This article presents the laboratory development of a novel rigless, self-selective water shut-off technique. The technique involves the design and pumping of three different fluids through fractured core plugs in a specific sequence. The first fluid serves to temporarily block porous medium while moving freely through fractures. The second fluid is a cross-linking polymer gelant, which is injected immediately after the first fluid at a pressure below the fracture pressure of the formation to block fractures. An enzyme-based chemical breaker solution, serving as the third fluid, is evaluated for removing the filter-forming materials. The treatment and flow studies are conducted using a high-pressure, high-temperature core flow setup. In conclusion, the developed water control technology presented in this study offers a low-cost solution for fractured and high-anomaly wells. The technology is particularly effective when there is a significant permeability contrast between the oil-bearing matrix and water-conductive fractures. The results demonstrate a successful blockage of fracture, with minimal contamination of porous medium. The study also highlights important factors to consider for the field application of this technology. It is recommended to conduct customized laboratory investigations under simulated reservoir conditions prior to implementing the technology in the field. This will help optimize the treatment design and ensure its effectiveness in real-world applications. Keywords: water shut-off; temporary blocking agent; gel composition; coreflood; permeability contrast.
{"title":"Novel water shut off method based on temporary plugging agent and gel composition","authors":"Elchin F. Veliyev, A. D. Shovgenov","doi":"10.5510/ogp2023si100837","DOIUrl":"https://doi.org/10.5510/ogp2023si100837","url":null,"abstract":"This article presents the laboratory development of a novel rigless, self-selective water shut-off technique. The technique involves the design and pumping of three different fluids through fractured core plugs in a specific sequence. The first fluid serves to temporarily block porous medium while moving freely through fractures. The second fluid is a cross-linking polymer gelant, which is injected immediately after the first fluid at a pressure below the fracture pressure of the formation to block fractures. An enzyme-based chemical breaker solution, serving as the third fluid, is evaluated for removing the filter-forming materials. The treatment and flow studies are conducted using a high-pressure, high-temperature core flow setup. In conclusion, the developed water control technology presented in this study offers a low-cost solution for fractured and high-anomaly wells. The technology is particularly effective when there is a significant permeability contrast between the oil-bearing matrix and water-conductive fractures. The results demonstrate a successful blockage of fracture, with minimal contamination of porous medium. The study also highlights important factors to consider for the field application of this technology. It is recommended to conduct customized laboratory investigations under simulated reservoir conditions prior to implementing the technology in the field. This will help optimize the treatment design and ensure its effectiveness in real-world applications. Keywords: water shut-off; temporary blocking agent; gel composition; coreflood; permeability contrast.","PeriodicalId":43516,"journal":{"name":"SOCAR Proceedings","volume":null,"pages":null},"PeriodicalIF":1.7,"publicationDate":"2023-06-30","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"139366608","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 paper considers one of the ways to determine the optimal arrangement of production and injection horizontal wells in the Vereisky horizon, which formations are composed of interbedded carbonate and terrigenous rocks. The geological and production analysis of the drilled wells was carried out. Multistage hydraulic fracturing was used to increase the proportion of reserves involved in development. When drilling horizontal wells, using hydraulic fracturing, it is possible not only to increase the drainage zone of the target reservoir, but also to involve the above- and below-lying layers in the development. The performed analysis confirmed the high efficiency of horizontal wells with multistage fracturing. Various variants of arrangement of production and injection horizontal wells were designed and modeled using the geological and hydrodynamic model of one of the object’s sections. Based on the performed analysis and calculations, the most effective schemes of well arrangements were selected. Keywords: carbonate rocks; horizontal well; forecast; modeling; multistage fracturing; injection; pressure maintenance system.
