Aliaksei Sottsau, Ramir Akbashev, Alexandr Peratsiahin, Vadim Garnaev
An innovative technology for determining the water cut in well products (without preliminary separation into liquid and gas fractions) uses the results of electrical impedance measurements and its dependence on the alternating current frequency. Water cut meter's sensor includes measuring and current electrodes, between which there is a well's multiphase flow. Imaginary and real components of the impedance quantitatively describe the component composition of the studied oil and gas-water mixtures. In this process, machine learning methods and developed algorithms for features extraction are used. Depending on the type of emulsion, two independent sensors are used in the oil pipeline, one of which measures in a direct emulsion, the other in an inverse emulsion. Tests of the described water cut meter on flow loops in the Russian Federation and in the Netherlands, as well as studies of well flows in oil production facilities in the Russian Federation and the Kingdom of Saudi Arabia, have shown high measurement accuracy in the full range of water cut, with high gas content, as well as at high salinity and in a wide range of flow rates. To do so, modern methods of data classification based on neural networks and regression modeling implemented using machine learning are employed. It was found that the flow rates of liquid and gas do not affect the results of measuring the water cut due to the high frequency of the impedance measurements - up to 100 thousand measurements per second. Use of in-line multiphase water cut meter makes it possible to apply intelligent methods of processing field information and accumulate statistical data for each well, as a big data element for predicting and modeling in-situ processes. It will also allow to introduce promising production processes aimed at increasing oil production and monitoring the baseline indicators of the well. Novelty of the presented technology: Solution of the problem of high-speed determination of water cut in a multiphase flow without preliminary separation using impedance metering. Creation of mathematical models of multiphase flow and methods for determining the type of flow and the type of emulsion. Machine learning methods and neural networks employment for high-speed analysis of flow changes. Development, successful testing and implementation of an affordable multiphase water cut meter of our own design, which has no analogs in industrial applications.
{"title":"Modern Solution for Oil Well Multiphase Flows Water Cut Metering","authors":"Aliaksei Sottsau, Ramir Akbashev, Alexandr Peratsiahin, Vadim Garnaev","doi":"10.2118/206475-ms","DOIUrl":"https://doi.org/10.2118/206475-ms","url":null,"abstract":"\u0000 An innovative technology for determining the water cut in well products (without preliminary separation into liquid and gas fractions) uses the results of electrical impedance measurements and its dependence on the alternating current frequency. Water cut meter's sensor includes measuring and current electrodes, between which there is a well's multiphase flow. Imaginary and real components of the impedance quantitatively describe the component composition of the studied oil and gas-water mixtures. In this process, machine learning methods and developed algorithms for features extraction are used. Depending on the type of emulsion, two independent sensors are used in the oil pipeline, one of which measures in a direct emulsion, the other in an inverse emulsion.\u0000 Tests of the described water cut meter on flow loops in the Russian Federation and in the Netherlands, as well as studies of well flows in oil production facilities in the Russian Federation and the Kingdom of Saudi Arabia, have shown high measurement accuracy in the full range of water cut, with high gas content, as well as at high salinity and in a wide range of flow rates. To do so, modern methods of data classification based on neural networks and regression modeling implemented using machine learning are employed. It was found that the flow rates of liquid and gas do not affect the results of measuring the water cut due to the high frequency of the impedance measurements - up to 100 thousand measurements per second. Use of in-line multiphase water cut meter makes it possible to apply intelligent methods of processing field information and accumulate statistical data for each well, as a big data element for predicting and modeling in-situ processes. It will also allow to introduce promising production processes aimed at increasing oil production and monitoring the baseline indicators of the well.\u0000 Novelty of the presented technology:\u0000 Solution of the problem of high-speed determination of water cut in a multiphase flow without preliminary separation using impedance metering. Creation of mathematical models of multiphase flow and methods for determining the type of flow and the type of emulsion. Machine learning methods and neural networks employment for high-speed analysis of flow changes. Development, successful testing and implementation of an affordable multiphase water cut meter of our own design, which has no analogs in industrial applications.","PeriodicalId":11052,"journal":{"name":"Day 3 Thu, October 14, 2021","volume":"23 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-10-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"83336243","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}
