In a laboratory experiment, the ability of the soil to self-cleaning under heavy petroleum pollution and the effect of biochars and shungites on the cleaning process were studied. Incubation of contaminated soils for 28 days at a constant humidity and temperature without addition of sorbents led to a decrease in the residual content of petroleum products by only 8%. The addition of biochar and shungite at a dose of 2.5% made it possible to reduce the content of petroleum under constant incubation conditions to 48.8% and 38%, respectively. It was shown that the incubation of oil-contaminated soils in the regime of variable humidity and temperature without the addition of sorbents makes it possible to reduce the content of petroleum by 32% over 28 days of the experiment. In the course of the study, methods were developed for determining substrate-induced respiration (SIR) in various incubation modes. Soil contamination with petroleum led to a significant decrease of SIR in the initial period of incubation from 12.8 C-CO2 µg/g h to 8.6 C-CO2 µg/g h, which returned to normal on the 14th day of the experiment. It has been shown that the introduction of biochars (to a lesser extent schungites) into oil-contaminated soils ensures the maintenance of SIR at the required level and increases the potential capacity of soils for self-purification. The paper discusses the possibilities of increasing the potential capacity of soils for self-cleaning under heavy oil pollution.
{"title":"Influence of carbon sorbents on the potential ability of soils to self-cleaning from petroleum pollution","authors":"E. V. Smirnova, R. Okunev, K. Giniyatullin","doi":"10.18599/grs.2022.3.18","DOIUrl":"https://doi.org/10.18599/grs.2022.3.18","url":null,"abstract":"In a laboratory experiment, the ability of the soil to self-cleaning under heavy petroleum pollution and the effect of biochars and shungites on the cleaning process were studied. Incubation of contaminated soils for 28 days at a constant humidity and temperature without addition of sorbents led to a decrease in the residual content of petroleum products by only 8%. The addition of biochar and shungite at a dose of 2.5% made it possible to reduce the content of petroleum under constant incubation conditions to 48.8% and 38%, respectively. It was shown that the incubation of oil-contaminated soils in the regime of variable humidity and temperature without the addition of sorbents makes it possible to reduce the content of petroleum by 32% over 28 days of the experiment. In the course of the study, methods were developed for determining substrate-induced respiration (SIR) in various incubation modes. Soil contamination with petroleum led to a significant decrease of SIR in the initial period of incubation from 12.8 C-CO2 µg/g h to 8.6 C-CO2 µg/g h, which returned to normal on the 14th day of the experiment. It has been shown that the introduction of biochars (to a lesser extent schungites) into oil-contaminated soils ensures the maintenance of SIR at the required level and increases the potential capacity of soils for self-purification. The paper discusses the possibilities of increasing the potential capacity of soils for self-cleaning under heavy oil pollution.","PeriodicalId":43752,"journal":{"name":"Georesursy","volume":null,"pages":null},"PeriodicalIF":0.8,"publicationDate":"2022-09-30","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"44716610","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 considering a new effective step-by-step approach to creating and tuning PVT-models of reservoir oil and reservoir gas condensate mixtures. The method is based on the reproducing of the results of field measurements and basic laboratory studies of representative samples in thermodynamic modeling using cubic three parameters equation of state. Tuning PVT-model is used for reliable modeling of PVT properties of reservoir fluids (reservoir oil and reservoir gas) in the design and monitoring of field development, calculation of multiphase flow in wells and field pipelines, as well as in basin modeling. Proposed approach makes possible to tune the PVT model with high accuracy of both reservoir oil and reservoir gas condensate system to experimental data using a step-by-step procedure, where at each step, by changing one of the parameters of the equation of state, one of the PVT properties of the hydrocarbon system is tuned. Algorithmization and automated application of this approach in specialized software products is possible. Proposed approach allows tune reservoir oil PVT-models on the main PVT-properties such as saturation pressure, FVF, STO density, gas-oil ratio of reservoir oil and dependencies of dynamic viscosity and compressibility on pressure at reservoir temperature as well as STO density. The tuned gas-condensate PVT-model precisely reproduces the key properties such as dew point pressure, initial condensate content in the reservoir gas, z-factor of the reservoir gas, gas-oil ratio, stable condensate density, drop down curve by the result of CVD-test. PVT-models created on the base of the proposed method, provide reliable information on the properties of a reservoir fluid in development of flow simulation both using a reservoir simulation compositional models and using pseudo models “black oil”. The method is illustrated by the example of creation of the adequate PVT-models of various regions of Russia reservoir oil and reservoir gas condensate mixtures.
