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Isotopic studies are currently among the most prioritized methods for addressing critical challenges in petroleum geology, particularly in determining the nature and sources of organic matter. This paper briefly presents the results of utilizing isotopic markers in addressing issues related to: stratigraphic correlation, geochemical characterization of organic matter, and fluid dynamic reconstruction. The isotopic effects (δ18О, δ13С) observed in the study of Meso-Cenozoic sections in Crimea and the Western Pre-Caucasus have enabled the identification of global events, facilitating detailed stratigraphic correlation. Analysis of the isotopic-geochemical characteristics (δ13С) of fluids from sedimentary formations of varying ages allowed for the determination of formation conditions, the genesis of organic matter, and its geochemical classification for a group of fields at Kamennaya Vershina (Western Siberia). By integrating geochemical vertical zonality, evidence of hydrocarbon mixing from different origins, and the detection of localized thermal anomalies based on isotopic parameters, a comprehensive fluid dynamic model was developed, incorporating previously acquired geological and geophysical data.

There is no consensus on the role of different source rocks (SRs) in the formation of the Krasnoleninskoe field. The main Upper Jurassic-Early Cretaceous SR of Western Siberia is represented on the Krasnoleninsky arch by the Tutleim formation (fm) (J3tt–K1v). It is overlain by argillaceous rocks of the Frolov fm (K1v–K1a), underlain by the Abalak (J2cl–J3km), Tyumen (J2a-b), Sherkalin (J1 ) formations and folded pre-Jurassic basement. All these formations potentially contain SR layers. The purpose of the article is to determine the sources of oil in the Krasnoleninskoe field by comparing oils with SRs and to determine of the history of oil composition formation. Based on a review of known geochemical parameters and the results of statistical analysis new molecular parameters for determining the type of organic matter (OM) and its maturity are proposed. A secondary processes of the oils of the Vikulov fm of the Kamennaya crest has been established, which is associated with the migration of hydrocarbons from the Vikulov fm to the overlying deposits. It is shown that the oils of the Vikulov fm of Kamennaya crest were formed from the SR, which was at the MC2 substage during the generation of hydrocarbons, and the oils of the Jurassic and pre-Jurassic deposits were formed on the end of MC2 -beginning of MC3 substages. It was determined that the oils of Kamennaya crest have aquatic initial OM, aquatic OM was found in the Tutleim and Tyumen SRs. According to the criteria of OM type and its maturity, the source of Kamennaya crest oils cannot be determined; therefore, genetic features of the difference between the aquatic OM of the Tyumen and Tutleim formations were found. These features made it possible to estimate the source of oils for different parts of the Krasnoleninskoe field: for Kamennaya crest the Tutleim fm, for the Talinskaya area the Tyumen fm, for the Em-Egovskaya area, the Tyumen and Tutleim formations. Estimation of the contribution of the Sherkalin and Abalak SRs to the formation of hydrocarbon accumulations is beyond the scope of current work.

In the context of the current trend, today we are focused on low-carbon energy, so the question of carbon dioxide utilization is very important. Underground storage of carbon dioxide is an important part of carbon capture and storage (CCS) projects and a key technology to reduce emissions of carbon dioxide to the atmosphere. There are currently many carbon dioxide capture projects around the world, but each project has its own specifics. The article discusses the features of carbon dioxide capture in natural geological reservoirs and the principles of carbon dioxide retention in them. An example of some Carbon Capture in a natural geological reservoirs projects are given. The choice of a natural reservoir, the development of a technology for its identification and justification criteria are of key importance for the environmentally sustainable capture of carbon dioxide.