Almaz Makhmutovich Sadykov, S. Erastov, M. S. Antonov, D. Kashapov, T. Salakhov, A. S. Kardopoltsev, F. Leskin, Inna Alexandrovna Sakhipova, Alexander Nikolaevich Nedoseikin, N. M. Zorkaltsev, I. F. Agzamov
One of the fundamental methods of developing low-permeability reservoirs is the use of multi-stage hydraulic fracturing in horizontal wells. Decreasing wells productivity requires geological and technical measures, where one of the methods is "blind" refracturing. Often, only one "blind" hydraulic fracturing is carried out for all ports of multistage hydraulic fracturing, the possibility of carrying out two or more stages of "blind" hydraulic fracturing is considered in this article. The purpose of the article is to increase the productivity of horizontal wells with multi-stage hydraulic fracturing by the "blind" refracturing method. A one-stage and two-stage approach was implemented when planning and performing "blind" hydraulic fracturing with analysis of treatment pressures, indicating a possibility for reorientation of the fracture during the second stage in a horizontal wellbore. Based on the experience of the "blind" hydraulic fracturing performed at the Kondinskoye field, "NK "Kondaneft" JSC carried out pilot work on "blind" refracturing at four horizontal wells of the Zapadno -Erginskoye field. A geomechanical model was used, built based on well logging and core studies carried out at "RN-BashNIPIneft" LLC. The total mass of the planned proppant per well was 280-290 tons, while this tonnage was pumped in one or more stages. A one-stage "blind" refracturing approach was successfully performed in one well, two-stage hydraulic fracturing was implemented in three wells, where in one of the wells, after two stages to open ports, initial hydraulic fracturing was also carried out to the last, previously non-activated port. In the case of two-stage hydraulic fracturing, the first stage purpose was to saturate the reservoir-fracture system with the injection of a "sand plug" with a high concentration of proppant at the end of the job to isolate the initial injectivity interval, determined based on the interpretation of well logging data and analysis of the wellhead treatment pressure. The second stage purpose was the initiation and possible reorientation of the fracture in a new interval, confirmed by an increase in surface pressure during hydraulic fracturing and instantaneous shut-in pressure. This article summarizes the results and lessons learned from the pilot works carried out using the geomechanical model and well productivity assessment before and after "blind" fracturing. The analysis of surface pressure based on production data indicating fracture reorientation is presented. The recommendations and accumulated experience presented in this work should increase the effectiveness of repeated "blind" refracturing in horizontal wells with multi-stage hydraulic fracturing.
{"title":"Scientific Approach to Planning and Implementation of Blind Refracturing in Horizontal Wells with MSF Completion in Low-Permeability Reservoirs","authors":"Almaz Makhmutovich Sadykov, S. Erastov, M. S. Antonov, D. Kashapov, T. Salakhov, A. S. Kardopoltsev, F. Leskin, Inna Alexandrovna Sakhipova, Alexander Nikolaevich Nedoseikin, N. M. Zorkaltsev, I. F. Agzamov","doi":"10.2118/206406-ms","DOIUrl":"https://doi.org/10.2118/206406-ms","url":null,"abstract":"\u0000 One of the fundamental methods of developing low-permeability reservoirs is the use of multi-stage hydraulic fracturing in horizontal wells. Decreasing wells productivity requires geological and technical measures, where one of the methods is \"blind\" refracturing. Often, only one \"blind\" hydraulic fracturing is carried out for all ports of multistage hydraulic fracturing, the possibility of carrying out two or more stages of \"blind\" hydraulic fracturing is considered in this article.\u0000 The purpose of the article is to increase the productivity of horizontal wells with multi-stage hydraulic fracturing by the \"blind\" refracturing method. A one-stage and two-stage approach was implemented when planning and performing \"blind\" hydraulic fracturing with analysis of treatment pressures, indicating a possibility for reorientation of the fracture during the second stage in a horizontal wellbore.