Hydrocarbon Systems Research Articles

Asphaltene genesis influence on the low-sulfur residual marine fuel sedimentation stability

• Genesis and structure of asphaltenes affect the stability of residual marine fuel. • Thermodestructive asphaltenes reduce the stability of residual marine fuel rapidly. • There is a residual marine fuel stability rank (TSA) from the asphaltenes genesis. This paper describes the results of studies carried out to determine the influence of asphaltene genesis on the low-sulfur residual marine fuel sedimentation stability, based on RMG 380 commercial fuel as an example. The composition and structural features of potentially acceptable residual components of marine fuels asphaltenes (vacuum residues, asphalt, visbreaker residues, heavy pyrolysis resins) and crude oil (for comparison) asphaltenes – 9 types in total – were comprehensively characterized by FT-IR, XRD, SEM, XRF, CNH analyses. The gross formulas of the examined asphaltenes were established by determining the molecular weight and elemental composition. The dependence of asphaltene genesis influence on stability was assessed by adding them in an amount of 1 to 5 wt% into RMG 380 marine fuel base compositions of constant composition according to “total sediment aged” (TSA) index. It was determined that when the asphaltene content of the studied stock types increases above 4 %, the stability of the fuel compositions, and consequently the asphaltene solubility, in the base hydrocarbon system (based on RMG 380 as an example) decreases in the following series: Asphalt → Vacuum residue → Crude oil → Visbreaker residue → Heavy pyrolysis resin.

Numerical modeling and parametric sensitivity analysis of heat transfer and two-phase oil and water flow characteristics in horizontal and inclined flowlines using OpenFOAM

Estimating the oil-water temperatures in flowlines is challenging especially in deepwater and ultra-deepwater offshore applications where issues of flow assurance and dramatic heat transfer are likely to occur due to the temperature difference between the fluids and the surroundings. Heat transfer analysis is very important for the prediction and prevention of deposits in oil and water flowlines, which could impede the flow and give rise to huge financial losses. Therefore, a 3D mathematical model of oil-water Newtonian flow under non-isothermal conditions is established to explore the complex mechanisms of the two-phase oil-water transportation and heat transfer in different flowline inclinations. In this work, a non-isothermal two-phase flow model is first modified and then implemented in the InterFoam solver by introducing the energy equation using OpenFOAM® code. The Low Reynolds Number (LRN) k-ε turbulence model is utilized to resolve the turbulence phenomena within the oil and water mixtures. The flow patterns and the local heat transfer coefficients (HTC) for two-phase oil-water flow at different flowlines inclinations (0°, +4°, +7°) are validated by the experimental literature results and the relative errors are also compared. Global sensitivity analysis is then conducted to determine the effect of the different parameters on the performance of the produced two-phase hydrocarbon systems for effective subsea fluid transportation. Thereafter, HTC and flow patterns for oil-water flows at downward inclinations of 4°, and 7° can be predicted by the models. The velocity distribution, pressure gradient, liquid holdup, and temperature variation at the flowline cross-sections are simulated and analyzed in detail. Consequently, the numerical model can be generally applied to compute the global properties of the fluid and other operating parameters that are beneficial in the management of two-phase oil-water transportation.

Numerical study and sensitivity analysis of two-phase oil-water flow and heat transfer in different flowline orientations using OpenFOAM