{"title":"A step-by-step approach to creating and tuning PVT-models of reservoir hydrocarbon systems based on the state equation","authors":"T. Yushchenko, A. Brusilovsky","doi":"10.18599/grs.2022.3.14","DOIUrl":"https://doi.org/10.18599/grs.2022.3.14","url":null,"abstract":"The article is considering a new effective step-by-step approach to creating and tuning PVT-models of reservoir oil and reservoir gas condensate mixtures. The method is based on the reproducing of the results of field measurements and basic laboratory studies of representative samples in thermodynamic modeling using cubic three parameters equation of state. Tuning PVT-model is used for reliable modeling of PVT properties of reservoir fluids (reservoir oil and reservoir gas) in the design and monitoring of field development, calculation of multiphase flow in wells and field pipelines, as well as in basin modeling. \u0000\u0000Proposed approach makes possible to tune the PVT model with high accuracy of both reservoir oil and reservoir gas condensate system to experimental data using a step-by-step procedure, where at each step, by changing one of the parameters of the equation of state, one of the PVT properties of the hydrocarbon system is tuned. Algorithmization and automated application of this approach in specialized software products is possible.\u0000\u0000Proposed approach allows tune reservoir oil PVT-models on the main PVT-properties such as saturation pressure, FVF, STO density, gas-oil ratio of reservoir oil and dependencies of dynamic viscosity and compressibility on pressure at reservoir temperature as well as STO density. The tuned gas-condensate PVT-model precisely reproduces the key properties such as dew point pressure, initial condensate content in the reservoir gas, z-factor of the reservoir gas, gas-oil ratio, stable condensate density, drop down curve by the result of CVD-test. \u0000\u0000PVT-models created on the base of the proposed method, provide reliable information on the properties of a reservoir fluid in development of flow simulation both using a reservoir simulation compositional models and using pseudo models “black oil”.\u0000The method is illustrated by the example of creation of the adequate PVT-models of various regions of Russia reservoir oil and reservoir gas condensate mixtures.","PeriodicalId":43752,"journal":{"name":"Georesursy","volume":null,"pages":null},"PeriodicalIF":0.8,"publicationDate":"2022-09-30","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"49037753","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 results of laboratory studies of nearly 1,300 samples from 50 wells of reservoirs of three productive terrigenous horizons represented by sandstones and siltstones are considered. Intergranular and fractured components mainly make up the porosity structure of reservoirs and their values influence the main parameters of rocks, including filtration-capacitive properties of reservoirs, and determine the processes of hydrocarbon field development. The spatial distribution of the intergranular and fractured components of reservoir porosity affects the development and exploitation of oil and gas reservoirs and determines the relevance of this study. The values of the fracture and intergranular component of porosity were determined by the author’s method using data on open porosity and the rate of elastic wave propagation in rock samples and the mineral skeleton of these samples during the simulation of reservoir conditions. A mosaic area distribution of fractured porosity values, caused by a long geological and tectonic history of the area development, was revealed. We identified zones of increased fractured porosity up to 0.7–0.8 % (percent absolute porosity) in the north and center of the western part of the field, and zones with minimum fractured porosity values of less than 0.2–0.3 % in the eastern part of the field. Results of laboratory core studies showed the presence of fractured porosity in reservoirs up to 1.26 %. The data on the size and distribution of fractured reservoirs across the Chayanda field area may be used to refine the field development project.
