Modern challenges and speed of information exchange for decision-making require new tools capable of storing and processing large amounts of data. The paper describes the principles, relevance and foundations of the expert-analytical platform MyGeoMap. The platform is designed to optimize and solve a wide range of scientific and practical problems. When creating the platform, we used the experience and knowledge accumulated by the Petroleum Geology Department, Geological Faculty of the Lomonosov Moscow State University. The platform allows to solve the following problems: promptly obtain information about oil and gas facilities anywhere in the world, search for analog deposits, use the platform as a corporate database and / or analytics tool, and much more. To date, the platform has collected more than a million geological, geophysical, industrial, environmental and other objects with georeferencing and attribute information. All data is collected from various open sources and integrated into a single digital environment. Data verification is carried out by qualified employees of the Institute for Advanced Oil and Gas Research of Moscow State University. The platform has its own intellectual developments, including the use of artificial intelligence tools for analytics and building predictive models. Platform users represent a specialized expert community whose potential has yet to be revealed. The MyGeoMap platform is a unique project that already today solves a number of interesting and important problems not only for the search and exploration of oil and gas fields, but also for other areas of economic development where geology plays a key role.

Modern geological exploration is a complex process that involves a series of research stages, each aimed at solving specific tasks in order to identify oil and gas reserves. These stages are typically carried out in a sequential manner, with the results being integrated as they are obtained. This process typically starts with a general analysis of the region where the search object is located, and then moves on to more detailed studies of the local area in order to gain a better understanding of the structure of the deposit. In this paper, we have developed algorithms for an integrated approach to exploration, which depend on the level of knowledge about the object being studied. We have also conducted an analysis of retrospective methods at different stages of exploration, using one of the most well-studied areas in the Pur-Taz oil and gas region as an example. The most poorly understood aspects of the field development stage include determining the timing of the arrival of hydrocarbons in the trap and the timing of structural changes in the hydrocarbon system. The lack of research into these regional factors leads to the loss of potential deposits. Using an example from one of the fields, we illustrate how we solved problems that had not been addressed before, such as restoring the paleostructure on a regional and zonal scale. This resulted in the identification of new promising areas for oil and gas exploration within the Pur-Taz area.

One of the important properties of the rock is the degree of water wettability of the pore space’s surface, which affects most petrophysical, geophysical and hydrodynamic parameters: residual water saturation, electrical resistivity of oil and gas saturated rocks, oil and gas saturation coefficients (S_o), displacements, relative phase permeability. Omission of wettability leads to geological and recoverable reserves distortion. Therefore, a comprehensive analysis of the geological conditions and petrophysical properties of reservoirs should begin with establishing the type of sediment wettability. When establishing a heterogeneous (non-hydrophilic) type of wettability, the standard method for determining So using the electrical GIS model must be adjusted using a special technology for core research, taking into account surface properties or using the P_n-s_w dependence of the “core-GIS” type. There are a number of diagnostic features of rock wettability, such as the mineral composition of the rock and clay components, the properties of water and oil, the structure of the void space, electrical resistance along the core and GIS, knowing which, it is possible to make qualitative assessments of the rock wettability type. The combination of various diagnostic factors leads to different mechanisms of sediment hydrophobization, which have different effects on the P_n-s_w relationships for determining S_o and on reserves estimation. Therefore, it is important to study the combination of signs that influence on wettability on the rock in natural conditions, rather than the influence of individual parameters.

When studying sections of productive wells using geophysical GIS and core methods, it was found that the GIS WPP in the productive section is a reliable value of the natural wettability of productive rocks in the well section. The values of RP, as a standard for the wettability of productive rocks according to GIS, allow us to select reasonable petrophysical P_n-s_o dependences for determining reliable coefficients of oil and gas saturation according to GIS. This paper collects and analyzes the main and most important factors affecting wettability, obtained from extensive studies of deposits in the TimanPechora oil and gas basin from north to south, in productive formations covering almost the entire productive section from P₂ to S₁. The article considers an example of the formation of different mechanisms of sediment hydrophobization for two types of heterogeneous reservoirs of terrigenous composition P₂-T₁ and D₂st.