Most classifications of reservoirs, seals and source rocks based on the ability of the rock to generate, accumulate and preserve hydrocarbons, and the genesis of rocks is not always taken into account. The article presents a ranking scheme for continental, coastal-marine and marine sedimentation environments that determine the genesis and properties of the basic criteria of petroleum potential – source rocks, reservoirs, seals and pinch-out traps.Rocks, which can consider as source rock, reservoirs and seals are formed in each depositional environment. However, their structure, mineral composition and distribution area will differ from each other depending on the sedimentary environment and conditions. A combination of elements of the hydrocarbon system formed, corresponding to the sedimentation environment and are characteristic for basins of various types. Continental environments are favorable for the formation of reservoirs and local seals, while the accumulation of source rocks limited by lacustrine, floodplain, and swamp facies. The coastal-marine environment is favorable for the formation of all the basic criteria of petroleum potential, and the transgressive-regressive cyclicity determines the interbedding of source rocks, reservoirs and seals in the section. The marine depositional environments are most favorable for the formation of regional seals and source rocks, including high-carbon formations.The proposed ranking scheme of sedimentary environments and the basic criteria of petroleum potential genetically related to them is applicable in system analysis and selection for analogues of petroleum system elements in sedimentary complexes formed in similar depositional environments.

The criteria of petroleum potential of a sedimentary basin are the features that characterize the evolution of a hydrocarbon system as a geological unit. There are basic and additional criteria of oil and gas potential. Without basic criteria, the functioning of the hydrocarbon system and consequent petroleum field formation is impossible. Additional criteria characterize qualitatively and quantitatively properties of the basic criteria. The properties of all basic criteria are ordered by genesis and summarized in a system that allows to quickly and accurately establish a relationship between them and classify them. The system can be used to select quantitative parameters for geological simulation of different scales, but also for automated applying for petroleum exploration and production. At the same time, the classification of basic criteria can be used at all stages of exploration. At the prospecting stage, when the type of sedimentary basin and the sedimentary conditions are recognized with some uncertainty, it is possible to predict the properties of source rocks, reservoirs, types of traps and seals. If all static basic criteria, such as source rock, reservoir, seal and trap, are available, it is possible to simulate the formation of petroleum fields, including generation, migration, accumulation and subsequent post-accumulation processes. At the stage of exploration and development, the classifications will help to verify the geological and hydrodynamic models of the field, taking into account the link to the regional and local structural plans and correctly identify the geological features of the study object and select the geological analogues.

The article presents the results of hydrocarbon compounds extracted from open pores and blocked by resinous-asphaltene compounds pores in the Tutleim formation rocks (a stratigraphic analogue of the Bazhenov formation) and the underlying Jurassic deposits on the territory of the Kamennaya crest of the Krasnoleninsky arch investigation. The aim of the work was both to study the possible migration of hydrocarbons along the section and area and to assess the variability of the bitumen composition in rocks relative to the structural plan of the area of interest, along the section, as well as unconventional reservoirs. It is shown that the structural features and the assumed additional heating of the rocks lead to variety in the hydrocarbons composition not only in open, but also in blocked pores, both through the area of Tutleim formation distribution and in different intervals of one well. It was established that in the sediments organic matter, which may slightly differ in nature within the formation, can accumulate, and this leads to some differences in the generation, accumulation and migration of hydrocarbon compounds processes. It is shown that the process of migration of hydrocarbons from the underlying sediments also affects the bitumen composition in the rocks of the Tutleim formation.

The idea of this work is to compare the results of geochemical and statistical analyzes in the study of organic matter in extracts of oil and gas source rock. The object of the study were the samples of oil and gas source rocks of the Tutleim and Tyumen Formations, as well as oil samples of the Vikulov Formation and Jurassic and pre-Jurassic deposits in the western part of the West Siberian basin.Among the methods of statistical analysis, the principal component method and the random forest method were used. A heat map of correlations was used as visualization tools.The principal component method helped us to reveal a clear difference between the organic matter of the Tutleim and Tyumen source rocks. The random forest method and the heat map made it possible not only to identify the distinctive geochemical properties for this strata, but also reveals the geological factors of their distinction. Thus, the organic matter of Tyumen source rock turned out to be more mature and it has relatively larger contribution of terrestrial organic matter compared to the Tutleim one. The same set of methods is applied to oil-source rock correlation. The oils of the Vikulov Formation obviously originate from the Tutleim source rock. Oils of Jurassic and pre-Jurassic reservoirs have a predominant contribution of the Tutleim source rock and some similarity (up to 30 %) with the Tyumen one. Oils from the Vikulov Formations are less mature than oils from the Jurassic and pre-Jurassic rocks. This may indicate the continued migration of hydrocarbons to Jurassic and pre-Jurassic deposits and the cessation of migration in the past to the overlying Aptian–Albian Vikulov Formation. Geochemical analysis also revealed the geochemical properties responsible for the maturity of source rocks and the type of organic matter. It confirmed the conclusions made on the basis of the application of methods of statistical analysis.