{"title":"Distribution of fractured reservoirs in the Chayanda field (Eastern Siberia)","authors":"Vitaly S. Zhukov, Vladimir V. Motorygin","doi":"10.18599/grs.2022.3.7","DOIUrl":"https://doi.org/10.18599/grs.2022.3.7","url":null,"abstract":"The results of laboratory studies of nearly 1,300 samples from 50 wells of reservoirs of three productive terrigenous horizons represented by sandstones and siltstones are considered. Intergranular and fractured components mainly make up the porosity structure of reservoirs and their values influence the main parameters of rocks, including filtration-capacitive properties of reservoirs, and determine the processes of hydrocarbon field development. The spatial distribution of the intergranular and fractured components of reservoir porosity affects the development and exploitation of oil and gas reservoirs and determines the relevance of this study. The values of the fracture and intergranular component of porosity were determined by the author’s method using data on open porosity and the rate of elastic wave propagation in rock samples and the mineral skeleton of these samples during the simulation of reservoir conditions.\u0000 \u0000A mosaic area distribution of fractured porosity values, caused by a long geological and tectonic history of the area development, was revealed. We identified zones of increased fractured porosity up to 0.7–0.8 % (percent absolute porosity) in the north and center of the western part of the field, and zones with minimum fractured porosity values of less than 0.2–0.3 % in the eastern part of the field. Results of laboratory core studies showed the presence of fractured porosity in reservoirs up to 1.26 %. The data on the size and distribution of fractured reservoirs across the Chayanda field area may be used to refine the field development project.","PeriodicalId":43752,"journal":{"name":"Georesursy","volume":null,"pages":null},"PeriodicalIF":0.8,"publicationDate":"2022-09-30","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"44900268","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. I. Shchekin, V. V. Verzhbitsky, T. A. Gunkina, Alexander V. Handzel
The paper discusses methodological approaches to the use of deterministic factor analysis for identifying the sources of changes in gas wells’ parameters under steady-state gas inflow obeying linear and non-linear filtration laws. Factor analysis methods make it possible to quantify the degree of influence of individual factors on the deviation of the indicator under study. In accordance with the methodology of factor analysis, mathematical models of the factor system were substantiated for linear and non-linear gas filtration, a set of factors of influence was determined, and ready-made solutions for factor analysis of gas wells’ operating parameters were obtained. In the paper, the method of weighted finite differences was substantiated and investigated with the aim of factor analyzing gas wells’ mode of operation and obtaining formulas to calculate the increment in gas production caused by changes in factors. Approbation of working formulas for assessing the degree of influence of factors on either positive or negative deviations in the gas flow rate was carried out with respect to the parameters of the wells of underground gas storages in the cycles of withdrawal and injection. The obtained formulas for factor analysis of gas wells make it possible to quantify the influence of such factors as reservoir and bottomhole pressures, filtration resistance coefficients, on the deviation of gas flow rate. Further ranking of wells by factors constitutes the basis for managing gas withdrawal (injection) processes and for well interventions planning.
{"title":"Factor analysis of gas wells’ operating parameters","authors":"A. I. Shchekin, V. V. Verzhbitsky, T. A. Gunkina, Alexander V. Handzel","doi":"10.18599/grs.2022.3.12","DOIUrl":"https://doi.org/10.18599/grs.2022.3.12","url":null,"abstract":"The paper discusses methodological approaches to the use of deterministic factor analysis for identifying the sources of changes in gas wells’ parameters under steady-state gas inflow obeying linear and non-linear filtration laws. Factor analysis methods make it possible to quantify the degree of influence of individual factors on the deviation of the indicator under study. In accordance with the methodology of factor analysis, mathematical models of the factor system were substantiated for linear and non-linear gas filtration, a set of factors of influence was determined, and ready-made solutions for factor analysis of gas wells’ operating parameters were obtained. In the paper, the method of weighted finite differences was substantiated and investigated with the aim of factor analyzing gas wells’ mode of operation and obtaining formulas to calculate the increment in gas production caused by changes in factors. Approbation of working formulas for assessing the degree of influence of factors on either positive or negative deviations in the gas flow rate was carried out with respect to the parameters of the wells of underground gas storages in the cycles of withdrawal and injection. The obtained formulas for factor analysis of gas wells make it possible to quantify the influence of such factors as reservoir and bottomhole pressures, filtration resistance coefficients, on the deviation of gas flow rate. Further ranking of wells by factors constitutes the basis for managing gas withdrawal (injection) processes and for well interventions planning.","PeriodicalId":43752,"journal":{"name":"Georesursy","volume":null,"pages":null},"PeriodicalIF":0.8,"publicationDate":"2022-09-30","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"48054874","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}