The paper is devoted to the classification of oil and gas source rocks. Determination or prediction of the characteristics of oil and gas source sediments is one of the key factors in assessing the prospects and forecasting the oil and gas potential of a particular region. In the paradigm of the sedimentary-migration theory of oil and gas formation, an adequate assessment of the amount and properties of organic matter in sedimentary rocks is the key to an adequate calculation of oil and gas resources. The article presents an overview of approaches to ranking oil and gas source rocks based on various parameters and proposes a new comprehensive approach to the classification of oil and gas source rocks that generate oil and gas. An attempt was made to combine the characteristics of the mineral part and organic matter of oil and gas source strata in a new general classification. The prediction of the properties of oil and gas source sediments is based on the conditions of accumulation of these strata. The proposed classification can be used to assess the prospects for oil and gas potential, especially in conditions of insufficient data on potential oil and gas source sediments. 

This paper presents an investigation of the isotopic characteristics of organic matter in Upper TriassicJurassic sediments of the West Siberian Basin, which are crucial for understanding the processes of oil and gas formation in the region. Based on detailed isotopic studies of bitumoids, a pattern of isotopic characteristic changes is demonstrated, driven by the influence of facies conditions of sedimentation. The aim of the study was to identify and systematize the regularities of carbon isotope distribution in autochthonous organic matter to create a genetic picture of its formation in various paleogeographic settings of the Jurassic period. Isotope-fractionation analysis of bitumoids allowed us to identify five groups, reflecting the link between the isotopic composition of organic matter and sedimentation conditions within the Frolovsko-Shaimsky, Yamalo-Gydansky, and Urengoy facies regions. The obtained results are of great importance for regional geology and petroleum geology, contributing to the optimization of hydrocarbon exploration and development strategies in the West Siberian Basin and providing new tools for assessing the hydrocarbon potential of sedimentary basins in general.

The Barents-Kara region is one of the most potential in the Russian Arctic with significant hydrocarbon accumulations. It has been confirmed since the early 80s of the last century by large and unique discoveries. In recent years 6 new gas fields have been discovered on the Kara Sea shelf. It is believed that the exploration stage on the Barents and Kara shelf is almost complete and the region at the development stage now. However, the deeply buried Paleozoic sedimentary complexes are practically unexplored and are at the initial exploration stage. The lack of information about deep complexes was one of the reason for the new stratigraphic drilling in the Arctic to tie seismic horizons. Different approach to assess hydrocarbon accumulations and generation potential is needed taking in account the different Mesozoic and Paleozoic data detalization. Underestimation of deep sedimentary complexes may lead to errors in volume and phase composition assessment. The small amount of information on deep complexes cause to predict reservoir and source rocks properties based on paleogeographic reconstructions for the entire Barents-Kara region. It was made for large tectonic blocks which could be deformed during the history development. Different thickness distribution, lithological and stratigraphic composition within depressions and platform blocks is expected.

Kara Sea shelf allow establishing of the modern stratigraphic and basin model of the Barents Sea and North Kara Sea Basins. The common history of the geological evolution of these basins began in the Early Paleozoic. The identification of erosional truncation contributes reconstruction of the paleoprofiles and restoring the thickness of eroded sediments, which were considered in the basin model.

Basin modeling has shown that the timing of generation, migration and accumulation of hydrocarbons are different depending on the history of the first-order tectonic elements development. No significant flows of hydrocarbons between first-order structural elements were defined.

Lower Paleozoic source rocks influenced great on the emerging of oil accumulations in the North Kara Sea Basin.

Despite the low thermal maturity of Upper Jurassic source rocks, the use of an individual kinetic spectrum of kerogen destruction leads to earlier and faster generation of hydrocarbons in comparison with standard kinetic spectra for type II kerogen.

The intrusions influenced the generation of hydrocarbons by Mesozoic source rock to varying degrees. Intrusions influenced on generation greater in the Lower-Middle Jurassic source rocks and less in the Upper Jurassic and Early Cretaceous source rocks. For the Triassic source rocks, the impact of intrusions has a negative effect, due to the rapid “burning” of the petroleum potential, as well as an increase of gas generation due to secondary cracking.

