatment. Therefore, for many countries with cold climatic conditions, the problem of improving the low-temperature properties of oils is one of the most pressing problems in the production and transportation of hard-to-recover oils. Recent studies show that the rates of heating / cooling processes have a great influence on the rheological properties of natural oil mixtures during heat treatment. The experience of operating oil fields shows that in oil gathering and transportation systems, due to the water cut of oils and the aggressiveness of formation waters, persistent oil emulsions are often formed, which complicate the commercial preparation of oils. \u0000The article presents the results of studies of the influence of the water cut factor on the transportation of well products, as well as the effect of the cooling rate on the pour point of oil emulsions. Laboratory studies have shown that an increase in the water content in emulsions of more than 40% leads to a significant increase in viscosity over the entire temperature range. It is also shown that an increase in water cut increases the pour point of oil by 7-14С.","PeriodicalId":17771,"journal":{"name":"Kazakhstan journal for oil & gas industry","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2021-12-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"88524583","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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