Experience shows that in the process of creating and long-term cyclic operation of underground gas storage facilities (UGS) in reservoirs of aquifers, reservoir gas losses can occur. Losses can reach tens of percent of the injected volumes of gas into the reservoir and have a significant impact on the reliability and safety and efficiency of operation of UGS. In this regard, the issues of the organization of field control and methodology for assessing reservoir gas losses at UGS are relevant. The article proposes the structuring of the gas injected into the reservoir into possible reservoir components, taking into account the state of the gas phase and participation in filtration mass transfer processes. The main factors determining the formation of different reservoir components are given. The basic concepts are considered and the definition of reservoir gas losses at UGS in aquifers is given. The main features of one or another type of reservoir gas losses are shown. Reservoir losses from free gas currents from an artificial gas deposit, which can occur as a result of vertical leaks from the storage facility and lateral gas escapes through the reservoir beyond the trap, are briefly described. Formation losses associated with gas adsorption by rocks, gas phase transitions and gas saturation of low-permeable sections of reservoirs; gas dissolution in invading reservoir water and its convective-diffusion entrainment by displaced water into the aquifer region of the reservoir are also considered. Using the example of a UGS created in an aquifer, the system of geological and commercial monitoring of a subsurface area within a mining branch in conditions of vertical interplastic flows of free gas is considered. It is shown that the implemented system of observation and control wells allows for adequate monitoring of the gas storage facility and control of the tightness of UGS throughout the section above the storage facility. The following components of reservoir gas losses at the storage facility are considered: dissolved gas in residual water within the gas reservoir; gas adsorbed by rocks within the gas reservoir; dissolved gas diffused from the gas reservoir into the contact aquifer region of the reservoir; dissolved and free gas in the control horizons. Using a geological model of the formation, as well as the results of modeling the convective-diffusion transfer of dissolved gas into the aquifer region of the formation, the assessment of the components of reservoir gas losses in a direct way by their locations is given.
{"title":"Reservoir gas losses at UGS facilities in aquifers","authors":"Alexander A. Mikhailovsky","doi":"10.18599/grs.2022.3.15","DOIUrl":"https://doi.org/10.18599/grs.2022.3.15","url":null,"abstract":"Experience shows that in the process of creating and long-term cyclic operation of underground gas storage facilities (UGS) in reservoirs of aquifers, reservoir gas losses can occur. Losses can reach tens of percent of the injected volumes of gas into the reservoir and have a significant impact on the reliability and safety and efficiency of operation of UGS. In this regard, the issues of the organization of field control and methodology for assessing reservoir gas losses at UGS are relevant.\u0000\u0000The article proposes the structuring of the gas injected into the reservoir into possible reservoir components, taking into account the state of the gas phase and participation in filtration mass transfer processes. The main factors determining the formation of different reservoir components are given. The basic concepts are considered and the definition of reservoir gas losses at UGS in aquifers is given. The main features of one or another type of reservoir gas losses are shown.\u0000\u0000Reservoir losses from free gas currents from an artificial gas deposit, which can occur as a result of vertical leaks from the storage facility and lateral gas escapes through the reservoir beyond the trap, are briefly described. Formation losses associated with gas adsorption by rocks, gas phase transitions and gas saturation of low-permeable sections of reservoirs; gas dissolution in invading reservoir water and its convective-diffusion entrainment by displaced water into the aquifer region of the reservoir are also considered.\u0000\u0000Using the example of a UGS created in an aquifer, the system of geological and commercial monitoring of a subsurface area within a mining branch in conditions of vertical interplastic flows of free gas is considered. It is shown that the implemented system of observation and control wells allows for adequate monitoring of the gas storage facility and control of the tightness of UGS throughout the section above the storage facility.\u0000\u0000The following components of reservoir gas losses at the storage facility are considered: dissolved gas in residual water within the gas reservoir; gas adsorbed by rocks within the gas reservoir; dissolved gas diffused from the gas reservoir into the contact aquifer region of the reservoir; dissolved and free gas in the control horizons. Using a geological model of the formation, as well as the results of modeling the convective-diffusion transfer of dissolved gas into the aquifer region of the formation, the assessment of the components of reservoir gas losses in a direct way by their locations is given.","PeriodicalId":43752,"journal":{"name":"Georesursy","volume":null,"pages":null},"PeriodicalIF":0.8,"publicationDate":"2022-09-30","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"47407911","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}
N. I. Korobova, E. Karnyushina, Nadezhda S. Shevchuk, S. Frolov, E. Bakay, G. Akhmanov
At present time several dozen hydrocarbon fields are known in the Vendian-Cambrian complex of the Lena-Tunguska basin, which clearly does not exhaust its potential. The significant stratigraphic interval of the complex, its thickness (up to 3000 m), favorable properties laid down in sedimentogenesis, namely the presence of source, reservoir and seal deposits, allow us to hope for the discovery of new oil and gas deposits. Sedimentological studies of the Vendian-Cambrian complex, carried out using a network of key lithological sections and outcrops, made it possible to create a series of schematic maps of sedimentation environments on a scale of 1:5000000 for six time intervals (Nepa, Tira, Danilovo, Tommotian-Early Atdabanian, Botomian-Amgaian and Late Cambrian). The evolution of sedimentation of the Vendian-Cambrian complex is considered, as well as an assessment of its oil and gas properties, which are primarily associated with various sedimentation environments.