\u0000 Based on the experience of the \"blind\" hydraulic fracturing performed at the Kondinskoye field, \"NK \"Kondaneft\" JSC carried out pilot work on \"blind\" refracturing at four horizontal wells of the Zapadno -Erginskoye field. A geomechanical model was used, built based on well logging and core studies carried out at \"RN-BashNIPIneft\" LLC. The total mass of the planned proppant per well was 280-290 tons, while this tonnage was pumped in one or more stages. A one-stage \"blind\" refracturing approach was successfully performed in one well, two-stage hydraulic fracturing was implemented in three wells, where in one of the wells, after two stages to open ports, initial hydraulic fracturing was also carried out to the last, previously non-activated port. In the case of two-stage hydraulic fracturing, the first stage purpose was to saturate the reservoir-fracture system with the injection of a \"sand plug\" with a high concentration of proppant at the end of the job to isolate the initial injectivity interval, determined based on the interpretation of well logging data and analysis of the wellhead treatment pressure. The second stage purpose was the initiation and possible reorientation of the fracture in a new interval, confirmed by an increase in surface pressure during hydraulic fracturing and instantaneous shut-in pressure.\u0000 This article summarizes the results and lessons learned from the pilot works carried out using the geomechanical model and well productivity assessment before and after \"blind\" fracturing. The analysis of surface pressure based on production data indicating fracture reorientation is presented. The recommendations and accumulated experience presented in this work should increase the effectiveness of repeated \"blind\" refracturing in horizontal wells with multi-stage hydraulic fracturing.","PeriodicalId":11052,"journal":{"name":"Day 3 Thu, October 14, 2021","volume":"22 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-10-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"85614070","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}
Vadim Andreevich Rubailo, K. Isakov, A. Osipenko, M. M. Akhmadiev
The work is devoted to the analytical methodology for the development of oil lenticular formations. The method is based on the theory of potentials for vertical and horizontal wells. The work takes into account the interference of wells, geological and petrophysical parameters of lenses, as well as the properties of the reservoir fluid, and a new equation for estimating the inflow to a horizontal well is derived. An assessment of the correctness of this work on the company's assets was made. The dependence for the express estimation of the number of wells depending on the economic parameters at the early stages of project development is obtained.
{"title":"Formation of a Methodology for Calculating the Optimal Number of Wells in the Development of Lenticular Formations to Achieve Maximum NPV","authors":"Vadim Andreevich Rubailo, K. Isakov, A. Osipenko, M. M. Akhmadiev","doi":"10.2118/206500-ms","DOIUrl":"https://doi.org/10.2118/206500-ms","url":null,"abstract":"\u0000 The work is devoted to the analytical methodology for the development of oil lenticular formations. The method is based on the theory of potentials for vertical and horizontal wells. The work takes into account the interference of wells, geological and petrophysical parameters of lenses, as well as the properties of the reservoir fluid, and a new equation for estimating the inflow to a horizontal well is derived. An assessment of the correctness of this work on the company's assets was made. The dependence for the express estimation of the number of wells depending on the economic parameters at the early stages of project development is obtained.","PeriodicalId":11052,"journal":{"name":"Day 3 Thu, October 14, 2021","volume":"64 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-10-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"80837162","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}
A. Grinevskiy, I. Kazora, I. Kerusov, D. Miroshnichenko
The article discusses the approaches and methods to study the Middle Jurassic deposits of the Tyumen Formation within the Frolov megadepression (West Siberian oil and gas province), which have high hydrocarbon potential. The materials refer to several areas with available 3D seismic data and several dozen oil wells. The problems of seismic interpretation and its application for geological modeling are considered. We also propose several ways to overcome them.
