Introduction. The Salair part of the Omorinsky license area is located southeast of the Yurubtchen-Tokhoma oil and gas condensate field. In paleostructural terms, it is confined to the transition zone from the shallow-shelf Riphean deposits of the Kamo Arch to the powerful deposits of the Irkineeva-Vanavara intracratonic depression. In the period 2006-2012, exploratory drilling and 3D seismic exploration were carried out here.
Aim. The goal of this work is to present the results of interpretation of seismic data obtained from reprocessing.
Materials and methods. The 3D seismic survey produced heterogeneous data using both explosive and pulsed sources. In 2020, reprocessing seismic data was carried out in a single graph. The processing step of seismic date in the time domain was implemented including PrSTM migration. The used graph based on advanced 3D technologies and an iterative approach made it possible to solve the main problems of the project in the time domain. The quality material was obtained as a result of the performed processing. Update seismic date made it possible to characterize the architecture of the margin of Rifean carbonate platforms with a high degree of detail and reconstruct the history of their development.
Results. Within the Salair part of the Omorinsky license area in the interval between the reflectors R3 and R4, uncluding the Madrа, Yurubtchen and Kuyumba Formations of the Middle Riphean, three 2-nd order sequences are identified with the consistent development of carbonate platforms. These sequences are well distinguished and traced in seismic lines due to the high contrast of seismic recording.
Conclusion. Materials from the Salair part of Omorinsky license area demonstrate that modern 3D seismic is an efficient approach for studying the morphology and history of the formation of such complex and large-scale Precambrian sedimentary bodies as Riphean carbonate platforms. The 3D seismic survey makes it possible to outline sedimentary system tracts in detail, identify sequence boundaries and reconstruct the architecture of sedimentary bodies in the margin zones of Riphean carbonate platforms.

The article presents the results of updating the geological and hydrodynamic model of the V5 formation.
The aim of the work was to improve the forecast of filtration and reservoir properties and development indicators using a geological and hydrodynamic models.
Materials and methods. Reference wells with core and well logging were used as initial data. According to core data, a correlation between absolute permeability and the granulometric composition of rocks was revealed. The double growth parameter of gamma ray logging was used as a parameter responsible for granulometry. The model of the porosity-permeability relationship is adopted according to the concept of pore space connectedness.
Results. The refined dependence of permeability calculation was successfully applied in geological and hydrodynamic modeling. Based on the results of well adaptation, a decrease in the dispersion of permeability multipliers is observed.
Conclusion. The obtained results confirm a significant improvement in the prediction of the hydrodynamic model when using this approach.

Probabilistic modeling of the geological model is an integral part of the development concept. The choice of final geologic model realizations corresponding to the P10, P50, P90, probability percentiles in probabilistic modeling affects the predicted production profile, so it is very important when selecting a realization to assess how accurately it reflects reservoir properties and accounts for uncertainties in both static and dynamic characteristics.
A large number of faults, resulting in deposits with complex block structure, characterizes East Siberian fields. This factor should also be taken into account in the selection process to ensure compliance with the percentiles of the distribution of counting parameters for each block.
The aim of the work is to select representative geologic realizations P10, P50, P90, from the pool of calculated models.
Materials and methods. This paper presents results of multivariate modeling for probabilistic estimation of reserves of the Botuobinsky horizon in one of the fields of Eastern Siberia using the Geoscreening tool in the Petrel software. The main peculiarity of the realized approach was a complex estimation of static and dynamic uncertainty parameters at the stage of multivariate model calculations.
Results. When analyzing the results obtained, the range of acceptable deviations from the values corresponding to the percentile of probability P10, P50, P90 was determined and the realizations falling within this range were selected for each block by such parameters as total hydrocarbon saturated volume, associated pore volume, initial geological oil and gas reserves and basic calculation parameters. Stress tests on the hydrodynamic model were performed, confirming the hypothesis that dynamic characteristics should be taken into account at the stage of multivariate calculations for probabilistic evaluation.
Conclusion. The tested methodology using the Geoscreening module allowed to select cases that most accurately correspond to the given percentiles of distribution for all parameters and optimize the time and number of calculations on the hydrodynamic model.