Evaluating the oil-water temperatures in flowlines is demanding mostly in deep offshore applications where flow assurance issues and dramatic heat transfer are anticipated to occur. Consequently, a 3-D mathematical model of oil-water Newtonian flow under non-isothermal conditions is established to investigate the mechanisms of the two-phase oil-water transportation and heat transfer in horizontal and inclined flowlines. In this study, a non-isothermal two-phase flow model is first modified and then implemented in the InterFoam solver by introducing the energy equation using OpenFOAM® code. The Low Reynolds Number (LRN) k-ε turbulence model is employed to resolve the turbulence phenomena within the oil and water mixtures. The flow patterns, local heat transfer coefficients (HTC), and relative errors for two-phase oil-water flow at different flowline orientations (0o, +4o, +7o) are compared with the experimental literature results. The model was also employed to ascertain the effect of input water cuts and flowline inclinations on the flow regimes, and the results were validated in literature with a high accuracy level. Global sensitivity analysis is then conducted to determine the effect of the different parameters on the output temperature and pressure of the produced two-phase hydrocarbon systems. Subsequently, HTC and flow patterns for oil-water flows at different inclinations of −10o, -4o, and +10o can be predicted by the model. The velocity distribution, liquid holdup, pressure gradient, and temperature variation at the flowline cross-sections are simulated and analyzed extensively.

Experiment and a catalyst acid property‐included global reaction modeling for catalytic pyrolysis of 1‐pentene

AbstractThe acid property of the catalyst is usually one of the most important parameters for the selection and design of catalysts for catalytic pyrolysis of 1‐pentene. Here, seven catalysts with similar pore properties and different acid properties were evaluated and characterized in terms of three key properties: Total acid amount (TA), Brønsted to Lewis acid ratio (B/L), and strong to weak acid ratio (S/W). A database of the stoichiometric coefficients of 26 pyrolysis products was constructed. Then, a novel catalyst acid property‐included global reaction modeling method was developed, which was used to predict the yields of the 26 pyrolysis products. Besides, a suitable range of TA, B/L, and S/W was obtained for enhancing ethylene and propylene. The model thus can predict the product composition, and be used for the design and selection of the acid properties of catalysts. This simulation method can also be extended to other hydrocarbon systems.

Albert Einstein, World of Dices and Hydrocarbon System Analysis

Albert Einstein, Caesar and others have used dices as a metaphor for risks and probabilities; indirectly reverting to the experience human kind may have with natural processes in its environment contemporarily with human evolution. It will be shown for example by concentrating on the exploration of hydrocarbons that the rules of a dice-game can be used to better understand the importance of the number of ruling parameters (dices), in this case geological parameters. Especially the Rotliegend Gas Play of the North German Basin belongs to the very complex hydrocarbon systems with more than 70 independent parameters. The Dutch Rotliegend Play for comparison can be characterized by only 10 parameters and is therefore of a simple type. Processes on earth like the formation of systems of hydrocarbon fields as well as environmental systems (e.g. river systems, lakes, islands, sedimentary basins) are subordinated to the dice of nature like in a Casino and are steered invisibly by a selection of rules of the game that one understands as natural laws. The complexity of a system as well as the variedness of its “members” that may be found in anthropogenic systems as well (different properties in thinking, self-reflection, feedback-capabilities, combative and ambitious behavior of individuals with the target to climb upwards in a ranking matrix) is decided by the number of the influencing parameters, represented by dices. Like in a dice-game the exploration of hydrocarbons is unsolvable connected to luck and bad-luck, coincidence and necessity, and to past and future.

Exploring the potential of oil and gas resources in Sichuan Basin with Super Basin Thinking

Based on the contemporary strategy of PetroChina and the “Super Basin Thinking” initiative, we analyze the petroleum system, the remaining oil and gas resource distribution, and the Super Basin development scheme in the Sichuan Basin with the aim of unlocking its full resource potential. We conclude that, (1) The three-stage evolution of the Sichuan Basin has resulted in the stereoscopic distribution of hydrocarbon systems dominated by natural gas. The prospecting Nanhua-rift stage gas system is potentially to be found in the ultra-deep part of the basin. The marine-cratonic stage gas system is distributed in the Sinian to Mid-Triassic formations, mainly conventional gas and shale gas resources. The foreland-basin stage tight sand gas and shale oil resources are found in the Upper Triassic–Jurassic formations. Such resource base provides the foundation for the implementation of Super Basin paradigm in the Sichuan Basin. (2) To ensure larger scale hydrocarbon exploration and production, technologies regarding deep to ultra-deep carbonate reservoirs, tight-sand gas, and shale oil are necessarily to be advanced. (3) In order to achieve the full hydrocarbon potential of the Sichuan Basin, pertinent exploration strategies are expected to be proposed with regard to each hydrocarbon system respectively, government and policy supports ought to be strengthened, and new cooperative pattern should be established. Introducing the “Super Basin Thinking” provides references and guidelines for further deployment of hydrocarbon exploration and production in the Sichuan Basin and other developed basins.