{"title":"Seismic Reservoir Characterisation of Tyumen Formation in Frolov Megadepression","authors":"A. Grinevskiy, I. Kazora, I. Kerusov, D. Miroshnichenko","doi":"10.2118/206592-ms","DOIUrl":"https://doi.org/10.2118/206592-ms","url":null,"abstract":"\u0000 The article discusses the approaches and methods to study the Middle Jurassic deposits of the Tyumen Formation within the Frolov megadepression (West Siberian oil and gas province), which have high hydrocarbon potential. The materials refer to several areas with available 3D seismic data and several dozen oil wells.\u0000 The problems of seismic interpretation and its application for geological modeling are considered. We also propose several ways to overcome them.","PeriodicalId":11052,"journal":{"name":"Day 3 Thu, October 14, 2021","volume":"1 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-10-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"87730804","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}
C. A. Garifullina, I. Ibragimov, I. Indrupskiy, D. S. Klimov, E. Zakirov, R. Sakhabutdinov
Continuing consumption of fossil fuels around the world, which has led to an increasing concentration of carbon dioxide CO2 in the atmosphere and global climate change caused by greenhouse gases, has become one of the main challenges for humanity. Heterogeneous catalytic hydrogenation of carbon dioxide in order to obtain valuable carbon-containing products and materials is one of the decarbonization directions. There is much research in the world dedicated to the hydrogenation of CO2 to various hydrocarbons, such as methane, lower olefins, long-chain hydrocarbons, formic acid, methanol and higher alcohols, which are produced by catalytic reactions with various mechanisms. There are still significant challenges associated with the need for an external source of hydrogen, high process temperatures, and the development of active, selective, and stable catalysts that would be suitable for large-scale production. This paper presents results of research on a CO2 utilization method with hydrogen and hydrocarbons production – the transformation of wastes into a source of energy, which allows solving environmental and energy problems. The method described in this paper consists in the interaction of metallic fillers with water saturated with carbon dioxide in a reactor at low (room) temperatures and further analysis of the resulting gas mixture using a chromatograph. Qualitative and quantitative evaluation of the produced gas composition, study of the effect of reaction system volume, filler composition and structure, and process temperature on the reaction product yield are presented. The results of theoretical and experimental analysis of the reactions underlying the process are given, and the economic potential of the proposed laboratory method is evaluated.
{"title":"Investigation of CO2 Utilization Processes on Metal-Containing Fillers with Generation of Hydrogen and Hydrocarbons","authors":"C. A. Garifullina, I. Ibragimov, I. Indrupskiy, D. S. Klimov, E. Zakirov, R. Sakhabutdinov","doi":"10.2118/206612-ms","DOIUrl":"https://doi.org/10.2118/206612-ms","url":null,"abstract":"\u0000 Continuing consumption of fossil fuels around the world, which has led to an increasing concentration of carbon dioxide CO2 in the atmosphere and global climate change caused by greenhouse gases, has become one of the main challenges for humanity. Heterogeneous catalytic hydrogenation of carbon dioxide in order to obtain valuable carbon-containing products and materials is one of the decarbonization directions. There is much research in the world dedicated to the hydrogenation of CO2 to various hydrocarbons, such as methane, lower olefins, long-chain hydrocarbons, formic acid, methanol and higher alcohols, which are produced by catalytic reactions with various mechanisms. There are still significant challenges associated with the need for an external source of hydrogen, high process temperatures, and the development of active, selective, and stable catalysts that would be suitable for large-scale production.\u0000 This paper presents results of research on a CO2 utilization method with hydrogen and hydrocarbons production – the transformation of wastes into a source of energy, which allows solving environmental and energy problems. The method described in this paper consists in the interaction of metallic fillers with water saturated with carbon dioxide in a reactor at low (room) temperatures and further analysis of the resulting gas mixture using a chromatograph.\u0000 Qualitative and quantitative evaluation of the produced gas composition, study of the effect of reaction system volume, filler composition and structure, and process temperature on the reaction product yield are presented. The results of theoretical and experimental analysis of the reactions underlying the process are given, and the economic potential of the proposed laboratory method is evaluated.","PeriodicalId":11052,"journal":{"name":"Day 3 Thu, October 14, 2021","volume":"11 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-10-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"74975399","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}
M. Shipaeva, D. Nurgaliev, A. Zaikin, V. Sudakov, A. Shakirov, Lutfullin Azat Abuzarovich, B. Ganiev