Background. A detailed structural framework and an understanding of the tectonic development history of the area are of particular importance in predicting the filtration-capacity properties of secondary reservoirs. The structural framework is based on seismic data. Even high-quality seismic data have limited information value, especially in complex seismic and geologic conditions. In such a situation, together with the classical structural seismic data interpretation, one can use the technique of structural-kinematic modeling [5], which makes it possible to predict the structure of geological objects within low-information areas on the basis of kinematic algorithms of structure formation. Such complex objects include the Kamovsky Arch of the Baykit Hight province, within which fields have been discovered whose reservoirs are represented by highly transformed fractured Riphean carbonates. The construction of the structural framework of the Baykit Hight province using the structural-kinematic modeling methodology is the first stage of building a model filtration-capacity property of the Riphean reservoirs.
Objective. To determine the key stages of tectonic development and associated paragenesis of faults and fractures within the Kamovsky Arch and adjacent territories.
Materials and methods. Data on the regional structure and development of the Siberian Platform, the Baikit Hight, the Kamovsky Arch and adjacent territories, 2D/3D seismic data, drilling data were used as source materials. As the basis of the work, a complex method of structural and tectonic analysis was used, including analysis of the thicknesses of stratigraphic units, mineralogical composition of sedimentary and magmatic formations, modeling of kinematics of formation, development and reactivation of faults (structural and kinematic modeling technique).
Results. As a result of the application of the method of structural-tectonic analysis 4 major tectonic stages were identified within the territory of the Kamovsky Arch. The structural-kinematic model of the territory development has been created and the main fault systems have been identified.
Conclusion. As a result of combining the standard seismic data interpretation with the structuralkinematic modeling technique, a reliable structural-tectonic model of the Baykit Hight province with detailed characterization of the main stages of the territory development was obtained. The results obtained are the basis for modeling the stress-strain state of the rock massif and determining the main directions of vectors of tectonic transport at different stages of development of structures controlling the distribution of filtration-capacity property Riphean reservoirs.

Introduction. Secondary changes in Vendian clastic rocks significantly affect their reservoir properties and are one of the factors complicating the oil and gas forecast of terrigenous reservoirs in the fields of the Chona group.
Aim. Qualitative and quantitative assessment of secondary transformations in rocks and their correlation with petrophysical parameters.
Materials and methods. The objects of study — Vendian clastic rocks, studied by a complex of lithological methods: petrographic, X-ray diffraction, granulometric.
Results. Interpretation of analytical data from core studies of terrigenous reservoir rocks of the B13 formation made it possible to identify the sequence of staged secondary processes in Vendian clastic reservoir rocks and evaluate their role in the formation of reservoir properties (RP). The role of primary (sedimentation) and secondary (epigenetic) factors in the formation of RP is assessed. The cyclical nature of secondary processes, translating sedimentary cyclothems, is noted.
Conclusion. The correlation of primary and secondary material-structural features of rocks with capacitive space indicates a complex genetic relationship of all lithogenesis processes in the formation of Vendian terrigenous reservoirs.

Introduction. Recent advances in the interpretation of seismic data are associated with inversion transformations of seismic data. Seismic data can be studied and interpreted by themselves, without the use of inversion, however, this does not allow us to get the most detailed idea of the structure of the formation, and under certain conditions can lead to an unreliable result. Due to the efficiency and quality of seismic inversion, currently most oil and gas companies use inversion technologies in order to increase the resolution of seismic data and increase the reliability of forecasts, increase the reliability of the assessment of filtration-capacitance properties of rocks, including porosity and effective thickness.
Goal. In order to obtain a forecast of the distribution of low-power reservoirs of terrigenous deposits in Eastern Siberia, dynamic analysis tools were evaluated and the optimal method was selected.
Materials and methods. In order to understand the possibility of seismic exploration and evaluate its predictive capabilities, petroelastic modeling was performed and a wedge model was constructed. Testing of various attribute analysis tools, such as the construction of attributes by the total cube, by cubes of elastic parameters, has been implemented. Synchronous inversion was calculated, its interpretation was carried out by the Bayesian classification of cubes of elastic parameters, and the collector probability cube was obtained at the output.
Results. As a result of the work carried out, it was found that the classic attribute approach is not suitable for low-power collectors of Vendas. The selection of a suitable calculation window or attribute is a labor-intensive and inefficient method of obtaining the trend of the spread of effective thicknesses in the inter-well space. The probability cube of the collector and the map based on probability cut-offs are the most optimal option.
Conclusion. Seismic inversion as a tool for detailed geological modeling on the example of an oil field in Eastern Siberia has shown the effectiveness for the prediction of low-power reservoirs.