{"title":"Geology aspects, sedimentation environments and oil-and-gas bearing capacity of Vendian and Cambrian deposits of Lena-Tunguska basin","authors":"N. I. Korobova, E. Karnyushina, Nadezhda S. Shevchuk, S. Frolov, E. Bakay, G. Akhmanov","doi":"10.18599/grs.2022.2.9","DOIUrl":"https://doi.org/10.18599/grs.2022.2.9","url":null,"abstract":"At present time several dozen hydrocarbon fields are known in the Vendian-Cambrian complex of the Lena-Tunguska basin, which clearly does not exhaust its potential. The significant stratigraphic interval of the complex, its thickness (up to 3000 m), favorable properties laid down in sedimentogenesis, namely the presence of source, reservoir and seal deposits, allow us to hope for the discovery of new oil and gas deposits. Sedimentological studies of the Vendian-Cambrian complex, carried out using a network of key lithological sections and outcrops, made it possible to create a series of schematic maps of sedimentation environments on a scale of 1:5000000 for six time intervals (Nepa, Tira, Danilovo, Tommotian-Early Atdabanian, Botomian-Amgaian and Late Cambrian). The evolution of sedimentation of the Vendian-Cambrian complex is considered, as well as an assessment of its oil and gas properties, which are primarily associated with various sedimentation environments.","PeriodicalId":43752,"journal":{"name":"Georesursy","volume":null,"pages":null},"PeriodicalIF":0.8,"publicationDate":"2022-05-16","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"45325443","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}
For more than 30 years N.B. Vassoevich had devoted to the development of the theoretical foundations of petroleum geology and geochemistry. In addition, Nikolay Bronislavovich was always interested in the original meaning of the words that he used as scientific terms. Under the term, he understood a lexical unit that serves to designate a scientific concept, performing the function of naming in relation to the object reflected in this concept. According to N.B. Vassoevich, the ambiguity of many geological “terms” is the cause of most heated scientific discussions. Therefore, the ordering of scientific terminology and nomenclature N.B. Vassoevich included among the most important scientific tasks.
{"title":"Issues of oil terminology in the studies of N.B. Vassoevich","authors":"Andrey L. Vassoevich","doi":"10.18599/grs.2022.2.2","DOIUrl":"https://doi.org/10.18599/grs.2022.2.2","url":null,"abstract":"For more than 30 years N.B. Vassoevich had devoted to the development of the theoretical foundations of petroleum geology and geochemistry. In addition, Nikolay Bronislavovich was always interested in the original meaning of the words that he used as scientific terms. Under the term, he understood a lexical unit that serves to designate a scientific concept, performing the function of naming in relation to the object reflected in this concept. According to N.B. Vassoevich, the ambiguity of many geological “terms” is the cause of most heated scientific discussions. Therefore, the ordering of scientific terminology and nomenclature N.B. Vassoevich included among the most important scientific tasks.","PeriodicalId":43752,"journal":{"name":"Georesursy","volume":null,"pages":null},"PeriodicalIF":0.8,"publicationDate":"2022-05-16","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"47164378","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}
T. G. Isakova, Anna S. Persidskaya, O. V. Khotylev, J. A. Kotochkova, A. D. Egorova, T. Dyakonova, A. S. Mozgovoy, V. Churkina, S. V. Kozakov, N. V. Kozhevnikova, R. Z. Livaev, V. Druchin, N. Belov, G. Kalmykov
The article considers facies analysis and the application of its results for the typification of rocks of the Tyumen Formation. The aim of the article is to create algorithms for the differentiated interpretation of geophysical studies of well log data of the Tyumen formation based on a detailed study of the core. Based on core studies, as well as geological, geophysical data and field information on the Tyumen Formation of some deposits in Western Siberia, the main groups of facies were identified, reflecting the hydrodynamic activity of sedimentation conditions: group 1 – high-dynamic conditions, group 2 – transitional conditions, group 3 – low-dynamic conditions. On the basis of this typification, petrophysical models of the deposits of the Tyumen Formation were created: petrophysical functions were built with differentiation by facies zones, boundary values of petrophysical parameters were obtained to identify reservoirs of different sedimentation conditions, algorithms for differentiated interpretation of well log data were proposed, also based on test results and field geophysical survey, differences in field characteristics for different sedimentation conditions were revealed, linear oil reserves were calculated using a new petrophysical model. The development and implementation of an integrated approach to the interpretation of well log data, taking into account the conditions of sedimentation, make it possible to increase the reliability of determining the properties of the reservoirs of the Tyumen Formation, and the efficiency of calculating the oil reserves.