At the present stage of the hydrocarbon production process, most of the unique and largest fields in the world are at a late stage of development. Despite the active development and policy of a decarbonised economy, the demand for liquid and gaseous hydrocarbons remains high, while of inevitably growing the number of mature fields. The Volga-Ural oil and gas province today is an old oil and gas producing region, most of the fields have already entered the final stage of development. However, through the introduction and development of new technologies for oil extraction, monitoring of production and localization of reserves, the life of the fields can be extended. One of these technologies is geochemical monitoring of well production. Its goal is to optimize the development of mature fields on the basis of promptly obtained information about the state of the wells using geochemical studies of the formation fluid, allowing timely implementation of the necessary measures. Geochemical studies allow identifying the source of fluid entering the well, determining a violation in the wellbore structure, checking the tightness of downhole equipment for separate operation, and performing an area analysis of the area development efficiency. This type of research is relevant both in giant fields with a large stock of production wells, often characterized from a geological point of view by multilayer structure, with technological complexity, packing, wear of equipment and strings, in some cases the impossibility of running gauge for research, and in fields with low depletion. The possibilities of geochemistry for solving local operational problems in wells are shown. Several hydrogeological complexes have been studied, the change in the properties of the produced water during the development process is described. The concepts of the geochemical conditions in the hydrocarbon deposits that existed earlier are changing due to the development of these objects as a dynamic system, continuous injection of different types of water into the reservoir, the use of enhanced oil recovery methods and other technogenic impact associated with the development of reserves. The digital revolution and the modern development of the industry marked the beginning of the creation of the Digital Atlas of Groundwater, the development of specialized algorithms that allow processing large amounts of data.
{"title":"Geochemical Monitoring of Formation Fluids for Reservoir Management Considering Complicating Factors in Mature Oilfields","authors":"M. Shipaeva, D. Nurgaliev, A. Zaikin, V. Sudakov, A. Shakirov, Lutfullin Azat Abuzarovich, B. Ganiev","doi":"10.2118/206506-ms","DOIUrl":"https://doi.org/10.2118/206506-ms","url":null,"abstract":"\u0000 At the present stage of the hydrocarbon production process, most of the unique and largest fields in the world are at a late stage of development. Despite the active development and policy of a decarbonised economy, the demand for liquid and gaseous hydrocarbons remains high, while of inevitably growing the number of mature fields. The Volga-Ural oil and gas province today is an old oil and gas producing region, most of the fields have already entered the final stage of development. However, through the introduction and development of new technologies for oil extraction, monitoring of production and localization of reserves, the life of the fields can be extended. One of these technologies is geochemical monitoring of well production. Its goal is to optimize the development of mature fields on the basis of promptly obtained information about the state of the wells using geochemical studies of the formation fluid, allowing timely implementation of the necessary measures. Geochemical studies allow identifying the source of fluid entering the well, determining a violation in the wellbore structure, checking the tightness of downhole equipment for separate operation, and performing an area analysis of the area development efficiency. This type of research is relevant both in giant fields with a large stock of production wells, often characterized from a geological point of view by multilayer structure, with technological complexity, packing, wear of equipment and strings, in some cases the impossibility of running gauge for research, and in fields with low depletion. The possibilities of geochemistry for solving local operational problems in wells are shown. Several hydrogeological complexes have been studied, the change in the properties of the produced water during the development process is described. The concepts of the geochemical conditions in the hydrocarbon deposits that existed earlier are changing due to the development of these objects as a dynamic system, continuous injection of different types of water into the reservoir, the use of enhanced oil recovery methods and other technogenic impact associated with the development of reserves. The digital revolution and the modern development of the industry marked the beginning of the creation of the Digital Atlas of Groundwater, the development of specialized algorithms that allow processing large amounts of data.","PeriodicalId":11052,"journal":{"name":"Day 3 Thu, October 14, 2021","volume":"195 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-10-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"75882377","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 long-term practice of operating wells producing oil rich in paraffins and asphaltenes has shown that the optimization of technologies for the removal of solid high-molecular organic deposits (asphaltene-resin-paraffin deposits) in oilfield equipment, lifting pipes and flow lines makes it possible to effectively solve the issues of improving the environmental friendliness and energy efficiency of oil production. The use of composite hydrocarbon solvents is one of the most well-known methods used to remove asphaltene-resin-paraffin deposits. Thus, to date, there is no systemic solution to this issue. This paper is aimed at discussing the provisions that determine the possible prospects for the development of an optimal strategy for the use of solvents for the removal of asphaltene-resin-paraffin deposits.