Clinoform strata are widely distributed in the various sedimentary basins throughout the world. They are observed in clastic and carbonate successions of the wide stratigraphic range and contain oil and gas fields. Clinoforms provide also an information about the direction of sediment transport, palaeogeography, and sea level changes. However, the universal approaches for palaeogeography reconstruction and reservoir prediction in the clinoform sequences of the various ages and in different sedimentary basins have not yet been developed. This study represents the methodical approach to clinoform investigation on the examples from Upper Jurassic and Lower Cretaceous clinoforms of the Barents Sea and Priob region of the West Siberia Basin. Established methodical approach solves three problems: 1) structure and types of clinoforms; 2) reconstruction of sedimentary conditions; 4) prospecting of oil and gas reservoirs and stratigraphic traps in the clinoforms.

. Significant oil reserves may be contained in the part of the oil reservoir related to the water-oil saturation transition zone, but a comprehensive description of the relationship between capillary pressure, relative phase permeability and saturation with oil and water is a constant problem in carbonate deposits due to complex wettability changes, difficulties with assessing the nature of reservoir saturation by well logging, pore geometry and lithofacies heterogeneity throughout the reservoir thickness in the saturation transition zone.

In the course of the work, it is shown that a reliable interpretation of the constructed capillary pressure curves and relative phase permeability, including taking into account various physical and geological factors of productive formations, has a significant impact on predicting the initial oil saturation coefficient and the thickness of the two-phase filtration zone for complex carbonate reservoirs. The paper examines various factors influencing the size of the transition zone in a carbonate reservoir: lithofacies and filtration-capacitive properties of reservoirs, age of sediments, properties of saturating fluids, surface properties by wettability of the solid surface of capillaries, and structural features of the pore space of reservoirs.

The paper presents the results of the analysis of the structure and composition of the terrigenous complex of the Lower-Middle Jurassic sediments of the East Manych Trough and the Prikum uplift system. The structure of the Lower Jurassic rocks is clarified and it is shown that the area of their distribution is associated with the troughs and depressions of the pre-Jurassic paleorelief. The Middle Jurassic sediments are more widespread and their thicknesses gradually increase in the northeastern direction. The Lower-Middle Jurassic sediments are productive, but new discoveries have not been made for more than 20 years, which requires new geological and methodological approaches. Currently, one of the wellknown and effective approaches to dissection and delineation of regionally traceable single-age reservoir rocks in “dumb” complexly built terrigenous strata is cyclostratigraphic analysis. Four transgressive-regressive sedimentary cyclites were identified in the Lower-Middle Jurassic sediments. The transgressive parts of the cyclites are confined to silty-clayey rocks of predominantly marine genesis, while the regressive parts are confined to silty-sandy rocks of coastal-marine and continental genesis. The boundaries of cyclites are tied to seismic sections, which allowed us to trace the distribution of cyclites in the area and construct maps of thicknesses of each cyclite. All discovered fields in the East Pre-caucasus are located in regressive parts of the cyclite. All discovered fields in the East Pre-caucasus are located in regressive parts of the cyclite. The Lower Jurassic reservoirs are confined to river channels, while the Middle Jurassic reservoirs are mainly associated with shallow-marine sediments of deltaic genesis.

The article presents the results of the lithofacies study of the Late Vendian Botuobinsky horizon of the southeastern part of the Srednebotuobinskoye field. The main problem solved in the article is the search for intervals with the best reservoir properties within the Botuobinsky horizon and the forecast of their distribution over the area of the Srednebotuobinskoye field using complex lithofacies and cyclic analysis. Based on the description of the core, thin sections, X-ray phase analysis, X-ray fluorescence spectrometry, structural, texture, granulometric analyses and geophysical well logging, a lithofacies scheme was constructed for the time of formation of the Botuobinsky horizon and the horizon was divided into four cyclites. The best reservoir characteristics within the Botuobinsky horizon were established in its middle part (2–3 cyclites) in the deposits of the coastal slope facies, tidal channels and sandy littoral. However, the primary filtration-capacity properties of the Botuobinsky horizon were significantly influenced by secondary processes of salinization, quartz regeneration, anhydritization and dolomitization, which, however, are manifested differently in different facies.

