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.

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.

An overview of possible transformations of logistic schemes for the export of mineral raw materials mined in the Arctic zone of the Russian Federation is presented. The existing system of transportation of mineral raw materials by sea, rail, inland water, road and air transport is considered. The description of mineral resource centers forming the cargo base of the Arctic transport system is given; their typification by types of transport for the export of products is given. A change in logistics schemes in connection with access to new markets in the changed geopolitical conditions was considered. The need for changes does not apply to rail, inland water, road and aviation transport, which provide mainly domestic transportation. Major changes affect pipeline and maritime transport. It was concluded that it is necessary to create liquefied natural gas production facilities at the exit points to the coast of the poorly devoured seas of main gas pipelines in order to monetize pipeline gas and expand the throughput capacity of main oil pipelines suitable for port oil loading terminals of the Baltic and Black Seas. The conditions for delivery to Asian oil export markets by sea have deteriorated due to the increase in the duration of circular flights and the cost of tanker freight. In addition, the possibility of an increase in the cargo traffic of the oil export to the Asian market in the Northern Sea Route was questioned due to the lack of a high deadweight cargo fleet and the required Arctic ice classes. The proposal on the need to revise strategic planning documents adopted in other political and economic conditions based on the current realities is justified.

The geological structure and the petroleum potential of the western part of the Russian Arctic shelf are still matter for disputes, especially due to the absence of deep drilling and scarce data. One of the key problems in assessing the petroleum potential of the North Kara Sea Basin and the adjacent North Barents Sea Basin is the lack of a proven stratigraphic model of the sedimentary cover.
The article presents a model of the structure of the sedimentary cover of the northern part of the Barents-Kara Sea region based on the analysis of the regional seismic data and comparison with outcrop sections of the archipelagos and adjacent land. The structure of the archipelagos is determined by tectonic events and rearrangements, which also reflect on the structure of the offshore sedimentary basins. In the structure of the northern part of the Barents-Kara Sea region, three large structures can be distinguished: North Barents Sea Basin, East Barents Steps, and North Kara Sea Basin. The East Barents Steps formed during Baikal orogeny and in the Riphean-Early Paleozoic time were uplifted, and separated the North Barents Sea and North Kara Sea basins.
The North Kara Sea Basin was probably formed in the Riphean and subsided in the Early Paleozoic, while the section of the North Barents Sea Basin is composed of a thick of Upper Paleozoic-Mesozoic sequence. In the Permian-Triassic time, the western slope of the East Barents Uplift was involved in the intensive subsidence of the North Barents Sea Basin and transformed to the steps, while the Lower Paleozoic succession were buried under a thick Permian-Triassic sequence.
In the sedimentary cover of the northern part of the Barents-Kara shelf, four promising petroleum plays can be distinguished: pre-Upper Devonian, Upper Devonian-Lower Carboniferous, Permian-Triassic, and Jurassic-Cretaceous. Pre-Upper Devonian promising petroleum complex within the study area are distinguished only in the North Kara Sea Basin, and hydrocarbon systems within it can be similar to hydrocarbon systems in the basins of the ancient platforms.

The active development of the Crimean region requires the provision of an independent energy system. Currently, there are 36 hydrocarbon fields in Crimea: 12 with natural gas, 9 with oil, 4 with oil and gas, 2 with oil and gascondensate and 9 gascondensate fields (according to www. mygeomap.ru portal by February 10, 2023). Despite the fact that the vast majority of fields are small and some of them werealready under the development it is necessary to consider their potential and production possibility at least for selling products on the domestic market within Crimea peninsula. In the second half of the last century, extensive exploration work was almost completely stopped because small deposits in the drilled structures have been found. Most of the traps of the Mezocenozoic section are complicated bythe faults. The possibility of discovering unexplored yet hydrocarbon resources especially in the lower stratigraphic complexes can be solved due to modern technologies distribution in the area. The contribution of deeper Permian-Triassic and Jurassic complexesto of modern hydrocarbon accumulations formation is poore evaluated and need to be analyzed in more details. Proper setting of geological exploration tasks and conducting modern regional and local seismic surveys will significantly increase the possibility of discovering new hydrocarbon deposits.

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.