{"title":"Designing horizontal wells in carbonate reservoirs using geological and hydrodynamic modeling tools","authors":"R. Bakhtizin, R. Nurgaliev","doi":"10.5510/ogp2023si100829","DOIUrl":"https://doi.org/10.5510/ogp2023si100829","url":null,"abstract":"The paper considers one of the ways to determine the optimal arrangement of production and injection horizontal wells in the Vereisky horizon, which formations are composed of interbedded carbonate and terrigenous rocks. The geological and production analysis of the drilled wells was carried out. Multistage hydraulic fracturing was used to increase the proportion of reserves involved in development. When drilling horizontal wells, using hydraulic fracturing, it is possible not only to increase the drainage zone of the target reservoir, but also to involve the above- and below-lying layers in the development. The performed analysis confirmed the high efficiency of horizontal wells with multistage fracturing. Various variants of arrangement of production and injection horizontal wells were designed and modeled using the geological and hydrodynamic model of one of the object’s sections. Based on the performed analysis and calculations, the most effective schemes of well arrangements were selected. Keywords: carbonate rocks; horizontal well; forecast; modeling; multistage fracturing; injection; pressure maintenance system.","PeriodicalId":43516,"journal":{"name":"SOCAR Proceedings","volume":null,"pages":null},"PeriodicalIF":1.7,"publicationDate":"2023-06-30","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"139367003","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 current conditions of well operation with electric submersible pumps are characterized by the need for gas separation at the pump intake, and natural separation can be insufficient to provide the technological rate of well, so gas separators are used as part of the electric submersible pump unit. The literature review and the results of our research demonstrate that currently there is no unified methodology for selecting gas separators of various designs for the operating well conditions, equipped with ESP units of different series. That is, the selection of a gas separator as part of ESP unit is based on partial data on performance and design of the gas separator, which is unacceptable, and in some cases dangerous due to the possible failure mode. The paper describes a methodology to predict the efficiency of a gas separator as part of a downhole electric submersible pump unit based on the summary of a significant set of statistical information from publications, results of our own experimental and field studies. Keywords: gas separator; gas content; electric submersible pump unit; ESP; separation efficiency; well oil production; separation coefficient.
{"title":"The approach to determine the gas separator efficiency as a part of an electric submersible pump unit","authors":"K. Goridko, V. Verbitsky, O. Kobzar","doi":"10.5510/ogp2023si100831","DOIUrl":"https://doi.org/10.5510/ogp2023si100831","url":null,"abstract":"The current conditions of well operation with electric submersible pumps are characterized by the need for gas separation at the pump intake, and natural separation can be insufficient to provide the technological rate of well, so gas separators are used as part of the electric submersible pump unit. The literature review and the results of our research demonstrate that currently there is no unified methodology for selecting gas separators of various designs for the operating well conditions, equipped with ESP units of different series. That is, the selection of a gas separator as part of ESP unit is based on partial data on performance and design of the gas separator, which is unacceptable, and in some cases dangerous due to the possible failure mode. The paper describes a methodology to predict the efficiency of a gas separator as part of a downhole electric submersible pump unit based on the summary of a significant set of statistical information from publications, results of our own experimental and field studies. Keywords: gas separator; gas content; electric submersible pump unit; ESP; separation efficiency; well oil production; separation coefficient.","PeriodicalId":43516,"journal":{"name":"SOCAR Proceedings","volume":null,"pages":null},"PeriodicalIF":1.7,"publicationDate":"2023-06-30","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"139367151","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}
E. M. Suleymanov, S. H. Novruzova, I. N. Aliyev, Y. Y. Şmonçeva
Currently, almost all researchers believe that turbulent flow is the most preferred displacement mode. However, when it comes to cementing, where practical limitations prevent obtaining turbulent flow, opinions begin to differ. In general, either «very slow» flow or «very fast» flow is recommended for all wells in the annulus. There are mainly two types of buffer liquids used – «wash» and «space». The first buffer liquid is «wash», which washes away and removes the remnants of drilling fluid, clay cake, etc., and the second is «space», a thicker system, entering the cavities, cleans them and also pulls out all the remnants of the first buffer liquid to the surface. The first buffer fluid is «wash», basically a thinner, of the drilling fluid, which may contain surfactants - surfactants or liquid-restraining agents, the preferred mode of motion is turbulent. The second buffer liquid – «space», can mainly contain polymeric materials, weighting agents, the preferred mode of movement is laminar (cork). The choice of these fluids is determined by their chemical compatibility with drilling and cement slurries, their effectiveness in removing the drilling fluid. Very important postulates adopted by almost all leading oil firms are given. A new and very affordable composition of the buffer liquid of the following composition has been proposed: «wash» - FLS - 4%, diesel fuel - 2%, the rest is water - 9%; «space» - carboxymethylcellulose (CMC) - 0.5%, bentonite solution with a density of 1030 kg/m3 - 99.5%. If necessary, these buffer fluids can be weighted, for example, with barite, to an average density between the densities of drilling and cement slurries in a given well.. Keywords: buffer fluid; drilling fluid; cement mortar;turbulent flow; mode of motion; mud cake; centralizer; casing string.