Aim. The article presents selected results and techniques developed in the process of drilling horizontal wells and fishbone wells in an oil and gas condensate field in Eastern Siberia.
Materials and methods. The risk analysis of the intrusive bodies and traps presence in the drilling area was carried out, the design petrophysical model has been refined, and corrections for gas in high-permeability reservoirs have been substantiated and introduced. The methodology for using smart pilot wells and methodology for estimating the target flow rate in the process of drilling wells have been developed and implemented.
Results. The drilling results of more than 60 wells were analyzed and evaluated. Final experience and the analysis made it possible to increase the efficiency of drilling new wells in this field. The author’s methods for forecasting the flow rate and changing the design of wells depending on the calculated geological potential have been tasted in practice. The positive effect of this methods has been proven.
Conclusion. The experience gained and the results of the decisions make it possible to replicate the project team’s approaches to other assets in Eastern Siberia with a similar geological structure.

Introduction. For the first time, a comprehensive program for the study of terrigenous formations of the Nepa formation was implemented on the core of new wells of the Ignalinsky, Tympuchikansky, Vakunaysky sites and wells drilled before 2000 in these and adjacent areas. Secondary processes developing in the terrigenous deposits of the Nepa formation are identified and characterized, their stages are determined, the relationship with the sedimentation medium and tectogenesis processes is established, and the prerequisites for the areal forecast of zones of secondary rock change and zones of absence of such changes are described.
Aim. Identification of the patterns of the spread of secondary processes in the deposits of the Nepa formation, the degree of their influence on the properties of rocks. Determining the directions of forecasting promising areas of reservoir development.
Materials and methods. To create a detailed model of secondary changes, a core study of 17 wells drilled by Gazpromneft-GEO LLC and 46 wells drilled before the 2000s was conducted.
Results. The scheme of stages of post-sedimentation processes is proposed, taking into account the influence of sedimentation conditions, background immersion of the sedimentary basin and inversion-tectonic restructuring, accompanied by changes in water-fluid regimes; formation of tectonic disturbances, fracture zones; thermal effects of magmatic bodies.
Conclusion. Analysis of core material, Well logs data and well operation results shows that halitization, anhydritization, dolomitization and bituminization have the greatest impact on reservoir properties of the deposit. The remaining processes are developed locally at individual sites and their impact on the amount of reserves, as well as the porosity and permeability, is significantly lower. The restoration of the sedimentation history of sediments, their compaction, and tectonic movements of the territory makes it possible to predict the prospects of sites at the zonal and local levels.

The article presents the results of planning the development of naturally fractured carbonate reservoir, considering the features of its geological structure
Aim. The work was aimed at improving the forecast of the geological structure and production using the static and dynamic model.
Materials and methods. Standard input data for geological modeling and microimagers were used as initial data; the dynamic model was adjusted based on the results of well testing and production testing. A fracture network model was built, fracture permeability was calculated, which then helped to adjust permeability in dynamic model.
Results. The resulting fracture permeability map was successfully used when history matching the dynamic model. According to the results of the dynamic model calculation, an improvement in history matching and the absence of unreasonable changes in permeability multipliers are observed.
Conclusion. The obtained results confirm the improvement of the dynamic model forecast and the preservation of moderate computing time when using this approach.

The complex geological structure of the oil and gas fields of the Siberian Platform, the facies variability of the Vendian terrigenous deposits, the anisotropy of filtration and reservoir properties cause significant difficulties in allocating sites for exploration and production drilling. In such conditions, it is extremely important to create a detailed facies model based on high-quality initial geological and geophysical information to determine the minimum and sufficient drilling volume.
Goal. To create a detailed seismofacial model of the basal deposits of the Nepean formation.
Methodology and scope of research. To create a detailed facies model, a sedimentological description of the core of 17 wells drilled by Gazpromneft-GEO LLC was carried out. For 46 wells drilled before the 2000s, a detailed description of full-size core samples, reference samples and grinds was carried out. The results of the sedimentological study of the core were combined with GIS data and 3D seismic interpretation.
Results. Based on the results of core studies and 3D seismic interpretation, a detailed facies model of the B13 formation deposits has been created. Unique data on the structure of the basement and weathering crust, which have a significant impact on the structure of the basal deposits of the Nepean formation, have been obtained. The main facies types are identified and characterized. The sequence of the development of the Nepean sedimentary basin has been restored and the geometry of sand bodies has been determined. It has been established that the best collector properties (before salinization) are characterized by facies of removal cones and distribution channels, which are confidently distinguished by the core and with the help of modern 3D seismic exploration.
Conclusion. The results obtained — methods and approaches, conceptual models, dimensions of facies bodies, their connectivity and FES can be used for analogous deposits in the region in order to create a reliable predictive basis for drilling and production forecasting