{"title":"The Choice of the Optimal Strategy for the Use of Solvents of High-Molecular Organic Deposits, Considering their Complex Composition and the Effect on the Oil Dispersion System","authors":"I. Guskova, D. Khayarova, E. R. Abzyapparova","doi":"10.2118/206473-ms","DOIUrl":"https://doi.org/10.2118/206473-ms","url":null,"abstract":"\u0000 The long-term practice of operating wells producing oil rich in paraffins and asphaltenes has shown that the optimization of technologies for the removal of solid high-molecular organic deposits (asphaltene-resin-paraffin deposits) in oilfield equipment, lifting pipes and flow lines makes it possible to effectively solve the issues of improving the environmental friendliness and energy efficiency of oil production. The use of composite hydrocarbon solvents is one of the most well-known methods used to remove asphaltene-resin-paraffin deposits. Thus, to date, there is no systemic solution to this issue. This paper is aimed at discussing the provisions that determine the possible prospects for the development of an optimal strategy for the use of solvents for the removal of asphaltene-resin-paraffin deposits.","PeriodicalId":11052,"journal":{"name":"Day 3 Thu, October 14, 2021","volume":"15 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-10-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"73568291","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}
A. Glotov, A. Skripkin, P. B. Molokov, N. Mikhailov
The article presents a new method of determining the residual water saturation of the Bazhenov Rock Formation using synchronous thermal analysis which is combined with gas IR and MS spectroscopy. The efficiency of the extraction-distillation method of determining open porous and residual saturation in comparison with the developed method which are considered in detail. Based on the results of studies in the properties of the Bazhenov Rock Formation, a significant underestimation of the residual water saturation in the existing guidelines for calculating reserves was found, and the structure of the saturation of rocks occurred to be typical for traditional low-permeability reservoirs. The values of open porous and residual water saturation along the section of the Bazhenov Formation vary greatly, which also contradicts the well-established opinion about the weak variability of the rock properties with depth.
{"title":"Residual Water Saturation of Source Rocks of the Bazhenov Formation Western Siberia, Russia","authors":"A. Glotov, A. Skripkin, P. B. Molokov, N. Mikhailov","doi":"10.2118/206586-ms","DOIUrl":"https://doi.org/10.2118/206586-ms","url":null,"abstract":"\u0000 The article presents a new method of determining the residual water saturation of the Bazhenov Rock Formation using synchronous thermal analysis which is combined with gas IR and MS spectroscopy. The efficiency of the extraction-distillation method of determining open porous and residual saturation in comparison with the developed method which are considered in detail. Based on the results of studies in the properties of the Bazhenov Rock Formation, a significant underestimation of the residual water saturation in the existing guidelines for calculating reserves was found, and the structure of the saturation of rocks occurred to be typical for traditional low-permeability reservoirs. The values of open porous and residual water saturation along the section of the Bazhenov Formation vary greatly, which also contradicts the well-established opinion about the weak variability of the rock properties with depth.","PeriodicalId":11052,"journal":{"name":"Day 3 Thu, October 14, 2021","volume":"4 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-10-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"88177889","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}
R. F. Ismagilov, I. Chernykh, A. S. Chukhlov, Sergey Evgenievich Nikulin, D. Gulyaev, L. Zinurov
The investigated field is located in the Solikamsk drawdown in the northeast of the Perm Territory. The oil content level of this field is composed of Tournaisian-Famennian, Radaevsky, Radaevian, and Tula formations. This article will analysis carbonate deposits from the Tula formation using the multiwell retrospective testing (MRT) technology. Currently, the development system has been already formed, and there is ongoing compaction drilling and targeted drawdown increase that is carried out at certain wells. A pressure support system has been formed. Before the surveys have been conducted, there was a trend in production decline, for reasons that are currently unknown. To identify the causes of production decline at the carbonate reservoir in the field, special technology was used to analysis production history data and bottom hole pressure - this technology is called multiwell retrospective testing (MRT). Four sections were selected for further analysis, MRT was able to reconstruct the reservoir pressure variations and production coefficient at the tested well, the influence of the offset wells on the tested wells has been evaluated, along with transmissibility at the cross-well interval and well-bore skin of the tested wells.