Formation of Oil and Gas Fields in Deep Hydrocarbon Systems: Outline of a Universal Search Concept

Formation of Oil and Gas Fields in Deep Hydrocarbon Systems: Outline of a Universal Search Concept

НЕФТЕГАЗОМАТЕРИНСКИЕ ПОРОДЫ И ПРОБЛЕМА НЕФТЕГАЗОНОСНОСТИ АЛДАНО-МАЙСКОЙ ВПАДИНЫ (ЮГО-ВОСТОК СИБИРСКОЙ ПЛАТФОРМЫ)

The analysis of existing understandings about distribution of oil-and-gas source rocks was performed for sedimentary section of the Aldan-Maya depression, the large margin structure in the south-east of the Siberian Platform. Taking into account new materials, the oil-and-gas generating potential of these strata was critically examined, and the ideas of previous research period were defined more precisely. On this basis, the sketch map of oil-and-gas bearing stratigraphic breakdown of the Aldan-Maya depression sedimentary cover was compiled. The main elements of hydrocarbon systems, including predicted petroleum plays and petroleum bearing strata were identified, forecast of possible types of traps for various parts of the depression was given. Based on this experience, the contour map of the petroleum potential forecast for the Aldan-Maya depression and adjacent territories was compiled.

A step-by-step approach to creating and tuning PVT-models of reservoir hydrocarbon systems based on the state equation

The article is considering a new effective step-by-step approach to creating and tuning PVT-models of reservoir oil and reservoir gas condensate mixtures. The method is based on the reproducing of the results of field measurements and basic laboratory studies of representative samples in thermodynamic modeling using cubic three parameters equation of state. Tuning PVT-model is used for reliable modeling of PVT properties of reservoir fluids (reservoir oil and reservoir gas) in the design and monitoring of field development, calculation of multiphase flow in wells and field pipelines, as well as in basin modeling. Proposed approach makes possible to tune the PVT model with high accuracy of both reservoir oil and reservoir gas condensate system to experimental data using a step-by-step procedure, where at each step, by changing one of the parameters of the equation of state, one of the PVT properties of the hydrocarbon system is tuned. Algorithmization and automated application of this approach in specialized software products is possible. Proposed approach allows tune reservoir oil PVT-models on the main PVT-properties such as saturation pressure, FVF, STO density, gas-oil ratio of reservoir oil and dependencies of dynamic viscosity and compressibility on pressure at reservoir temperature as well as STO density. The tuned gas-condensate PVT-model precisely reproduces the key properties such as dew point pressure, initial condensate content in the reservoir gas, z-factor of the reservoir gas, gas-oil ratio, stable condensate density, drop down curve by the result of CVD-test. PVT-models created on the base of the proposed method, provide reliable information on the properties of a reservoir fluid in development of flow simulation both using a reservoir simulation compositional models and using pseudo models “black oil”. The method is illustrated by the example of creation of the adequate PVT-models of various regions of Russia reservoir oil and reservoir gas condensate mixtures.