Authors used the paleogeographic approach to identify the different facies generation potential, mark out the areas with the highest organic matter and its types, analyse the reservoir quality for oil and gas potential assessment of the Pre-Caucasus basin Khadum formation. The greatest prospects in the Western and Central parts of the basin characterized by terrestrial and partly mixed organic matter types and are associated with the facies of the Sarpinsk-Armavir channel where discharge currents from the Volga-Don basin occurred. The same organic matter types can be related to clastic fans drawn from the north. In the Eastern part the main prospects are associated with unconventional black shale reservoirs with the predominantly aquatic organic matter, isolated on the top and base by the thick series of seal rock.

Both sedimentological factors and secondary processes of lithogenesis influenced the formation of porosity and permeability properties of the reservoir rocks of the Vikulov suite of the Krasnoleninskoe field. The former includes the conditions of sedimentation of the deposits of the Vikulov suite, which at the initial stages of its formation were controlled by the development of a system of incised river valleys, the stages of filling of which, like their composition, have their own characteristics. Also, various genetic types of deposits were formed here. The formation of the upper part of the Vikulov suite took place in a shallow-marine setting, in conditions of storm and wave shallow water, which affected the thin-layered structure of the VK1-3 reservoir. On the other hand, in the sections of a number of wells, dense interlayers are noted, the formation of which is associated with both sedimentation and superimposed processes in lithogenesis, including the formation of hydrocarbon deposits. Therefore, the prediction of the distribution of productive reservoir rocks is the main task when creating a petrophysical model of the field, and to solve this problem, the methods of lithofacies and staged core analysis are used in the work.

The article discusses the structure and formation conditions of the domanicoid high-carbon formation (VUF) within the central and southeastern parts of the Volga-Ural basin. The presented results of the analysis of the structure, conditions of formation and oil and gas content of domanicoid deposits are a generalization of the accumulated knowledge obtained during the research of the authors in certain regions and areas. The regional geological model of the formation of the domanicoid complex was created based on the results of seismostratigraphic and cyclostratigraphic analyzes. In the structure of the Middle Frasnian – Tournaisian domanicoid deposits, three different areas are distinguished, differing in composition, structure, thickness, and formation conditions – the carbonate platform, the intrashelf depression and its slopes. The revealed cyclicity in the structure of the complex showed that the section consists of 4 large cyclites, the accumulation of which occurred at the stage of changes in the relative sea level. An analysis of the material composition of the deposits made it possible to identify various sedimentation environments and their characteristic strata, which unite lithological units, within each large cyclite. Geochemical and petrophysical studies of the rocks of the domanicoid VUF made it possible to assess the oil and gas potential, identify the intervals containing the largest amount of organic matter, and intervals of reservoir rocks in the context of the studied deposits.

The modern idea of the geological structure of oil deposits of the Nizhnechutinskoye field is presented. The uniqueness of the field lies in the shallow depths of productive deposits. The oil-saturated layer is 100 m. The shallow depths of productive formations led to low formation temperature and pressure. Under such conditions, oil is inactive, characterized by high viscosity, and dissolved gas is practically absent. The features of the formation of the sedimentary cover in the area of the field predetermined the block structure, while the rocks of the productive horizon are characterized by a complex system of vertical fractures, which greatly complicates the process of oil recovery. A distinctive feature of the studied section of the field is the presence of effusive rocks underlying the main productive stratum and overlapping the lower productive layer.
The article systematizes the results of field trial operation, which revealed a number of complicating factors, which is associated primarily with the uniqueness of the geological structure of the studied deposits. Despite the solid history of studying the Nizhnechutinskoye field, which has almost 300 years, given the negligible depth of productive deposits, oil production at this field still remains a difficult task.

The basis for solving almost all geological problems are models, which are a reflection of the structure of deposits. This places high demands on the detail and accuracy of the models.
One of the most important parameters in the calculation of reserves is the oil saturation factor, observed in most cases using Dakhnov-Archie models. Despite the widespread use of this technique, it has a number of significant limitations. An alternative way to assess oil saturation in this case is to use a capillary model obtained from the results of capillary measurements of the core.
The capillary model is a continuous multidimensional function of the dependence of the water saturation coefficient on the free water level, porosity and permeability. A well-compiled capillary model is a reflection of the geological model of the reservoir – with information about the water saturation of the reservoirs by the altitude of the structure, the levels of fluid contacts, fluid densities, surface and reservoir properties.
This paper discusses the capabilities of capillary models, which are widely used in three-dimensional modeling of the degree of saturation of the interwell space, the calculation of the volume of oil-saturated rocks, geological reserves of hydrocarbons, as well as dynamic characteristics in the construction of hydrodynamic models.