{"title":"Enhancing of spacer fluids compositions for well cementing","authors":"E. M. Suleymanov, S. H. Novruzova, I. N. Aliyev, Y. Y. Şmonçeva","doi":"10.5510/ogp2023si100860","DOIUrl":"https://doi.org/10.5510/ogp2023si100860","url":null,"abstract":"Currently, almost all researchers believe that turbulent flow is the most preferred displacement mode. However, when it comes to cementing, where practical limitations prevent obtaining turbulent flow, opinions begin to differ. In general, either «very slow» flow or «very fast» flow is recommended for all wells in the annulus. There are mainly two types of buffer liquids used – «wash» and «space». The first buffer liquid is «wash», which washes away and removes the remnants of drilling fluid, clay cake, etc., and the second is «space», a thicker system, entering the cavities, cleans them and also pulls out all the remnants of the first buffer liquid to the surface. The first buffer fluid is «wash», basically a thinner, of the drilling fluid, which may contain surfactants - surfactants or liquid-restraining agents, the preferred mode of motion is turbulent. The second buffer liquid – «space», can mainly contain polymeric materials, weighting agents, the preferred mode of movement is laminar (cork). The choice of these fluids is determined by their chemical compatibility with drilling and cement slurries, their effectiveness in removing the drilling fluid. Very important postulates adopted by almost all leading oil firms are given. A new and very affordable composition of the buffer liquid of the following composition has been proposed: «wash» - FLS - 4%, diesel fuel - 2%, the rest is water - 9%; «space» - carboxymethylcellulose (CMC) - 0.5%, bentonite solution with a density of 1030 kg/m3 - 99.5%. If necessary, these buffer fluids can be weighted, for example, with barite, to an average density between the densities of drilling and cement slurries in a given well.. Keywords: buffer fluid; drilling fluid; cement mortar;turbulent flow; mode of motion; mud cake; centralizer; casing string.","PeriodicalId":43516,"journal":{"name":"SOCAR Proceedings","volume":null,"pages":null},"PeriodicalIF":1.7,"publicationDate":"2023-06-30","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"139367334","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 article studies the economic effect of foreign direct investment in the oil and gas sector of Azerbaijan. As a study result it was determined that it is most appropriate to direct foreign investments to the sectors capable of creating high added value. Since these investments are mainly oriented to industrial production and processing sector, there are wide export opportunities here. For the economic development of the oil and gas industry, it is advisable to increase the qualitative component of foreign direct investment. In general, the directions of foreign direct investment in the oil and gas sector correspond to the interests of the Republic of Azerbaijan, which means that it is necessary to increase the efficiency of foreign direct investment. This is possible due to optimization of strategic and operational business processes at the level of investor companies. Thus, as a result of the study, it can be said that the inflow of foreign direct investment in the oil and gas sector has had a positive impact on economic growth in the country as a whole. Keywords: oil and gas sector; foreign investment; foreign direct investment; investment environment assessment; economic development.