{"title":"Optimization of the Reservoir Pressure Maintenance System in a Low-Permeability Carbonate Field","authors":"R. F. Ismagilov, I. Chernykh, A. S. Chukhlov, Sergey Evgenievich Nikulin, D. Gulyaev, L. Zinurov","doi":"10.2118/206507-ms","DOIUrl":"https://doi.org/10.2118/206507-ms","url":null,"abstract":"The investigated field is located in the Solikamsk drawdown in the northeast of the Perm Territory. The oil content level of this field is composed of Tournaisian-Famennian, Radaevsky, Radaevian, and Tula formations. This article will analysis carbonate deposits from the Tula formation using the multiwell retrospective testing (MRT) technology.\u0000 Currently, the development system has been already formed, and there is ongoing compaction drilling and targeted drawdown increase that is carried out at certain wells. A pressure support system has been formed. Before the surveys have been conducted, there was a trend in production decline, for reasons that are currently unknown. To identify the causes of production decline at the carbonate reservoir in the field, special technology was used to analysis production history data and bottom hole pressure - this technology is called multiwell retrospective testing (MRT).\u0000 Four sections were selected for further analysis, MRT was able to reconstruct the reservoir pressure variations and production coefficient at the tested well, the influence of the offset wells on the tested wells has been evaluated, along with transmissibility at the cross-well interval and well-bore skin of the tested wells.","PeriodicalId":11052,"journal":{"name":"Day 3 Thu, October 14, 2021","volume":"33 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-10-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"83882200","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. Sokolov, M. Delengov, Regina Sabirianova, K. Musikhin, Oleg Bogdanov
The objective of this paper is to assess the generation potential of the Triassic hydrocarbon (HC) source rocks for the petroleum potential of the Middle-Caspian Oil and Gas Basin. Tectonically the study area belongs to the Epigercine Scythian-Turanian plate, which includes the following major tectonic elements: the Karpinsk-Mangyshlak ridge and the Prikum-Central Caspian system of troughs and uplifts. Comprehensive research approach to identify the main features of the Triassic hydrocarbon system, such as the interpretation of seismic data, laboratory geochemical analysis and evolution restoration of the hydrocarbon systems elements by 3D basin modeling techniques. The geochemical research includes pyrolytic analysis of potential Triassic source rocks, determination of the vitrinite reflectance values, chromatography-Mass Spectrometry studies of molecular structure. The subsequent basin modeling made it possible to integrate a wide range of geological and geophysical information into a single complex. These basin modeling results provide a better understanding of evolution restoration of the hydrocarbon systems elements and make it possible to foresee hydrocarbon accumulation's localization. The combined set of research helped to identify the boundaries of the Triassic HC source rocks in the Middle-Caspian Basin. It also allowed characterizing in detail their geochemical parameters and evaluating the volume of its generation potential. Triassic deposits are part of the taphrogenic intermediate complex of the Scythian platform and mainly located in graben structures. The increased content of organic matter is associated with the Lower Triassic Neftekum Formation of the Olenek Stage, which is composed of clayey limestones and mudstones. The content of total organic carbon (TOC) in limestones in the Eastern Fore-Caucasus area averages 0.1 % in some layers up to 2.05 %. The average TOC content in mudstones is 0.43 %. This parameter is up to 0.9 % in the direction of the East-Manych trough. Triassic deposits were penetrated by 5 wells, the average content of organic carbon was 1.22% in mudstones. The samples show a migrant presence of bitumen. According to 3D basin modeling results, the Olenek HC source rock has practically exhausted its potential in on most of the except the southern