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 VendianPaleozoic 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».

The article presents the results of research on the influence of structural reconstructions on the hydrocarbon systems evaluation in the eastern part of the Yenisei-Khatanga trough. Based on seismic data interpretation and paleoprofiles construction, several stages of structural reconstructions in the geological evolution of the basin are established: at the Middle and Late Triassic boundary, Late Triassic and Jurassic boundary, in the Bathonian-Callovian time, TithonianValanginian time, in the Barremian-Aptian time, in the Aptian-Albian time, in the Cenomanian time, and powerful reconstructions in the Cenozoic era. Based on interpretation of geochemical information of the well-core and outcrops, the characterization of the type of organic matter, the amount of initial organic carbon, the oil and gas source potential for the Late Triassic, Lower Jurassic, Middle Jurassic, Upper Jurassic, Lower Cretaceous oil and gas source rocks is given. The results of exploration of the geological structure of the region, the geochemical features of oil and gas source rocks became the basis for building a 2D basin model, which made it possible not only to identify generation kitchen, migration routes and accumulation zones of hydrocarbon fluids, but also to estimate the start time of generation and emigration of hydrocarbons, as well as the moments of interruption of these processes during periods of uplifting of the territory. Changes of the structural plan transformed the configuration of the basin, which led, on the one hand, to the formation of areas where rich in organic matter interlayers accumulated, and, on the other hand, to the interruption of hydrocarbon systems evaluation, reconfiguration and even destruction of deposits.

Nowadays well logging curves are interpreted by geologists who preprocess the data and normalize the curves for this purpose. The preparation process can take a long time, especially when hundreds and thousands of wells are involved. This paper explores the applicability of Machine Learning methods to geology tasks, in particular the problem of lithology interpretation using well-logs, and also reveals the issue of the quality of such predictions in comparison with the interpretation of specialists. The authors of the article deployed three groups of Machine Learning algorithms: Random Forests, Gradient Boosting and Neural Networks, and also developed its own metric that takes into account the geological features of the study area and statistical proximity of lithotypes based on log curves values.As a result, it was proved that Machine Learning algorithms are able to predict lithology from a standard set of well logs without calibration on reference layers, which significantly saves time spent on preliminary preparation of curves.

The ancient Precambrian formations of Eastern Siberia include oil and gas source rock (SR) interlayers, but in most cases, they can’t be classified as high-carbon ones, because the actual organic carbon content in these strata is low and rarely exceeds 10%. This point effect the approach to the available geochemical data interpretation and the method of quality samples selection. The aim of the work was to determine methods for pyrolytic data verification and the oil and gas Lower Vendian SR quality assess, that based on the results of geochemical researches. It was identified, that before SR catagenetic transformation analyzation by the Tmax parameter and determining the OM type, samples with a low generation potential or with the migrated bitumen presence should be excluded from the consideration. The presence of secondary epigenetic bitumen also indicates the active HC fluids migration within the basin. After data verification, the SR properties were assessed. So lower Vendian SRs have OM with a satisfactory and high generation potential, second type and low maturity in most cases. The oil and gas window zones are located within large depressions and troughs. In addition, the local heating was noted in zones with a large number of faults, where the heating was conducted due to the intrusions introduction and the hydrothermal fluids action.