{"title":"Economic effect of foreign direct investment in the oil and gas sector of Azerbaijan","authors":"E. A. Guseynov, A. A. Tagiyev","doi":"10.5510/ogp2023si100862","DOIUrl":"https://doi.org/10.5510/ogp2023si100862","url":null,"abstract":"The article studies the economic effect of foreign direct investment in the oil and gas sector of Azerbaijan. As a study result it was determined that it is most appropriate to direct foreign investments to the sectors capable of creating high added value. Since these investments are mainly oriented to industrial production and processing sector, there are wide export opportunities here. For the economic development of the oil and gas industry, it is advisable to increase the qualitative component of foreign direct investment. In general, the directions of foreign direct investment in the oil and gas sector correspond to the interests of the Republic of Azerbaijan, which means that it is necessary to increase the efficiency of foreign direct investment. This is possible due to optimization of strategic and operational business processes at the level of investor companies. Thus, as a result of the study, it can be said that the inflow of foreign direct investment in the oil and gas sector has had a positive impact on economic growth in the country as a whole. Keywords: oil and gas sector; foreign investment; foreign direct investment; investment environment assessment; economic development.","PeriodicalId":43516,"journal":{"name":"SOCAR Proceedings","volume":null,"pages":null},"PeriodicalIF":1.7,"publicationDate":"2023-06-30","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"139367700","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}
This paper presents the results of lithofacies analysis of log curves and sedimentological description of the core material of wells from the Karaton field to determine the environmental condition and determine the similarity of the behavior of log curves. The field is located in the Karaton-Tengiz zone of uplifts, which are characterized by a rather complicated environmental conditions. Based on typical models of facies groups and a description of the core material of the Jurassic deposits, it was possible to identify zones of development of sandy deposits and determine the main environmental condition. Keywords: lithology; sedimentology; facies; electrofacies; generic model; depositional environment.
{"title":"Determination of the conditions of sedimentation of the Jurassic deposits of the Karaton field based on a comparison of electrofacies and sedimentological description of the core","authors":"N. A. Pronin","doi":"10.5510/ogp2023si100861","DOIUrl":"https://doi.org/10.5510/ogp2023si100861","url":null,"abstract":"This paper presents the results of lithofacies analysis of log curves and sedimentological description of the core material of wells from the Karaton field to determine the environmental condition and determine the similarity of the behavior of log curves. The field is located in the Karaton-Tengiz zone of uplifts, which are characterized by a rather complicated environmental conditions. Based on typical models of facies groups and a description of the core material of the Jurassic deposits, it was possible to identify zones of development of sandy deposits and determine the main environmental condition. Keywords: lithology; sedimentology; facies; electrofacies; generic model; depositional environment.","PeriodicalId":43516,"journal":{"name":"SOCAR Proceedings","volume":null,"pages":null},"PeriodicalIF":1.7,"publicationDate":"2023-06-30","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"139366341","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 research aims to evaluate the feasibility of using bacteria-based self-healing concrete using Portland cement and assess the effect of temperature on its performance. The results showed that the inclusion of calcium lactate and bacteria in the mixture accelerates the gain in compressive strength, but after 28 days of curing, the healing agent has no impact on the overall compressive strength value of the mixture. The crack width distribution analysis revealed an inverse relationship between crack width and self-healed area, with wider cracks having lower self-healing rates. Most of the healing occurs within 15 days, with only a small fraction healing between day 15 and 60 days. The study also showed that low temperatures do not produce self-healing in tested samples, and 25°C increases the self-healed area for all crack widths. Finally, chromatography tests of submerged water reveal that reaction to seal the cracks takes calcium from some external source. Keywords: self-healing cement; carbon emission; bacteria; calcium lactate; Portland cement.