{"title":"Typification of the deposits of the Tyumen Formation according to the degree of hydrodynamic conditions of sedimentation to create a petrophysical model and differentiated interpretation of well log data","authors":"T. G. Isakova, Anna S. Persidskaya, O. V. Khotylev, J. A. Kotochkova, A. D. Egorova, T. Dyakonova, A. S. Mozgovoy, V. Churkina, S. V. Kozakov, N. V. Kozhevnikova, R. Z. Livaev, V. Druchin, N. Belov, G. Kalmykov","doi":"10.18599/grs.2022.2.16","DOIUrl":"https://doi.org/10.18599/grs.2022.2.16","url":null,"abstract":"The article considers facies analysis and the application of its results for the typification of rocks of the Tyumen Formation. The aim of the article is to create algorithms for the differentiated interpretation of geophysical studies of well log data of the Tyumen formation based on a detailed study of the core.\u0000\u0000Based on core studies, as well as geological, geophysical data and field information on the Tyumen Formation of some deposits in Western Siberia, the main groups of facies were identified, reflecting the hydrodynamic activity of sedimentation conditions: group 1 – high-dynamic conditions, group 2 – transitional conditions, group 3 – low-dynamic conditions.\u0000\u0000On the basis of this typification, petrophysical models of the deposits of the Tyumen Formation were created: petrophysical functions were built with differentiation by facies zones, boundary values of petrophysical parameters were obtained to identify reservoirs of different sedimentation conditions, algorithms for differentiated interpretation of well log data were proposed, also based on test results and field geophysical survey, differences in field characteristics for different sedimentation conditions were revealed, linear oil reserves were calculated using a new petrophysical model.\u0000\u0000The development and implementation of an integrated approach to the interpretation of well log data, taking into account the conditions of sedimentation, make it possible to increase the reliability of determining the properties of the reservoirs of the Tyumen Formation, and the efficiency of calculating the oil reserves.","PeriodicalId":43752,"journal":{"name":"Georesursy","volume":null,"pages":null},"PeriodicalIF":0.8,"publicationDate":"2022-05-16","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"42589469","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}
Two-dimensional basin modeling was carried out along regional profiles (sublatitudinal and submeridional). When modeling, the software package of Lomonosov Moscow State University was used. The models take into account the features of geological structure of the Riphean deposits of the Kama-Belsky aulacogene northern part and the Vendian-Paleozoic complexes that overlay it. Recent data on the features of region geology (taking into account the assessment of thickness of the eroded Riphean-Vendian deposits), as well as on the features of organic matter of the ancient Precambrian deposits were used. As a result, boundaries of the oil and gas window and geotemperature gradient were revealed. Main type of deposits according to the results of 2D basin modeling is anticlinal (reservoir-arch) and stratigraphically shielded. Data obtained testify, firstly, to two stages of hydrocarbon generation by the Riphean-Vendian oil source strata (the first stage occurs at the end of the Early Riphean, the second – at the Vendian-end of the Late Carboniferous), and, secondly, to prevailing share of the Riphean-Vendian complex of source strata in the formation of oil and gas content of sedimentary cover within the marginal zones of the Kama-Belsky aulacogen northern-northwestern part of the Volga-Ural oil and gas basin. Generation of hydrocarbons by source strata of the Riphean-Vendian and Late Devonian-Early Carboniferous continues to this day, however, it has rather an «inertial character».