The work is aimed at searching for new fields and forecasting the distribution of productive oil and gas-saturated formations in the Vendian-Cambrian deposits of Eastern Siberia. Since the anticlinal theory of hydrocarbon exploration has exhausted its potential in ancient petroleum basins, it is necessary to look for new approaches to forecasting oil and gas potential and mechanisms of fields. The authors used the classical approach of basin analysis developed by the founders of the Petroleum Geology Department of the Lomonosov Moscow State University, using modern research methods. For the main tectonic elements of the south of the Siberian platform, the thickness of eroded deposits was determined, one-dimensional (1D) geological models were constructed that determine the operating time of hydrocarbon systems, and an analysis of changes in the structural plan at all stages of geological development of the territory was performed. The obtained results are linked to each other to establish the time of formation of hydrocarbon deposits and the stages of their reformation and destruction due to changes in the structural plan. The second phase of generation of Proterozoic oil and gas source strata in the Mesozoic era is shown. Conclusions are made about the expansion of the Nepa-Botuobinskaya anteclise by 50–100 km due to the inversion of the structural plan in the southeastern part, from the side of the Baikal folded region. Models of the formation of deposits for the Kurey syneclise and the Nepa-Botuobinskaya anteclise are created, the most promising areas for the development of the Srednebotuobinskoye field are identified and a new approach to searching for deposits in the south of the Siberian platform is proposed.

The Lower and Middle Carboniferous deposits of the European part of Russia are coal-bearing in many regions, so their study and exploration began in 19th century. Such basins as the Donetsk, Podmoskovny, Kamsky, Kizelovsky, and Lviv-Volyn basins located in Ukraine are well known. The aim of this study was to re-examine the maceral composition taking into account the modern terminology of the International Committee for Coal and Organic Petrology, as well as to reconstruct the paleogeographic areas in which the coal formation of the studied basins took place. Maceral composition of coals of all mentioned basins and some coaloccurrences of the East European Platform (EEP) from the collections in Lomonosov Moscow State University and Geological Institute of the Russian Academy of Sciences were examined. The modern International Nomenclature was used for the first time for coals of different Russian European basins. Two facial zones were distinguished according to coal macerals composition, which are in agreement with early described paleogeography reconstructions and lithological analysis. The first zone is widely spread in the inner part of the Platform, it is represented by alluvial and lake facies (Podmoskovny, Kamsky basins) and in the peripheral region (Kizelovsky) delta fancies are marked out. This area is characterized by coals with very diverse maceral composition, mixtohumolites (Russian term) are frequent, and among the liptinite group alginites – representatives of sapropelic organic matter – are not uncommon. The second zone, identified by coal petrographic data, is the southern and western margins of the EEP, where coal-bearing is represented in a wider stratigraphic interval, and is associated with coastal-marine conditions. The main coal-forming component of the coals of these basins are macerals of the vitrinite group, which account for at least 80%. Alginites are also found in the maceral composition of Donetsk and Lviv-Volyn basins. The abundance of macrosporinites and other liptinites formed from the ancient higher plants is considered to be a common feature of coals of both zones.

The article is devoted to the complex coordination of multi-scale multi-level data obtained at different stages of geological exploration, in order to create a single ordered model of the deposit, taking into account retrospective and modern research results. The search for oil and gas fields in sedimentary oil and gas basins involves a classic scheme from the general to the particular. Therefore, when determining the oil and gas potential of the territory, regardless of the stage of geological exploration, it is necessary to determine the boundaries of the location of the local object in the regional plan and build a structural framework for the main reference strata (reflecting horizons). Based on the structural framework, paleostructural reconstructions are carried out to restore the stages of trap formation and determine the migration paths of fluids. Based on the data of geophysical well surveys and core studies, reservoir intervals are established, the properties of lithotypes are identified and secondary processes of reservoir rock transformation are determined. Geochemical and hydrogeochemical studies of fluids are conducted to identify fluid-dynamic connections within a sedimentary basin, oil and gas accumulation zone, field, and individual deposit. Geomechanical studies are performed to apply modern development methods. All obtained data are integrated with each other, allowing new patterns to be identified, thereby increasing the reliability and efficiency of geological exploration.