{"title":"Laboratory analysis of self-healing cement composition based on calcium lactate and bacteria","authors":"Elchin F. Veliyev, G. V. Aliyeva","doi":"10.5510/ogp2023si100838","DOIUrl":"https://doi.org/10.5510/ogp2023si100838","url":null,"abstract":"The research aims to evaluate the feasibility of using bacteria-based self-healing concrete using Portland cement and assess the effect of temperature on its performance. The results showed that the inclusion of calcium lactate and bacteria in the mixture accelerates the gain in compressive strength, but after 28 days of curing, the healing agent has no impact on the overall compressive strength value of the mixture. The crack width distribution analysis revealed an inverse relationship between crack width and self-healed area, with wider cracks having lower self-healing rates. Most of the healing occurs within 15 days, with only a small fraction healing between day 15 and 60 days. The study also showed that low temperatures do not produce self-healing in tested samples, and 25°C increases the self-healed area for all crack widths. Finally, chromatography tests of submerged water reveal that reaction to seal the cracks takes calcium from some external source. Keywords: self-healing cement; carbon emission; bacteria; calcium lactate; Portland cement.","PeriodicalId":43516,"journal":{"name":"SOCAR Proceedings","volume":null,"pages":null},"PeriodicalIF":1.7,"publicationDate":"2023-06-30","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"139367103","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 article is devoted to the study of the relationship between the uncertainty of the volume of hydrocarbon reserves of Productive series in the South Caspian Basin and geological-technical criteria. As we know, the accuracy of the assessment of field reserves is directly affected by the degree of study of the calculation parameters. The study of these parameters depends to varying degrees on the geological and physical characteristics of this field. The main purpose of the study was to define the impact of these geological and technical factors on the uncertainty of the volume of hydrocarbon reserves. By classifying the fields according to their geological and physical characteristics, it is possible to analyze the relationship between geological and technical factors and the uncertainty of the volume of hydrocarbon reserves. As in all basins, the uncertainty of the volume of hydrocarbon reserves in the South Caspian Basin (SCB) depends on the degree of study of the calculated parameters of the fields (oil and gas field, effective thickness, porosity, oil and gas saturation, formation pressure, formation temperature, etc.). During the research, great importance was attached to the application of the cluster method. The Euclidean distance of the cluster analysis was used to identify homogeneous groups. Taking into account the general results of the research process, it should be noted that the uncertainty of the volume of Productive series (PS) hydrocarbon reserves in the SCB, in addition to the level of accuracy of calculation parameters, also depends on other geological and technical factors (depth of deposits, depth of sea, complexity of structure, number of tectonic blocks and development objects). Keywords: field; formation; uncertainty; geological and technical factors; complexity of structure; reserve.
{"title":"Investigation of the dependence between the uncertainties of the volume of hydrocarbon reserves of Productive series in the South Caspian Basin with geological and technical criteria","authors":"E. H. Ahmadov","doi":"10.5510/ogp2023si100827","DOIUrl":"https://doi.org/10.5510/ogp2023si100827","url":null,"abstract":"The article is devoted to the study of the relationship between the uncertainty of the volume of hydrocarbon reserves of Productive series in the South Caspian Basin and geological-technical criteria. As we know, the accuracy of the assessment of field reserves is directly affected by the degree of study of the calculation parameters. The study of these parameters depends to varying degrees on the geological and physical characteristics of this field. The main purpose of the study was to define the impact of these geological and technical factors on the uncertainty of the volume of hydrocarbon reserves. By classifying the fields according to their geological and physical characteristics, it is possible to analyze the relationship between geological and technical factors and the uncertainty of the volume of hydrocarbon reserves. As in all basins, the uncertainty of the volume of hydrocarbon reserves in the South Caspian Basin (SCB) depends on the degree of study of the calculated parameters of the fields (oil and gas field, effective thickness, porosity, oil and gas saturation, formation pressure, formation temperature, etc.). During the research, great importance was attached to the application of the cluster method. The Euclidean distance of the cluster analysis was used to identify homogeneous groups. Taking into account the general results of the research process, it should be noted that the uncertainty of the volume of Productive series (PS) hydrocarbon reserves in the SCB, in addition to the level of accuracy of calculation parameters, also depends on other geological and technical factors (depth of deposits, depth of sea, complexity of structure, number of tectonic blocks and development objects). Keywords: field; formation; uncertainty; geological and technical factors; complexity of structure; reserve.","PeriodicalId":43516,"journal":{"name":"SOCAR Proceedings","volume":null,"pages":null},"PeriodicalIF":1.7,"publicationDate":"2023-06-30","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"139367570","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}
When extracting oil and gas from underground reservoirs, fluids such as water, CO2, polymer solutions, and surfactant solutions are often injected to displace the hydrocarbon resources. However, the presence of high-permeable layers, channels, and fractures in the reservoirs can hinder the efficiency of the displacement processes. The displacing fluids tend to channel through these high-permeability features, leaving behind significant amounts of hydrocarbon in low-permeability zones, which remain unswept. Recent developments in nanocomposite hydrogels, such as PPGs, have shown promising results for water shutoff due to their thermal stability and deformability. In this study, a preformed particle gel with nano additive (NC-PPG) was developed through free radical polymerization of AM, AMPS, and nanoclay. Nanoclay nanoparticles were found to act as physical cross-linkers in the polymer network, leading to smaller pore sizes and slightly enhanced thermal stability. The addition of an appropriate amount of nanoclay nanoparticles significantly improved the swelling rate and mechanical properties of NC-PPG. The presented composition also showed good salt tolerance, as evidenced by its compatibility with highly saline formation water and the plugging rate and RRF of 0.25% NC-PPG solution, which were 94.3% and 17.6, respectively, in the sand-pack flowing experiment. These results suggest that NC-PPG has the potential to effectively plug the high permeability zones in mature reservoirs, making it a suitable candidate for water shutoff treatment and enhanced oil recovery (EOR) strategies. The ability of NC-PPG to improve sweep efficiency and control water flow in reservoirs can contribute to more efficient oil production and reservoir management practices. Keywords: enhanced oil recovery; water shut-off; plugging efficiency; preformed particle gel; nanoclay; sweep efficiency.