Sediment Organic Contents Required for Gas Hydrate Formation: A Survey of Published Basin and Hydrocarbon System Models

Recent advances in basin and petroleum system modelling have allowed for the investigation of gas hydrate systems, including modelling of the generation, migration, and accumulation of biogenic and thermogenic gas within gas hydrate deposits. In this brief survey paper, the treatment of sediment organic properties (organic content and richness, expressed as total organic carbon and the hydrogen index) within previously published basin and petroleum system models of marine gas hydrate systems is reviewed. Eight studies (published between 2015 and 2020) are described and discussed. This review contributes to the state of knowledge in the field by reviewing existing modelling studies of gas hydrates and concludes with brief takeaways on important considerations and knowledge gaps in the state of basin and hydrocarbon system modelling of gas hydrate systems.

Testing the Sediment Organic Contents Required for Biogenic Gas Hydrate Formation: Insights from Synthetic 3-D Basin and Hydrocarbon System Modelling

Gas hydrates comprise one of the largest reservoirs of organic carbon on Earth. Marine gas hydrate predominantly consists of biogenic (i.e., microbially generated) methane molecules trapped within lattice-like cages of frozen water molecules. Sedimentary organic matter is the feedstock for methanogens producing gas in anaerobic sub-seafloor environments. Therefore, an understanding of the minimum amount of organic material (measured as carbon and hydrogen content) necessary for methanogenesis to result in appreciable volumes of hydrocarbons is central to understanding the requirements for gas hydrate formation. Reactive transport modelling by workers over the past 20 years suggests minimum requirements of ~0.3–0.5. wt. % TOC (total organic carbon) for gas hydrate formation, while earlier workers predicted TOC as low as ~0.1–0.2. wt. % could produce biogenic gas. However, the hydrogen content (recognized as the limiting reagent in hydrocarbon generation for over 50 years) needed for biogenic gas generation and gas hydrate formation is poorly understood. Furthermore, the minimum organic contents needed for gas hydrate formation have not been investigated via basin-scale computational modeling. Here, we construct a synthetic 3-D basin and gas hydrate system model to investigate minimum sediment TOC and hydrogen (HI, hydrogen index) contents needed for gas hydrate formation. Our modelling suggests that, under geologically favorable conditions, TOC as low as 0.1. wt. % (paired with 100 HI) and HI as low as 50 (paired with 0.2. wt. % TOC) may produce biogenic gas hydrate saturations above 1%. Our modelling demonstrates the importance of basin-scale investigation of hydrocarbon systems and demonstrates how the confluence of favorable structural controls (e.g., faults, folds, anticlines) and stratigraphic controls (e.g., carrier beds, reservoirs) can result in gas hydrate accumulations, even in organic-poor settings.

Generation and geochemical signatures of natural gas from solid bitumen: Implications from closed and stepwise semi-open pyrolysis experiments

Solid bitumen has been acknowledged as an important source of overmature shale gas. However, the gas generation potential, chemical signatures and carbon isotopic compositions of natural gas derived from solid bitumen in an overmature hydrocarbon system are not well-understood with respect to various geological conditions. In this study, a relatively low-maturity solid bitumen from Cambrian reservoirs in the northwest Sichuan Basin was pyrolyzed in both closed and stepwise, semi-open systems. In the closed system, methane generated in the overmature thermal stage is dominated by the secondary cracking of wet gas and cumulative methane carbon isotopic values that are 4.4‰–14.8‰ lighter than the carbon isotope composition of the original solid bitumen. In semi-open systems, the gas is predominantly generated from residual solid bitumen and has wetness (i.e., C2–C5/C1–C5 by volume) values of generally less than 1%. At the same thermal maturity levels, the carbon isotope composition of methane in various semi-open systems is 4.4‰–10.0‰ heavier than those in the closed system and may also be isotopically heavier than the carbon isotope value of the original solid bitumen. The present study also illustrates that the calculated gas yields and methane carbon isotopes within a certain thermal maturity range in the closed system cannot be compared with those from residual solid bitumen as measured in the corresponding semi-open systems. This highlights the need to conduct specific semi-open pyrolysis experiments to investigate the late gas generation potential and geochemical signatures of natural gas from solid bitumen when the geological system is not a closed system. By comparing the above-mentioned results with the geochemical characteristics of Wufeng-Longmaxi shale gas from the Changning and Jiaoshiba gas fields of the Sichuan Basin, southwest China, it is suggested that the shale gas examined in this study is most likely generated in semi-open systems rather than in a closed system. In other words, the early-generated gas has been expelled from the shales, leaving the late-generated gas from residual solid bitumen and/or kerogen as the main gas source in the present hydrocarbon system.