Aim. The article presents the results of rock physics used to justify the value of performing seismic inversion in predicting reservoir properties in the interwell space in an oil-gas-condensate field in Eastern Siberia.
Materials and methods. As part of the work, an analysis was carried out to find the potential for predicting the reservoir properties of the target formation using 3D and well logging data. An approach has been proposed to justify the implementation of seismic inversion and its type to reduce geological uncertainties when drilling production wells. The process of constructing a rock physics model of the target reservoir is described, and various geological scenarios for modeling elastic parameters are realized.
Results. A rock physics model was built using 7 wells of the field that penetrated the target formation. The analysis of the base scenario and modeling results made it possible to assess the potential of predicting the reservoir, individual lithotypes, saturation in the field of elastic parameters, also with seismic data frequency filter, and to prepare a program for additional exploration of the field to increase the efficiency of drilling production wells.
Conclusion. The results obtained allow us to recommend calculation of simultaneous inversion to reduce geological uncertainties associated with predicting reservoir properties in the interwell space. The conclusions of this work make it possible to translate used approach to other projects in Eastern Siberia with a similar geological structure.

Introduction. More than 50 % of the world’s oil and gas reserves are concentrated in carbonate reservoirs. At the same time, they are characterized by a complex structure and strong lateral variability of sediments, since their filtration-intensive properties (FES) can simultaneously depend both on the sedimentation structure of sediments, which is decisive in the formation of FES, and on secondary processes (recrystallization, dolomitization, leaching, etc.), which enhance facies heterogeneity. One of the most important tasks in modeling such deposits is to trace productive effective thicknesses in the inter-well space. For “complex” terrigenous reservoirs, inversion and its volumetric interpretation through Bayesian classification have proven themselves well. Such approaches make it possible to restore the values of elastic properties in the target intervals of the section and to make a forecast in the inter-well space of the distribution of reservoirs and their FES. The correctness of using this approach to carbonate rocks remains a topic for discussion.
Aim. In order to obtain a forecast of the distribution of reservoirs of carbonate deposits of the Osinsky horizon of Eastern Siberia, a method for constructing a low-frequency model was developed and the optimal interpretation was chosen.
Materials and methods. Considering the features of the carbonate section, various methods of constructing the NMF have been tested and an optimal technique has been developed to preserve the geological basis of the section and remove the influence of wells on the trend. Synchronous inversion was calculated, its interpretation was carried out by the Bayesian classification of cubes of elastic parameters, and the collector probability cube for each facial zone was obtained at the output.
Results. It is established that the classical approach to constructing a low-frequency trend through well interpolation is not suitable for carbonate reservoirs, it is necessary to use the trend for more correct propagation of elastic properties. When interpreting, facies changes in the formation should also be taken into account, since in different facies the reservoir can be represented by different FES, and therefore by different elastic parameters.
Conclusion. Seismic inversion as a tool for detailed geological modeling on the example of an oil field in Eastern Siberia has shown its effectiveness for predicting FES in the carbonate interval.

Aim. In order to make a qualitative prediction of reservoir properties in the inter-well space, a lithological-facies characteristic of deposits of the Talakh horizon was performed and a seismogeological correlation of cyclites was performed within the framework of constructing a three-dimensional geological model.
Materials and methods. As a result of the lithological-facies study of the core, facies were isolated, then combined into macrofacies, of which the main macrofacies of the reservoirs were given a lithological-petrophysical characteristic. Based on the results of facies analysis, data from geophysical well surveys (GIS) and the results of seismic interpretation, two transgressive cyclites were identified, differing from each other in facies composition and petrophysical properties.
Results. On the basis of a complex interpretation of the core and GIS, the facies series of sediments within the Talakh horizon has been reconstructed, the cyclicity of the section is described, which is represented by the lower Tl2 cyclite, composed of more continental deposits of facies of alluvial and tidal channels, with an increased reservoir content and an increased porosity value relative to the upper Tl1 cyclite, which is represented by more marine deposits mainly of delta facies of tidal-low tide type.
Conclusions. As a result of the conducted studies, a detailed lithological and facies characteristic of the section within the Talakh horizon on the territory of the study area was obtained. The information obtained helped to clarify the geological structure of the object and more correctly predict the properties of the reservoir, using its own lithology and porosity trends separately for each cyclite.