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) (J_3tt–K_1v). It is overlain by argillaceous rocks of the Frolov fm (K_1v–K_1a), underlain by the Abalak (J_2cl–J_3km), Tyumen (J_2a-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.

A comparative study of the Uralian Foreland in the Timan-Pechora and Volga Urals basins reveals considerable differences in structure and petroleum habitat. These differences were in large measure controlled by their geodynamic settings. A typical scenario of the continental marginal basin which subsequently was modified in the foredeep basin took place in the Timan-Pechora basin. The sedimentary fill of the basin is made up of the Phanerozoic deposits only. The principal oil source rock is provided by the prolific Domanik Suite broadly developed in is eastern part of the basin. The mature Domanik source rocks charged the majority of oil and gas fields of the Timan-Pechora Basin. In the Volga Urals basin the sedimentary fill includes two overlapping foredeep sequence – Riphean and Paleozoic, of which the Riphean one is much thicker. The Riphean depocenters were subjected to structural inversion during the docking of the Magnitogorsk island arc to the Uralian margin in the Middle Devonian-Frasnian. The inversion was accompanied by the thickening of the Riphean section due to the reactivation of the pre-existing Precambrian deformation and caused the regional uplift in the Southern Uralian Foreland. This uplift led to shifting of the Domanik troughs to the westerly outboard part of the Volga-Uralian Basin. The Domanik source rock remained immature over much of the Southern Uralian Foreland which is interpreted to be a result of the inversion of the Riphean depocenters and related regional uplift. It is proposed that the enormous clustering of large oil deposits in the Paleozoic section of the south-eastern part of the Volga Uralian Basin was to a much extent produced by the charging from the multi-kilometer thick Riphean section of the Southern Uralian Foreland.

Tonsteins, predominantly solid kaolinite clay interbeds, are widespread in the coals of the Kuznetsk Basin and usually contain idiomorphic zircon grains of magmatic origin in quantities suitable for uranium-lead (U-Pb) radiometric dating. For the first time, tonstein zircons from coal seam 78 of the Tailugan Formation (Fm) are dated by two methods: Laser Ablation Inductively Coupled Plasma Mass Spectrometry (LA-ICP-MS) and Chemical Abrasion Isotope-Dilution Thermal Ionization Mass Spectrometry (CA-ID-TIMS).
The CA-ID-TIMS datings of 257.0 ± 1.3 Ma and 256.6 ± 0.4 Ma determine the age of the lower boundary of the Tailugan Fm and the Tailuganian Regional Stage at 257.0 Ma. We estimate the duration of the Tailuganian to be around 4.22 million years. The dating results make it possible to directly correlate the Tailuganian of the Kuzbass with the upper half of the Wuchiapingian and with most of the Changhsingian of the International Chronostratigraphic Scale.
The accumulation rate of total sediments of the Tailugan Fm, calculated without considering the compaction index, is approximately 0.13–0.18 mm/year, and the rate of coal accumulation is 0.024 mm/year. Such values are comparable to the accumulation rates of the Late Paleozoic coal-bearing strata of the Donetsk Basin and Western Australia. The rate of peat accumulation during the Tailuganian, calculated at a compaction index of 10:1, has been estimated at 0.24 mm/year. This value is comparable to the rates of peat accumulation in the Holocene bogs of the Kuznetsk Alatau in Siberia and the European part of Russia.
The presence of tonsteins in the coal seams of the Tailugan Fm suggests that the upper surface of the peat at the time of its accumulation was below the water level, serving as a protective screen for the thin volcanic deposits and preventing its erosion.
The assemblages of macroflora, ostracods, conchostracans and bivalves considerably vary through the section of the Tailugan Fm. This variation makes it possible to identify in Kuzbass the stratigraphic level that corresponds to the boundary between the Wuchiapingian and Changhsingian stages in the future.