Hydrocarbon system of the South Caspian Depression

Actuality. The hydrocarbon generation sources in the South Caspian Basin (SCB) are located at the depth of nine or more kilometers, where the organic-rich Maikop sediments occur. The main oil-and-gas fields here are found in reservoirs of the Productive Strata (Lower Pliocene), bedding at a depth of one or more kilometers. At the same time, the significant role at the process of hydrocarbons migration from the source of their generation to the reservoirs belongs to the tectonic faults (fractures). However, the results of the research according to the latest seismic data carried out in recent years are indicated the unavailability of the tectonic faults in the SCB, which connected the hydrocarbon generation sources with the reservoirs in the Productive Strata.
 Target. The determination of the geological elements at the studied area that contributed the role of the hydrocarbon migration channels and connected generation source with reservoirs in the Productive Strata.
 Objects. The hydrocarbon generation source, hydrocarbon migration channel, tectonic faults and fractures, Productive Strata reservoirs, eruptive channels of the mud volcanoes.
 Approach. The collaboration interpretation results of the deep drilling and the seismic data by using the common depth point method.
 Results. Based on the structural interpretation results of the seismic data with high-resolution parameters, are indicated the lack of the tectonic faults which connecting the hydrocarbon generation source with reservoirs of the Productive Strata in the SCB.
 In addition, the hydrocarbons that generated in the Maikop sediments are transported to the Productive Strata reservoirs by the eruptive channels of mud volcanoes. The opinion that the process of hydrocarbon generation in the Maikop clay deposits continues to the present time and the mud volcanoes eruptive channels provide feeding of the deposits with the continuous supply of oil-and-gas was expressed. Such kind of mechanism allows to classify the deposits, that more than a century under developed in the South Caspian Depression and which located at the zone of mud volcanomaturity, to the category of replenished.

Endospores associated with deep seabed geofluid features in the eastern Gulf of Mexico.

Recent studies have reported up to 1.9× 1029 bacterial endospores in the upper kilometre of deep subseafloor marine sediments, however, little is understood about their origin and dispersal. In cold ocean environments, the presence of thermospores (endospores produced by thermophilic bacteria) suggests that distribution is governed by passive migration from warm anoxic sources possibly facilitated by geofluid flow, such as advective hydrocarbon seepage sourced from petroleum deposits deeper in the subsurface. This study assesses this hypothesis by measuring endospore abundance and distribution across 60 sites in Eastern Gulf of Mexico (EGM) sediments using a combination of the endospore biomarker 2,6-pyridine dicarboxylic acid or 'dipicolinic acid' (DPA), sequencing 16S rRNA genes of thermospores germinated in 50°C sediment incubations, petroleum geochemistry in the sediments and acoustic seabed data from sub-bottom profiling. High endospore abundance is associated with geologically active conduit features (mud volcanoes, pockmarks, escarpments and fault systems), consistent with subsurface fluid flow dispersing endospores from deep warm sources up into the cold ocean. Thermospores identified at conduit sites were most closely related to bacteria associated with the deep biosphere habitats including hydrocarbon systems. The high endospore abundance at geological seep features demonstrated here suggests that recalcitrant endospores and their chemical components (such as DPA) can be used in concert with geochemical and geophysical analyses to locate discharging seafloor features. This multiproxy approach can be used to better understand patterns of advective fluid flow in regions with complex geology like the EGM basin.