Riphean-Vendian Petroleum system of VolgaUral Basin (Northern part, Kama-Belsky aulakogen) main elements are described. Reservoirs and properties of them (porosity and permeability), source rocks are characterized geochemically by results of pyrolysis, extraction, gas chromatography. To understand the conditions of Volga-Ural Proterozoic petroleum system formation were analyzed lots of publications and collected huge dataset (regional geological data, seismic, well data, geochemical data and so on). Were made maps of Riphean-Vendian tectonics and location in North part of VolgaUral Basin. The main characteristics important for petroleum system formation and oil and gas prospects estimation were indicated.

To get properties and characteristics of oil and gas source rocks and for other geological aims, geologists analyzes core samples from wells and outcrop samples. But we should probably somehow correct geochemical source rock properties data we get on outcrop samples, because organic matter could change significantly due to oxidizing and weathering. This problem is very important but poorly developed in modern publications, so it attracted our interest and led to this investigation. Published information on the organic matter weathering which change it’s content and quality in sedimentary rocks is collected and summarized in this article. The changes of the kerogen (isolated from the mineral matrix) elemental composition during its long-term storage are presented.We compared the results we get in laboratory and results of other authors who dealt with natural changes of organic matter in outcrops. An attempt to interpret the results obtained from the point of view of hypergene changes in OM was made. Uncertainties that require further study and development are indicated. This work is the first step to better understanding of weathering effect on organic matter content and properties – question of great importance for making adequate oil and gas prospects estimations.This study continues the work of our foregoers and Teachers – geochemists of the Petroleum Geology Department of Lomonosov Moscow State University: N.B. Vassoevich, Yu.I. Korchagina, O.A. Radchenko, V.A. Uspensky, I.E. Leifman, A.N. Guseva, O.K. Bazhenova, T.A. Kiryukhina.

The article discusses the fundamental possibilities of using the results of geochemical and hydrogeochemical studies of organic matter, oils and waters in oil and gas geology, including for objects at the stage of development. It is shown that complex geochemical studies of oils and waters make it possible to get more correct conclusions about the presence or absence of fluid-dynamic connectivity of different horizons. Studies of organic matter and oils allow (by basin modeling instrument) to understand the contribution of different source rocks to formation of oils of different reservoirs. Hydrogeochemical studies of associated waters and waters used in the reservoir pressure maintenance system in a complex of works not only actively complements the knowledge about the presence or absence of fluid-dynamic connections between reservoirs and production objects, but also make it possible to predict, for example, salt deposition on equipment and in the reservoirs, and therefore allow you to prevent the possibility of unwanted salt deposition. The conclusions are based on the results of comprehensive geological and geochemical studies carried out by the authors for one of the deposits of the Krasnoleninsky arch of Western Siberia, which is at the development stage, as well as on the previous experience of the authors.

Identification of the source rock potential and distribution area is the most important stage of the basin analysis and oil, and gas reserves assessment. Based on analysis of the large geochemical and geological data base of the Petroleum geology department of the Lomonosov Moscow State University and integration of different-scale information (pyrolysis results and regional palaeogeographic maps), generation potential, distribution area and maturity of the main source rock intervals of the Barents-Kara Sea shelf are reconstructed. These source rocks wide distribute on the Barents-Kara Sea shelf and are characterized by lateral variability of generation potential and type of organic matter depending on paleogeography. During regional transgressions in Late Devonian, Early Permian, Middle Triassic and Late Jurassic, deposited source rocks with marine organic matter and excellent generation potential. However in the regression periods, during the short-term transgressions, formed Lower Carboniferous, Upper Permian, Induan, Olenekian and Late Triassic source rocks with mixed and terrestrial organic matter and good potential.Upper Devonian shales contain up to 20.6% (average – 3%) of marine organic matter, have an excellent potential and is predicted on the Eastern-Barents megabasin. Upper Devonian source rocks are in the oil window on the steps, platforms and monoclines, while are overmature in the basins. Lower Permian shale-carbonate source rock is enriched with marine organic matter (up to 4%, average – 1.4%) and has a good end excellent potential. Lower Permian source rocks distribute over the entire Barents shelf and also in the NorthKara basin (Akhmatov Fm). These rocks enter the gas window in the Barents Sea shelf, the oil window on the highs and platforms and are immature in the North-Kara basin. Middle Triassic shales contain up to 11.2% of organic matter, there is a significant lateral variability of the features: an excellent generation potential and marine organic matter on the western Barents Sea and poor potential and terrestrial organic matter in the eastern Barents Sea. Middle Triassic source rocks are in the oil window; in the depocenters it generates gas. Upper Jurassic black shales are enriched with marine and mixed organic matter (up to 27,9%, average – 7.3%) and have an excellent potential. On the most Barents-Kara Sea shelf, Upper Jurassic source rock are immature, but are in the oil window in the South-Kara basin and in the deepest parts of the Barents Sea shelf.