On the example of an oil deposit of the Vereisk age which is one of the deposits in the Volga-Urals, lithotypes of rocks are distinguished, characterized by a fundamentally different structure of the void space. For selected lithotypes experiments were carried out on core samples with a change in the stress state of rocks under conditions of volumetric (pseudo-triaxial) compression. The pressure created in the experiments is identified with the development of processes at a distance from the epicenter of the hydraulic fractures appearance. Core samples were studied before and after exposure by non-destructive testing methods. The study of the sample structures by standard and tomographic methods did not allow us to establish significant changes during loading of the samples. At the same time, some increase in rock permeability was established in experiments. With this in mind, the samples were studied according to a technique specially developed by the authors using electron microscopy. The use of microscopic studies made it possible to obtain quantitative information about the change in the void space at a level inaccessible to X-ray tomography. As a result, it was found that both for potential reservoirs and for impermeable rocks, there is an increase in the length and opening of preexisting fractures, which can be considered as the formation of additional effective fluid filtration channels. The experiments performed have changed the idea of the process of hydraulic fracture development and can be used in geological and technological calculations.

The displacement efficiency and residual oil saturation are the most important characteristics determining the recoverable volumes of oil and the waterflooding efficiency. The main data about these parameters are provided by laboratory core studies. Specialized field tests make it possible to evaluate the same characteristics in-situ, directly on a well, thus excluding the influence of scale effect and impact of core sampling and preparation.
This paper presents the results of a field study to evaluate the displacement efficiency and residual oil saturation on a well draining terrigenous Devonian formations on one of the areas of the Romashkinskoye field. The results are compared with generalized dependencies based on core data. Significant influence of the scale effect (the effect of sweep multiplicity) on the estimated parameter values was noted, which indicates the need to supplement laboratory experiments with specialized field studies.

Well cement sheath stability analysis for two oil-producing wells in the completion of productive formations by shaped charge perforating was performed. The data of direct measurements of pressures in the borehole at different distances from the cable head of the perforating tool at the moment of detonation, which exceeded 50 MPa, were used in the studies. The pressure values were approximated along the wellbore using a power law. To reliably predict the stress-strain state of the near-wellbore zone of the perforation interval, the ANSYS finite-element modeling software was used. To determine the stress field, an axisymmetric finiteelement calculation scheme was built, the height of the model along the wellbore was 39 m. During modeling, it was taken into account that the geological and physical parameters of the simulated reservoirs differed in depth and reservoir pressure value were different. Elastic-strength properties of the cement stone formed were determined during the laboratory experiments for different recipes of cement slurries. According to the results of modeling, the areas of destruction and strength reserve of cement stone, as well as the values of radial displacement of the production casing in the perforation interval were determined. The developed model of the nearwellbore zone and methodical approaches can be used in future for choosing optimal elastic and strength properties of cement stone, perforation tools and technological parameters of perforating-explosive operations.

The article shows the results of deep research along the profile of the settlement of Nizhnyaya Oblukovina – the city of Andrianovka, crossing the northern part of the Kamchatka median massif. A geological and geophysical model of the structure of the earth’s crust and upper mantle has been constructed, where the structural position of the object under study is presented and an assumption is made about its origin. The model highlights a fragment of paleosubduction (slab), which was part of the most ancient convergent boundary in western Kamchatka. The final stage of subduction blocking and its displacement to the east at a distance of ~60 km in the Early Eocene is associated with the entry into the accretionary complex of a terrane in the form of an island-arc plate 6–9 km thick. At the site of the maximum inflection of the subsequent slab, an extension zone was formed – a rift zone, along which the rise of mantle material and high-temperature fluid occurred. Approximately 52 million years ago, the processes of metamorphism, focal melting and intrusion of granites into the upper layers of the crust took place. As a result, in the eastern part of the plate and its flanks, a granitoid massif was formed with a rock density of 2.58 g/cm³ , which is significantly lower than the environmental density. Density deficiency led to a violation of isostatic equilibrium and, as a result, to a rise in this part of the structure. The most intense uplift occurred at the end of the Oligocene, as a result of which a ledge was formed, which the authors recommend giving the name: “Middle Kamchatka ledge” instead of the rooted “Kamchatsky median massif”. The genetic relationship of the Shanuch ore region with the features of the deep structure of the lithosphere has been revealed. The results of the research indicate a hidden (buried) distribution of the island-arc plate beyond the boundaries of the mapped outcrops of metamorphids. Intrusions of the main composition, promising for the opening of sulfide copper-nickel ores, are located in the marginal parts of the ledge.