Pentagon‐Containing Doublet Graphene Fragments with Edge‐Dependent Spin/Charge Distribution

Comprehensive SummaryThe synthesis of stable open‐shell hydrocarbon system comprising of pentagon defects and zigzag edges remains unexplored, which can be considered as model compounds for unraveling the spin‐localized states in graphene edges. With concise synthetic approaches, two π‐extended fluorenyl radicals were synthesized and isolated in their crystalline state. X‐ray crystallographic analysis and studies on the magnetic, optical and electrochemical properties of neutral and charged species have revealed an interesting edge‐dependence of the spin/charge distribution, that is, the spin and charge distribution shifted from the pentagon defects to the zigzag edges with the elongation of conjugation. Such phenomenon was unprecedented for hydrocarbon radicals and can be rationalized by the recovery of Clar Sextets in the dominant resonance structures. Remarkably, one of the radicals exhibited exceptional stability in air‐saturated solutions with the half‐life time up to 260 d, thus providing opportunities for the applications as electronic materials.

Applications of an Association Activity Coefficient Model, NRTL-PA, to Alcohol-Containing Mixtures

A new activity coefficient method for associating systems, NRTL Plus Association (NRTL-PA), is developed and evaluated for alcohol + hydrocarbon systems. The method combines Wertheim’s perturbation theory using the PC-SAFT form of the association strength with Flory’s theory and a residual contribution represented with NRTL. The model is capable of accurate representation of simultaneous VLE, LLE, and excess enthalpy with the same set of parameters. The association contribution is fixed using literature values during regression to provide focus on the capabilities of combining Wertheim statistical mechanics with a residual activity model. The model is shown to be superior to the traditional NRTL model and represents accurately the increase in excess enthalpy as temperature increases. The NRTL-PA model is publicly available as an Aspen Plus user model.

The potential and mechanism of nonionic polyether surfactants dissolved in CO2 to improve the miscibility of CO2–hydrocarbon systems

Certain unique reservoir conditions and technical difficulties have greatly limited the use of CO2 miscible injection in unconventional reservoirs. Lowering the miscibility pressure to realize the miscibility of CO2 and crude oil is critical for achieving the most efficient recovery process. In this study, we investigated whether nonionic polyether surfactants could improve the miscibility of CO2 and hydrocarbons. And an improved experimental method for a quantitative evaluation of additive efficiencies in lowering the miscibility pressure was introduced for the first time. The dissolution behaviors of nonionic polyether surfactants in CO2 and phase behaviors of CO2–hydrocarbon systems with and without surfactant additives were conducted. The effects of surfactant structure and concentration and temperature on the solubility of nonionic polyether surfactants in CO2 along with the efficiency of miscibility pressure reduction for CO2–hydrocarbon systems were analyzed. The results showed that the polyoxypropylene alkyl ethers exhibited excellent potential for improving the miscibility of the CO2 and hydrocarbons, especially when low molecular weight surfactant molecules with high polyoxypropylene group content were used. The first-contact miscibility pressure (FCMP) of the mixed oil and CO2 could be reduced by as much as 22.51% with 3 wt% C4(PO)3 addition. Furthermore, a mechanistic understanding showed that the solubilization of the CO2 caused by polyether reverse micelles resulted in a reduction of miscibility pressures for CO2–hydrocarbon systems. The study results and the novel evaluation method provided guidance for designing and selecting appropriate additive structures to reduce miscibility pressures of CO2–oil systems and meet the CO2 miscible injection technology requirements.