Based on comprehensive analysis of geological, geochemical, and paleotectonic settings, the conditions for the formation of Neoproterozoic oil and gas source rocks of the Earth are analyzed. A brief review of oil and gas fields in Eastern Siberia, China, the Middle East, Africa, and Australia is given, with Riphean and Vendian terrigenous and carbonate source rock. An overview of the oil and gas bearing basins of the world and a stratigraphic reference of the Neoproterozoic strata discovered within them, containing proven and suspected oil and gas source rocks, are given.The formation of Neoproterozoic oil and gas source rocks is analyzed in a complex way: simultaneously from the point of view of paleotectonics, paleogeographic and paleoclimatic conditions, paleobiological diversity and geochemical conditions. As part of paleotectonic analysis, the results of plate tectonic reconstructions for the Neoproterozoic stage are presented in accordance with one of the most currently relevant geodynamic models. Paleogeographic events and paleoclimatic conditions are described in the context of the specifics of the formation settings of carbonate-terrigenous oil and gas source rocks. In particular, the reasons for the accumulation of sediments enriched with organic carbon in the interglacial epochs of the Neoproterozoic and possible mechanisms for maintaining conditions favorable for their accumulation are considered. The conditions for the accumulation of oil and gas source rocks are also linked to global paleobiological pre-Phanerozoic events, and the analysis of the geochemical data of rocks makes it possible to characterize and correlate Neoproterozoic oil and gas source rocks on a global scale. On the basis of such a comprehensive assessment, a conclusion was made about fundamentally similar geological conditions for the formation of Neoproterozoic oil and gas source rocks in oil and gas bearing basins.

The article is devoted to the variation of generation potential of the Lower-Middle Jurassic organic matter in the Karabash area (South-Western part of the West Siberian basin) depending on facies and sedimentary cyclisity. Based on geochemical and lithological core studies, specific geochemical features of organic matter established for main facies groups of Early-Middle Jurassic in the study area. The best generation potential inherent in deposits of swamps, swampy floodplains and tidal plains. These facies groups characterized by predominance of the continental organic matter and considered to gas source rocks. However, macerals composition, kinetic spectra and biomarker analysis show the presence also of marine organic matter. Some facies groups, such as flooded swamps and swampy floodplains has potential to generate hydrocarbons due to preservation of liptinites with high hydrogen index. Cyclic analysis with basics of sequence stratigraphy of the continental deposits allow tracing the correlation between generation potential and relative sea level changes.