One of the main geological uncertainties at the search stage is the morphology of the prospects, the presence and areal distribution of reservoir rocks and seals, and phase saturation of reservoir rocks.
Aim. The main goal of the work is to develop a methodology for the influence of electrical exploration on the chance of geological success (gCoS) in the design of geological exploration. The key objectives of the work are to test the developed methodology on the licensed areas of Gazprom-neft and implement the results of the calculation into the current decision tree of the project according to the developed methodology. The relevance of the work is to reduce geological risks and uncertainties at the search stage.
Materials and methods. An integrated approach using seismic and electrical surveys allows increasing the chance of geological success in geological exploration. To implement electrical exploration into the general decision tree, it is necessary to perform mathematical modeling. After performing the mathematical modeling a further decision is made on the feasibility of the economic evaluation of the project, taking into account electrical exploration. In this study, a case is presented that describes the impact of electrical exploration on the chance of geological success of PK (probability of having a reservoir).
Results. Based on the results of the work, a methodology for assessing the economic effect of the use of electrical exploration at the exploratory stage of geological exploration was developed and the chance of geological success (gCoS) was increased by introducing electrical exploration into the decision tree of the project.
Conclusion. The development of this direction is seen in the improvement of the scientific and methodological base for conducting modeling of electrical exploration work and testing the developed methodology for economic assessment on additional licensed areas of Gazprom-neft PJSC.

In modern practice of oil and gas companies investment decisions are dependent on indicators based on probabilistic geological calculations. Technical limitations make it necessary to discretize the space of uncertainties using few representative scenarios. This stage of work has a significant impact on the assessment of project economics.
The aim of this work is to formalize the experience on the selection of representative cases of a probabilistic geological model used for further production and economics forecasts.
Materials and methods. As part of the work, based on published works and projects carried out at Gazpromneft LLC, the main steps of choosing scenarios of a probabilistic geological model, the difficulties that arise in each of them, and ways to overcome them are formulated. A case study of selecting models for a large multihorizon field is shown. The probabilistic geological model and the selection of representative scenarios were carried out in order to plan pilot works on it. This object allowed illustrating typical questions that arise when solving the problem of finding representative realizations.
Results. The main problems of selection of representative realizations are formulated. They include unstable distribution of in-place volumes obtained as a result of probabilistic modeling; the need to take into account key alternatives when choosing a sufficient number of scenarios; ambiguity of work with distributions for complex projects (multilayer fields, with a block structure, etc.); the need to describe the space of uncertainties in terms of parameters significant for the production forecast using a limited set of models both at the integral level and at the local one. Possible solutions to these issues are proposed, as well as example based on a real object.
Conclusion. The analysis carried out summarizes the experience of solving the problem of choosing representative realizations of a probabilistic geomodel. Further development of modeling tools and computing power can significantly affect this issue.

The construction of a structural-tectonic model of the environment in the early stages of exploration is associated with significant uncertainties due to the sparse network of seismic profiles. The choice of one or another algorithm for interpolation of times and velocities of seismic waves without involvement of additional a priori information may significantly affect the result of structural constructions.
Aim. With the purpose of detailing the structural model and minimizing uncertainties and geological risks at early stages of geological exploration, we developed an approach to reconstruct the morphology of horizons in the interprofile space of seismic data, using as a priori information of modern airborne geophysical methods.
Materials and methods. To solve the problem, we used methods of machine learning with a teacher. On the model data we tested the most popular algorithms of machine learning. It was concluded about the applicability and limitations of the used algorithms. The main stages of solving the problem are described in detail. The main categories of uncertainties that accompany structural prediction, the possibilities of their identification and quantification are considered. Approaches to analyze the influence of features on prediction results are described, including for flexible machine learning models. An approach based on a heuristic search algorithm is proposed to automate poorly formatted procedures, such as feature selection and optimization of hyperparameters of machine learning models. All computations were performed in the Python programming language, using open source libraries.
Results. Using examples of model and real data, we have demonstrated a significant refinement of structural plan of the horizons, based on the prediction, taking into account a priori information, in comparison with the classical interpolation algorithms.
Conclusion. The results allow the conclusion about high efficiency of involvement of remote geophysical methods at the stage of structural analysis of the early stages of geological exploration. Such a comprehensive analysis allows to obtain a more reliable geological model, to focus the attention on the most promising objects with less geological risks when planning further detailed exploration works.