The digital core analysis technique and associated direct pore-scale flow modeling tools provide unique capabilities for simulating physicochemical processes at the microscale, while accounting for the structure and properties of actual reservoir rock matrices. This study presents numerical simulation results of pore-scale acid treatment in carbonate reservoirs using the density functional hydrodynamics (DFH) method. The proposed approach models interactions between hydrochloric acid (HCl) solution flow and pore surfaces through an additional distancedependent potential incorporated in the simulation model.

The investigation focuses on determining the influence of acid injection rate on mineral matrix dissolution efficiency, porosity evolution, and rock permeability alteration. Simulations were conducted on a three-dimensional digital dolomite model reconstructed based on X-ray tomography data. By accounting for both pore space heterogeneity and surface chemical reactions, this study examines flow regime effects on mineral dissolution processes and establishes empirical correlations between effective reaction rates and flow velocity.

The results demonstrate the significant potential of numerical methods for investigating processes that are challenging or impossible to reproduce under laboratory conditions. The developed approach offers new perspectives for analyzing acid stimulation effects on reservoir pore characteristics, with important implications for enhancing hydrocarbon recovery efficiency.

Based on the results of lithological, cyclostratigraphic analyses, as well as linking with geophysical research of wells data and correlation of well sections, the main isochronous levels of deposits of the Parfenovsky horizon in different facies zones of the Angara-Lena step were identified and traced. The sediments were formed in the conditions of coasts with wandering streams and tidal deltas passing into a shallow marine sedimentation basin. The lithological heterogeneity of the deposits is associated with a wide variety of medium-scale facies units (meso-facies), as well as the intensity and direction of secondary processes.

This paper presents the results of application of modified preformed particle gels based on different monomers and aluminosilicates for conformance control technology at the fields of the Republic of Tatarstan, characterized by fractured carbonate reservoir with high salinity of formation water (more than 230 g/l). To evaluate the efficiency of synthesized gel particles at the first stage “bottle test” were carried out (swelling ratio, long-term stability, selection of the optimal size, etc.), according to the results of which the most effective sample was selected, characterized by high absorption capacity (more than 7 g/g) and able to retain its blocking properties for 180 days. At the next stage of works filtration experiments on core material were carried out to evaluate blocking properties, the results of which proved the effectiveness of application for blocking of high permeability channels. The results of laboratory studies allowed to proceed to pilot tests on injection gel particles. Injection of the reagent was carried out in the flowing mode with the gel particles with the concentration of 0.1–0.8% wt. in the injected highly mineralized water with the flow rate not more than 5 m³/hour. Dynamics of injection pressure change was used as the main criterion of efficiency assessment during the pilot test.

The paper presents results of comprehensive study of core samples collected from Tournaisian sediments of the Saraylin Series within the Nizhnekamsk Uncompensated Trough. The survey region covers the southeastern slope of North Tatar Arch in the Republic of Tatarstan. The study is targeted at the Saraylin Series, a complex of carbonatesiliceous-terrigenous rocks with increased organic matter content, confined to the interval from the lower boundary of the Tournaisian Stage to the bottom of overlying Tournaisian carbonate rocks or terrigenous sediments of another (postTournaisian) age.

Samples from two wells confined to axial and flank regions of the trough were investigated. For the first time ever, the Saraylin sediments of the Republic of Tatarstan were characterized by core data to enable identification of the main lithofacial and geochemical features.

Results of pyrolysis studies of the entire coring interval were analyzed. Vertical and horizontal variations of pyrolytic parameters of the sediments within the section were established. Is has been established, that the Saraylin sediments in the axial and flank regions of the trough are high-carbon, predominantly domanicites and domanicoids. Organic matter is represented by type II kerogen and has low maturity at PK₃-MK₁ level.

The resource potential of Saraylin sediments was evaluated within one paleofacial zone of axial region of the trough based on core data. Five lithologic and geochemical clusters were identified considering nonuniform distribution of organic matter content and other geochemical characteristics of the sediments through the section.