The article considers the geochemical characteristics of the rocks of the Bazhenov and Nizhnetutleim formations in the southwestern part of the West Siberian oil and gas province, or rather in the territory of the Karabash search zone. The work was carried out on the basis of the core material study of the section of 29 wells within the Karabash zone by pyrolysis on the Rock-Eval 6. The regularities of the distribution of organic carbon concentrations (Сorg, %) on the studied territory were obtained. With the help of data mapping, it was established that the maximum concentrations of organic matter are timed to the southern regions of the zone (the most submerged parts of the paleobasin). The assessment of the catagenesis degree (degree of maturity) of organic matter of the Bazhenov horizon in the study area was carried out. Level maturity of organic matter of rocks is specified in the parameter Tmax Rock-Eval. Within the study area it’s increasing from South to North, from graduation PK3 (according to the scale of N.B. Vassoevich) (Tmax < 430 0 С) in the area of wells Verkhnetyumskaya 34 to MK2 (Tmax 440–445 0 С) in the area of Molodezhnaya and the Zapadno-Frolovskaya square. The resulting catagenetic zoning determined the boundaries of the generation kitchen for this territory. Generation scale for the Upper Jurassic source rocks was estimated, taking into account its lithofacial structure.

The Bazhenov formation is a source of unconventional hydrocarbons and a complex object of study. Oil accumulations in the Bazhenov formation are not controlled by the structural factor. In this article, based on the results of basin modeling, the priority geological and geochemical parameters that affect the distribution of unconventional hydrocarbon accumulations in the sediments of the Bazhenov formation are identified. The article describes the initial geological, lithological, petrophysical, geochemical and thermal parameters necessary for the analysis of the hydrocarbon system of the Bazhenov formation. The paper presents the results of calculating a 2D model of a regional sublatitudinal profile of the West Siberian basin. The calibration of geological and thermal models based on the data on reservoir temperatures and pressures, as well as on the vitrinite reflectance (Ro) and Tmax pyrolysis is illustrated. The analysis of the sensitivity of the model to changes in the kinetic spectrum of kerogen destruction of the Bazhenov formation has been carried out. Criteria for localization of the most promising areas of the Bazhenov shale formation are proposed. On the basis of the work done, it was shown that the basin modeling tool in combination with the results of geological and geochemical studies allows us to distinguish promising areas within bituminous formations. The key parameters are maturity of organic matter, the amount of generation and adsorption of hydrocarbons, as well as overpressure zones.

The article provides an analysis of the variability of the composition of hydrocarbon fluids from the Bovanenkovo field (Yamal, Western Siberia) in order to better understand the geological processes that led to the formation of this field and the reformation of the composition of fluids in the layers of this field. It is shown that geochemical information on the composition and properties of oil, condensate and gas allows to “reconstruct” the geological stages of the formation of deposits in their modern form. The data on the properties of fluids, group and molecular composition of the light and middle parts of oils and condensates of various layers are given. Differences in the composition of hydrocarbons from different reservoirs of the field, the relationship of the composition of fluids with oil deposits and superimposed geological reorganizations in the Yamal area already formed were demonstrated. In terms of composition, three groups of oils were identified: residual, whose composition was formed as a result of the migration of relatively low-molecular components, light oils with a high content of paraffins and light (low-paraffinic) oils and condensates. It is shown that differences in the composition of oils are due both to the composition of the original organic matter for them and to migration processes after the formation of accumulations of hydrocarbon fluids.

Prospects for the growth of hydrocarbon (HC) reserves in the Timan-Pechora basin are associated with poorly explored areas, which include the Korotaikha Depression, which is a very difficult region for oil and gas exploration. Analysis and reinterpretation of both old and new seismic data made it possible to identify a number of anticlinal structures within the region, as well as to identify possible lithological HC traps, such as reefing bodies of late Devonian-Early Carboniferous age and delta sand formations of the Permian-Triassic age. The wide stratigraphic range of the sedimentary cover makes it possible to select several hydrocarbon systems in the basin of the Korotaikha Depression. Basin modeling has shown that there are all conditions for НС generation and accumulation in the Korotaikha Basin. Based on the results of the simulation, Korotaikha Basin should be considered as a potentially promising oil and gas area, where the main oil and gas accumulations are located in the side parts of the basin, and also within the inversion highs and saddles. The total booked geological resources of hydrocarbons may amount to about 1.7 billion tons standard fuel. Korotaikha Depression and its aquatorial continuation can be referred to the category of major oil-gas search regions.