Zones of hydrocarbons generation in the Meso-Cenozoic complex of the Black Sea-Caspian region

As a result of the studies carried out within the study area, four areas of stable subsidence (basin) were identified during the entire period of the formation of the plate cover: Karkinitsky, Indolo-Kubansky, East Kubansky and Terek-Caspian. Each of the basins is characterized by a unique evolution, which manifests itself in differences in the tectonic regime and sedimentation rates. This determined the features of the geological structure of the basins, the sources of generation within them and the critical moment characterizing the process of generation - migration - accumulation of hydrocarbons in the system. Overcoming the critical moment occurs in the centers of hydrocarbon generation, when more than 50% of hydrocarbons emigrated from the source rock and accumulated in traps. As a rule, the sources are confined to the most submerged parts of the sedimentary basin, in which the deposits are in more severe thermobaric conditions. Keywords: sedimentary basin; hydrocarbon system; generation source; plate cover; tectonic regime; sedimentation rate; basin analysis.

Modeling of hydrocarbons migration and accumulation processes in the Meso-Cenozoic complex of the Black Sea-Caspian Region

The article is devoted to the study of the processes of migration and accumulation of hydrocarbons in the Meso-Cenozoic complex of the Black Sea-Caspian region. The results of the modeling made it possible to study and model the processes of migration and accumulation of hydrocarbons in hydrocarbon systems in the Meso-Cenozoic complex of the Black Sea-Caspian region. All simulated petroleum systems are characterized by migration from the main reservoir, which lies directly above the simulated oil and gas source stratum, to the overlying ones. This is due to the peculiarities of the formation of sedimentary formations under conditions of alternating regressions and transgressions. The factor stimulating migration is the active tectonic regime of the studied sedimentary basins. Based on the modeling results, the conclusion about the wide development of hydrocarbon flow processes is consistent with the presence of multilayer deposits. It has been established that extended catagenetic zoning is typical for subsidence areas, which is due to the high rates of sedimentation and subsidence, and, accordingly, the large thickness of oil source deposits in the oil formation focus. Keywords: Black Sea-Caspian region; modeling; migration; accumulation; oil and gas source strata; deposit; sediments; organic matter.

Formation conditions and evolution of the oil and gas strata of the prospective East Siberian oil and gas province

Introduction. East Siberian Sea shelf refers to the Novosibirsk-Chukotka prospective oil and gas province. The definition of the East Siberian shelf as a prospective oil and gas province and its division into areas is based, along with the structural and geological prerequisites, on the identification of numerous bitumen occurrences in the Paleozoic, Triassic and Jurassic sediments of the Novosibirsk Islands.Aim. To construct spatio-temporal digital models of sedimentary basins and hydrocarbon systems for the main horizons of source rocks, as well as to carry out their detailed analysis based on the available information about the oil and gas content, the gas-chemical composition of sediments, the characteristics of the component composition and evolution of source rocks within the studied prospective oil and gas province. The conducted research made it possible to study regional trends in oil and gas content, features of the sedimentary cover formation and the development of hydrocarbon systems in the area under study.Materials and methods. The materials of production reports obtained for individual large objects in the water area were the source of information. A basin analysis was based on a model developed by the Equinor specialists (Somme et al., 2018) [8, 9], which covered the time period from the Triassic to Paleogene inclusive and took into account the plate-tectonic reconstructions performed by Dor’e et al. in 2015. The resulting model included four main sedimentary complexes: pre-Aptian, Apt-Upper Cretaceous, Paleogene, and Neogene-Quaternary.Results. The calculation of numerical models was carried out in two versions with different types of kerogen of oil and gas source strata corresponding to humic and sapropel organic matter. The key factor in controlling the development of hydrocarbon systems was found to be the sinking rate of the basins and the thickness of the formed overburden complexes.Conclusion. The conducted analysis allowed the most promising research objects to be identified. The main foci of hydrocarbon generation in the Aptian-Late Cretaceous and Paleogene complexes were identified, along with the area of their most probable accumulation. Significant hydrocarbon potential is expected in the Paleogene clinoforms of the Eastern Arctic. This complex is currently underestimated, thus requiring further resource assessment study. A detailed mapping of its interior structure should be carried out.