{"title":"Laboratory evaluation of novel nano composite gel for water shut-off","authors":"Elchin F. Veliyev, Azizagha Aliyev","doi":"10.5510/ogp2023si100835","DOIUrl":"https://doi.org/10.5510/ogp2023si100835","url":null,"abstract":"When extracting oil and gas from underground reservoirs, fluids such as water, CO2, polymer solutions, and surfactant solutions are often injected to displace the hydrocarbon resources. However, the presence of high-permeable layers, channels, and fractures in the reservoirs can hinder the efficiency of the displacement processes. The displacing fluids tend to channel through these high-permeability features, leaving behind significant amounts of hydrocarbon in low-permeability zones, which remain unswept. Recent developments in nanocomposite hydrogels, such as PPGs, have shown promising results for water shutoff due to their thermal stability and deformability. In this study, a preformed particle gel with nano additive (NC-PPG) was developed through free radical polymerization of AM, AMPS, and nanoclay. Nanoclay nanoparticles were found to act as physical cross-linkers in the polymer network, leading to smaller pore sizes and slightly enhanced thermal stability. The addition of an appropriate amount of nanoclay nanoparticles significantly improved the swelling rate and mechanical properties of NC-PPG. The presented composition also showed good salt tolerance, as evidenced by its compatibility with highly saline formation water and the plugging rate and RRF of 0.25% NC-PPG solution, which were 94.3% and 17.6, respectively, in the sand-pack flowing experiment. These results suggest that NC-PPG has the potential to effectively plug the high permeability zones in mature reservoirs, making it a suitable candidate for water shutoff treatment and enhanced oil recovery (EOR) strategies. The ability of NC-PPG to improve sweep efficiency and control water flow in reservoirs can contribute to more efficient oil production and reservoir management practices. Keywords: enhanced oil recovery; water shut-off; plugging efficiency; preformed particle gel; nanoclay; sweep efficiency.","PeriodicalId":43516,"journal":{"name":"SOCAR Proceedings","volume":null,"pages":null},"PeriodicalIF":1.7,"publicationDate":"2023-06-30","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"139367008","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 article analyzes the main characteristics of the reliability indicators of machines and equipment operated in emergency situations and extreme conditions. Methods for their evaluation are discussed using various methods of probability theory and mathematical statistics. Keywords: machines; equipment; reliability; emergency; extreme conditions; evaluation; probability theory; mathematical statistics.
{"title":"Analysis of the characteristics of reliability indicators of machines and equipment operating in emergency situations and extreme conditions","authors":"A. M. Gafarov, P. G. Suleymanov","doi":"10.5510/ogp2023si100864","DOIUrl":"https://doi.org/10.5510/ogp2023si100864","url":null,"abstract":"The article analyzes the main characteristics of the reliability indicators of machines and equipment operated in emergency situations and extreme conditions. Methods for their evaluation are discussed using various methods of probability theory and mathematical statistics. Keywords: machines; equipment; reliability; emergency; extreme conditions; evaluation; probability theory; mathematical statistics.","PeriodicalId":43516,"journal":{"name":"SOCAR Proceedings","volume":null,"pages":null},"PeriodicalIF":1.7,"publicationDate":"2023-06-30","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"139367773","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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