Introduction. The main technology for developing Achimov tight-oil reserves of the YNAO is hydraulic fracturing. Increasing the single frac stage efficiency requires a detailed processes consideration and a traditional templates abandonment.
Aim. Theoretical basis and the influence assessment of the frac width on the proppant crash and well productivity.
Materials and methods. The significant difference between the simulated conditions and the actual fracture geometry was determined by reviewing the approved methodology for studying proppant crash, which leads to a distortion in decision-making for design fracturing. A physical model of a discrete system is considered to assess the load distribution along the proppant pack depth.
Results. Only the first three layers of proppant are subjected to full external load in a laboratory study. The lower layer experiences a load 33 % lower than the simulated one, which distorts the understanding of proppant crash processes in a real fracturing. These findings were used to formulate a program of modified laboratory studies.
Conclusion. Approved fracture investigation techniques are only applicable to comparing different proppants among themselves, but quantitative results cannot be used in hydraulic fracturing design without adjustment for the actual propped width.

The article considers the possibility of using self-generating lightweight proppants in the process of hydraulic fracturing (fracking). The relevance of this topic is due to the lack of low-density proppants on the market, which are necessary to retain fracture openings in remote areas. Proppant generation under reservoir conditions will improve the fracturing process and provide better fracture openings compared to the basic technology.
Aim. Investigation of different polymer reagents as feedstock for the formation of self-generating proppants.
Materials and methods. To evaluate the applicability of the proposed hypothesis, a polymer base, melamine carbamid resin, and an aqueous solution of oxalic acid as a hardener were used. Self-generation of proppant was carried out on a specialized stand under conditions when there is no agglomeration of polymer granules. Evaluation of physical and mechanical properties of the obtained granules was carried out in accordance with standard methods. The proppant pack conductivity methodology was used to evaluate propping capacity.
Results. As a result of laboratory investigations, it was revealed that the polymeric proppant formed in the process of generation has poor resistance to hydrochloric acid and does not meet the criteria for geometrical shapes. The cracks filled with the cure-generated proppant have low conductivity at pressures greater than 4000 PSI. It was also found that granules obtained in the process of generation have insufficient strength characteristics (90 % of granules are destroyed at a pressure of 5000 PSI).
Conclusion. High cost and insufficient performance characteristics of the obtained self-generating proppant granules make them unprofitable as propping agents. One should keep in mind the potential possibility of using this technology in the case of selecting an alternative polymer composition that allows to qualitatively increase the strength characteristics of the resulting propping agents.

The main geophysical method to assess the porosity of the reservoir is gamma-gamma density logging. The equation of the relationship between density and porosity, among other constants, includes such a parameter as the density of the fluid in the pore space. When carrying out density logging after drilling, by the beginning of work, as a rule, a zone of penetration of drilling mud filtrate filling the pore space within the radius of the method study has time to form. However, at present, more and more geophysical studies are being carried out as part of the logging while drilling complex, which makes it possible to determine the properties of the reservoir that are not affected by filtrate. In the presence of a transition zone, the fluid density may vary depending on the ratio of the fractions of different phases, which will affect the results of porosity calculation, but in petrophysical equations, the fluid density is a constant.
Aim. To eliminate errors in the calculation of properties, it is necessary to find a way to determine the exact value of the density of the fluid mixture. The problem is complicated by the circumstance that to determine the fluid density, it is necessary to assess the reservoir water saturation, while to assess the water saturation, it is necessary to know the porosity. The interdependence of these quantities makes it difficult to construct petrophysical dependencies, and the type of functions excludes the possibility of an analytical solution of the system of these equations.
As an example, theoretical calculations illustrating the algorithm for determining properties, as well as the results of the implementation of this technique in the process of hydrodynamic modeling of one of the objects of the Vostochno-Messoyakhskoye field are given.
Materials and methods. The paper shows an algorithm for the numerical solution of such a system based on the method of simple iteration. This approach allows cyclical calculation of properties, increasing the accuracy of the estimate with each repetition.
Results. As an example, theoretical calculations illustrating the algorithm for determining properties, as well as the results of the implementation of this technique in the process of hydrodynamic modeling of one of the objects of the Vostochno-Messoyakhskoye field. The use of the algorithm made it possible to significantly improve the quality of adaptation of the hydrodynamic model without the need for local settings.
Conclusions. The only limitation of the method is the availability of density logging while drilling. The calculation algorithm does not use any complex mathematical models, which allows it to be implemented in any software product. The results obtained suggest that this method can be a reliable way to improve the quality of property assessment, and therefore improve the predictive ability of geological and hydrodynamic models.