part of the study area, as well as the eastern flank. The Olenek stage's Neftekum HC source rock in the southern part of the model is identified with MK1-3 catagenesis gradations, this grade represents the main zone of oil generation. At the northern part of study area, those strata of source rock are positioned at a great depth. The hydrocarbon source rock in those areas have reached the grades of catagenesis MK5-AK1, which represents the zones of condensate and gas formation. The research results allow to take a new look at the influence of the Triassic hydrocarbon system and its prospects of petroleum potential of the Middle-Caspian Oil and Gas Basin. It also
{"title":"Triassic Hydrocarbon System of the Middle-Caspian Oil and Gas Basin","authors":"D. Sokolov, M. Delengov, Regina Sabirianova, K. Musikhin, Oleg Bogdanov","doi":"10.2118/206597-ms","DOIUrl":"https://doi.org/10.2118/206597-ms","url":null,"abstract":"\u0000 The objective of this paper is to assess the generation potential of the Triassic hydrocarbon (HC) source rocks for the petroleum potential of the Middle-Caspian Oil and Gas Basin. Tectonically the study area belongs to the Epigercine Scythian-Turanian plate, which includes the following major tectonic elements: the Karpinsk-Mangyshlak ridge and the Prikum-Central Caspian system of troughs and uplifts.\u0000 Comprehensive research approach to identify the main features of the Triassic hydrocarbon system, such as the interpretation of seismic data, laboratory geochemical analysis and evolution restoration of the hydrocarbon systems elements by 3D basin modeling techniques. The geochemical research includes pyrolytic analysis of potential Triassic source rocks, determination of the vitrinite reflectance values, chromatography-Mass Spectrometry studies of molecular structure. The subsequent basin modeling made it possible to integrate a wide range of geological and geophysical information into a single complex. These basin modeling results provide a better understanding of evolution restoration of the hydrocarbon systems elements and make it possible to foresee hydrocarbon accumulation's localization.\u0000 The combined set of research helped to identify the boundaries of the Triassic HC source rocks in the Middle-Caspian Basin. It also allowed characterizing in detail their geochemical parameters and evaluating the volume of its generation potential. Triassic deposits are part of the taphrogenic intermediate complex of the Scythian platform and mainly located in graben structures. The increased content of organic matter is associated with the Lower Triassic Neftekum Formation of the Olenek Stage, which is composed of clayey limestones and mudstones.\u0000 The content of total organic carbon (TOC) in limestones in the Eastern Fore-Caucasus area averages 0.1 % in some layers up to 2.05 %. The average TOC content in mudstones is 0.43 %. This parameter is up to 0.9 % in the direction of the East-Manych trough. Triassic deposits were penetrated by 5 wells, the average content of organic carbon was 1.22% in mudstones. The samples show a migrant presence of bitumen.\u0000 According to 3D basin modeling results, the Olenek HC source rock has practically exhausted its potential in on most of the except the southern part of the study area, as well as the eastern flank.\u0000 The Olenek stage's Neftekum HC source rock in the southern part of the model is identified with MK1-3 catagenesis gradations, this grade represents the main zone of oil generation. At the northern part of study area, those strata of source rock are positioned at a great depth. The hydrocarbon source rock in those areas have reached the grades of catagenesis MK5-AK1, which represents the zones of condensate and gas formation.\u0000 The research results allow to take a new look at the influence of the Triassic hydrocarbon system and its prospects of petroleum potential of the Middle-Caspian Oil and Gas Basin. It also","PeriodicalId":11052,"journal":{"name":"Day 3 Thu, October 14, 2021","volume":"4 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-10-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"89944399","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：