Based on the resulting data, the resource potential of the rocks in the lower portion of the Saraylin Series was estimated. The amount of liquid hydrocarbons, mobile petroleum reserves and residual kerogen generation potential were estimated. Results of the present research efforts enable refinement of the resource potential of high-carbon Tournaisian rocks of the Saraylin Series and provide improved understanding of their oil and gas potential within the southeastern slope of North Tatar Arch.

High extent of subsurface exploration activities in the Republic of Tatarstan results in ever increasing scarcity of hydrocarbon resources available for the purposes of oil production. Under such conditions, the search for and development of overlooked reservoirs within existing producing fields become of great importance. The Sargaevskian horizon is associated with unique Domanic deposits which are considered the main oil source rocks within the Volga-Ural petroleum province. Domanic rocks are capable of both generating and accumulating hydrocarbons. This paper analyses all available G&G data from previous studies of the Sargaevskian sediments in Almetyevskaya and Aznakaevskaya areas of Romashkinskoe field. Reinterpretation of open-hole logs run in 712 wells was conducted to refine the geological structure and evaluate the oil potential. Data acquired using modern logging methods including pulsed neutron logging and pulsed neutron spectroscopy gamma-logging were used to identify potential reservoir zones and evaluate fluid saturation in cased holes. Saraylinskoe field located within the same facies zone as Romashkinkoe field and having the confirmed oil potential of Sargaevskian horizon was reviewed. 

The sediments of Lake Turgoyak (Southern Urals, Russia) have been accumulating throughout the Late Pleistocene and the Holocene. Sedimentation is controlled by the lake’s morphometry, drainage systems, vertical zoning, thermal state of the water, and wind action.
Therefore, analysis of cartographic materials illustrating the area’s geology, topography, drainage systems, watersheds (catchment areas) and drainage divides is relevant in this regard. All these aspects are important for assessing the role of sediment sources and transportation routes, as well as deposition mechanisms and sediment distribution within the lake. The study of lake deposits provides valuable insights for genetic interpretation of sedimentary sequences in the context of paleoclimatic and paleoecological trends and events.
This study presents a digital model of Lake Turgoyak and its surroundings. The model was developed using GIS software, incorporating available geological, topographical, and bathymetric maps. Overlaying watershed models onto geological maps of pre-Quaternary and Quaternary deposits enabled assumptions about the material composition of sediment transported into the lake.
Developing similar digital models for lake systems in the Urals, other regions of Russia, and worldwide opens opportunities to systematize information at a new level and utilize it for various reconstructive purposes.

This study presents the first investigation of Lake Kandrykul sediments through radiometric dating and detailed lithological and mineralogical analysis of a long (>5 m) core sample retrieved from the lake’s bottom. The results shed new light on depositional conditions in the region and contributed to a broader understanding of lake sedimentation during the late Quaternary.
Radiocarbon dating indicates that sedimentation in Lake Kandrykul began approximately 8,000 years ago. The studied depositional sequence consists of alternating layers of silty clay, silty sandy loam, heavy silty loam, and light silty loam.
Allogenic minerals make up the bulk of the sediment composition, reaching up to 76%. Elevated Ca and Mg content in several core intervals correlate with the presence of authigenic carbonate and sulfate crystals, reflecting Lake Kandrykul’s setting within an erosional-karst depression formed in sulfate-carbonate-rich sedimentary rocks.
The changing ratios between allogenic and authigenic components serve as indicators of Holocene climate shifts, particularly highlighting two major arid periods: around 6,000–5,100 years BP and 2,000–1,000 years BP.

For the first time, zircons from thin volcanic ash layers contained within organic-rich black shales (Domanik facies) at the Devonian–Carboniferous boundary have been dated using the U–Pb LA-ICP-MS method. The studied material comes from core samples of two boreholes located in the axial and marginal zones of the Kama–Kinel Trough System within the Volga–Ural Petroleum Province. In the axial zone, the base of the Siphonodella quadruplicata conodont zone yielded a concordant U–Pb age of 357.6 ± 1.7 Ma. In the marginal zone, the upper part of the Palmatolepis gracilis expansa Zone provided a concordant U–Pb age of 360.0 ± 1.2 Ma. These ages agree, within analytical uncertainty, with the current conodont-based chronostratigraphic framework and allow refinement of the onset of the Hangenberg Event in the studied basin.