The Domanic deposits of the Volga-Ural oil and gas basin are a high-carbon thin-bedded formation capable of both producing hydrocarbons with its own oil and gas bearing strata and concentrating them in separate reservoirs and zones (Stoupakova et al., 2015). Formation of the Domanic deposits occurred in a relatively deep basin, during the filling of which a variety of sedimentation environments arose from relatively deep sea to shallow-marine. The peculiarity of the formation conditions of high-carbon strata is the increased content of organic matter, carbonate material and free silica, the source of which could be hydrotherms or volcanogenic products, creating a special gas regime of the Earth’s atmosphere in the late Devonian. Evaluation of the generation potential of the Domanic formation showed that siliceous-carbonate and carbonate-siliceous rocks enriched with marine algal organic matter have a high potential. The greatest prospects of oil bearing are the deflections formed on the site of the avlakogen and their slopes, where deposits, rich in organic matter, were formed practically throughout the late Devonian-Tournaisian. High prospects have slopes of uplifts or sides of reef bodies. Such incisions are distributed on the sides of troughs of uncompensated immersion and the lower parts of uplift slopes adjacent to them. In the domanonicoid deposits, in which the carbonate material predominates, the high-carbon intervals developed along the biohermic structures.

Deep trough lie at the base of the sedimentary basins of the Arctic, which for a long geological time remained the epicenter of the immersion and the area of accumulation of large sedimentation strata, often exceeding 10-15 kilometers. Deep troughs extend long distances from the basin to the basin. In their limits, the deposition occurred of both the ancient Paleozoic basins and the younger Meso-Cenozoic basins. The main sedimentary material was transported along the immersion areas;centers of oil and gas generation were formed. The width of such trough is 100-200 km, and the length reaches 1000 km or more. Deep faults along the troughs often exhibited shear deformations, and at the boundary of the restructuring from one basin to another, fold-thrust deformations occurred. As a result, under the young sedimentary cover, more ancient fold-thrust structures are traced, stretched often along the axis of deflection.At all stages of basin development, potential oil and gas deposits were built, which generated hydrocarbons. The features of the tectonic structure of the basins and the nature of hydrocarbons migration make it possible to forecast the search for new accumulations of oil and gas. In the Paleozoic basins, the search should focus on border structures, stratigraphically and tectonically limited traps associated with stratigraphic non-conformities and the emergence of ancient rocks beneath the erosion surface. In the Mesozoic basins, the traps are often associated with strata filling theterrigenous sediments, where lithological traps are widespread both in various debris cones, and in the areas of Mesozoic rocks adjacent to older sediments. In the Cenozoic basins of the eastern sector of the Russian Arctic region, the search for hydrocarbons should be conducted at large anticlinal uplifts.

Domanic Upper Devonian deposits of the Timan-Pechora petroleum province are the subject of growing scientific and practical interest from the time of its discovery (late 19th century). And, despite the considerable knowledge database on Domanic organic matter have accumulated geochemists, it still requires more detailed study. This article presents the geochemical characteristics of organic matter of Timan-Pechora Domanic source rock using Rock Eval pyrolysis and the kinetic spectra of kerogen decomposition of sedimentary deposits from different parts of the Timan-Pechora basin. The variety of Domanic kinetics by deep strata and by area of the Timan-Pechora basin were analyzed. Dependence of kinetics from sedimentation conditions is shown. Four regional (sublatitudinal and submeridional) 2D basin models were created using of geochemical results. The results of petroleum basin modelling are performed. The sensitivity study of basin models to the kinetic spectrum change was made. It is shown that use of measured Domanic kinetics instead of published in software kinetics significantly affects basin modelling results. Were estimated the volume of generated by Domanic source rock hydrocarbons with use of different kinetics (published and measured). The difference in Domanic generation between these two scenarios is about 70 Bt of oil.