{"title":"The role of proterozoic sediments in the formation of oil and gas content in the northern part of the Volga-Ural oil and gas basin (based on the results of basin modeling)","authors":"D. Kozhanov, M. Bolshakova, I. Khopta","doi":"10.18599/grs.2022.2.12","DOIUrl":"https://doi.org/10.18599/grs.2022.2.12","url":null,"abstract":"Two-dimensional basin modeling was carried out along regional profiles (sublatitudinal and submeridional). When modeling, the software package of Lomonosov Moscow State University was used. The models take into account the features of geological structure of the Riphean deposits of the Kama-Belsky aulacogene northern part and the Vendian-Paleozoic complexes that overlay it. Recent data on the features of region geology (taking into account the assessment of thickness of the eroded Riphean-Vendian deposits), as well as on the features of organic matter of the ancient Precambrian deposits were used. As a result, boundaries of the oil and gas window and geotemperature gradient were revealed. Main type of deposits according to the results of 2D basin modeling is anticlinal (reservoir-arch) and stratigraphically shielded. Data obtained testify, firstly, to two stages of hydrocarbon generation by the Riphean-Vendian oil source strata (the first stage occurs at the end of the Early Riphean, the second – at the Vendian-end of the Late Carboniferous), and, secondly, to prevailing share of the Riphean-Vendian complex of source strata in the formation of oil and gas content of sedimentary cover within the marginal zones of the Kama-Belsky aulacogen northern-northwestern part of the Volga-Ural oil and gas basin. Generation of hydrocarbons by source strata of the Riphean-Vendian and Late Devonian-Early Carboniferous continues to this day, however, it has rather an «inertial character».","PeriodicalId":43752,"journal":{"name":"Georesursy","volume":null,"pages":null},"PeriodicalIF":0.8,"publicationDate":"2022-05-16","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"41950324","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}
N. Yandarbiev, R. Sachsenhofer, A. Stepanov, D. N. Yandarbieva
The paper considers geochemical data on the biomarker composition of oils from the fields of the Terek-Caspian oil and gas basin. Samples of oils from the fields of the main oil and gas bearing regions of the Eastern Ciscaucasia – Terek-Sunzha zone, Prikumsky swell, Piedmont Dagestan and the Middle Caspian Sea were studied. To determine the “geochemical” age of oils, the ratios of regular steranes in saturated oil fractions were analyzed. It was found that the value of the biomarker parameter St28/St29, which determines the geological age of the original organic matter for oils, varies widely – 0.36–1.47. The most “ancient” age (Devonian-Carboniferous) was determined for the oils of the Prikumsky swell and the water area of the Middle Caspian; in the Terek-Sunzha zone and Piedmont Dagestan, an increase in the proportion of St28 sterane is recorded in oils, which indicates a younger generation age (up to the Paleogene). The data obtained can be used to clarify the history of the formation of hydrocarbon accumulations in this region.
{"title":"About “Paleozoic roots” of the oils of the Eastern Ciscaucasia","authors":"N. Yandarbiev, R. Sachsenhofer, A. Stepanov, D. N. Yandarbieva","doi":"10.18599/grs.2022.2.17","DOIUrl":"https://doi.org/10.18599/grs.2022.2.17","url":null,"abstract":"The paper considers geochemical data on the biomarker composition of oils from the fields of the Terek-Caspian oil and gas basin. Samples of oils from the fields of the main oil and gas bearing regions of the Eastern Ciscaucasia – Terek-Sunzha zone, Prikumsky swell, Piedmont Dagestan and the Middle Caspian Sea were studied. To determine the “geochemical” age of oils, the ratios of regular steranes in saturated oil fractions were analyzed. It was found that the value of the biomarker parameter St28/St29, which determines the geological age of the original organic matter for oils, varies widely – 0.36–1.47. The most “ancient” age (Devonian-Carboniferous) was determined for the oils of the Prikumsky swell and the water area of the Middle Caspian; in the Terek-Sunzha zone and Piedmont Dagestan, an increase in the proportion of St28 sterane is recorded in oils, which indicates a younger generation age (up to the Paleogene). The data obtained can be used to clarify the history of the formation of hydrocarbon accumulations in this region.","PeriodicalId":43752,"journal":{"name":"Georesursy","volume":null,"pages":null},"PeriodicalIF":0.8,"publicationDate":"2022-05-16","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"41854637","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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