Introduction and aim. An important task in assessing well interventions (hydraulic fracturing, repeated hydraulic fracturing), assessing the state of hydraulic fractures, the energy state of the reservoir, and assessing the volumes of drained reserves is to provide high-quality input information about the “reservoir-wellbore” system. To solve such problems, well testing is used, the duration of which can be limited by both geological features of the field structure and economic factors.

Materials and methods. In order to increase the information content of the studies, alternative tools for processing well testing data are used. Such tools require the use of permanent bottomhole pressure and temperature monitoring systems, as well as permanent well flowmeters for correct determination of the well stream fractional composition (these can be stationary multiphase flow meters or mobile metering complexes). One of such tools is deconvolution. Deconvolution converts previously recorded bottomhole pressure at a changing rate into a constant-rate pressure profile, i.e. into a pressure level-offcurve with a duration equal to the entire well operation history. The resulting pressure curve is then processed using traditional well testing methods, including changes in gas properties.

Results. The paper describes examples of applying deconvolution on real well data from one of the ROSPAN INTERNATIONAL license blocks.

Conclusion. Recommended for use under applicable conditions.

Introduction. Dynamic analysis is an important tool for reservoir properties prediction. Usage of its results is tied to the quality of the initial seismic data. If there are several seismic surveys with various processing graphs, it is necessary to normalize signal amplitudes values.

Aim. The aim of the work is dynamic analysis results adaptation (based on seismic surveys from different years) to predict the perspective turbidite fans’ boundaries within the Achimov complex interval.

Materials and methods. An experiment with seismic attributes normalizing was conducted to identify the optimal solution for reservoir forecasting for three different layers, depending on a set of factors on one of the oil fields in Yamalo-Nenets Autonomous District. The quality control was based on the identified anomalies (conducted by normalized attributes) verification with well data, as well as 3D seismic data at a neighboring site.

Results. Based on the experiment results, optimal parameters for the attributes normalization within the framework of dynamic analysis were found in order to obtain a qualitative & quantitative reservoir distribution forecast within the Achimov formation in conditions of limited geophysical data maturity. According to the results of obtained maps comparison with the calculated attributes within the arrays of 3D cubes in the neighboring area, the attribute anomalies on the map correspond to the conceptual continuation of the turbidite fans, clearly expressed in the wave pattern in 3D seismic data (common depth point).

Conclusion. Proper attributes selection and amplitudes normalization during dynamic analysis in conditions of limited study allows obtaining a geobodies propagation forecast, which is compared with the conceptual representation, borehole data and anomalies obtained at a neighboring 3D seismic data. Some recommendations for attributes normalization for various external factors have been developed.

Introduction. Modern methods for calculating the elastic properties of rocks range from empirical regressions to complex theoretical models that take into account the mineral composition and fluid. The analysis of these relationships forms the basis for interpreting seismic inversion data, however, the variety of approaches makes it difficult to choose a model, and numerous parameters introduce uncertainties.

Aim. Automation of the petroelastic modeling process using the global stochastic optimization method and development of optimal petroelastic models for deposits of accretion systems.

Materials and methods. The study was performed for the layers of the AS group of the Cherkashinsky formation (a deposit in Western Siberia). The algorithm of differential evolution is applied, which allows to obtain the parameters of the model with minimal error.

Results. Optimal petroelastic models are constructed for both variants of the volumetric model — full and truncated. The quality metric demonstrated a close correlation between the modeled and recorded data, confirming the effectiveness of the proposed approach.

Conclusions. The differential evolution method has proven its applicability for automated tuning of petroelastic models, ensuring reproducibility of results and reducing the subjectivity of manual parameter selection.

Introduction. This paper discusses the application of forward stratigraphic modeling as part of an exploration program development. Geological process modeling is aimed at reconstructing reservoir architecture through algorithms that simulate natural processes. The results provided make it possible to evaluate different variants of lithology distribution of the Achimov formation and predict zones of development of promising oil and gas deposits in areas that are not well explored.

Aim. The aim of the work is to predict the distribution of potentially promising objects confined to lithological traps.

Materials and methods. One parametric well and one exploratory well have been drilled in the area under consideration, and the work area has also been covered by 2D seismic exploration. In this work, forward stratigraphic modeling of deep-water floor fans and landslide complexes of the Achimov formation in one of the areas of the Western Siberian oil and gas province was carried out.

Results. As a result of modeling, it was possible to determine the sources of sediment transport and sources of deposition, and to map the boundaries of landslide objects and deep-sea floor fans.

Conclusions. Creation of dynamic models reflecting the processes of formation of deposits is a relevant tool to improve the understanding of the formation of oil and gas traps. Implementation of the new algorithm can improve the reliability of geological models and open new opportunities for hydrocarbon field discovery.

Introduction and aim. In a situation where the structure of oil and gas reserves is becoming more complex, there is an increased need for prompt development management based on mathematical modeling and for reducing the uncertainty of modeling results. In this regard, the development of modeling methods based on the analytical physically meaningful CRM (Capacitance Resistance Model) material balance model is relevant. The purpose of this article is to provide an overview of the original methods based on the CRM model for solving the problems that arise during the development of oil and gas-oil deposits.

Materials and methods. The studies were conducted using actual and synthetic data. The developed methods are based on the analytical model of the CRM material balance and its modifications, and cover a wide range of practical tasks.

Results. The presented methods allow to solve the following tasks, namely: the separation of production and injection by reservoirs, modeling of the operation of wells of the sub-gas zone, mapping of reservoir pressure, forecasting of water cut, and accounting for geological and technological measures. Also given are methods that allow to increase the cost-effectiveness in solving optimization problems.

Conclusion. The developed methods are recommended for use in the development of oil and gas-oil deposits, including for solving operational tasks. CRM modeling, taking into account its functionality, can play a key role in the technology of multi-level modeling, which is aimed at improving the quality of decisions made in the development of fields.

Introduction. The article raises the issue of correct assessment of water saturation based on electrical logging data in intervals of clayey sandy-siltstone reservoirs. The combination of clay component and low mineralization of pore waters causes the effect of additional conductivity in terrigenous reservoirs. This leads to the need to adjust the classical Dakhnov–Archie equation, which in practice is done using semi-empirical models with a number of uncertainties.

The aim of the experimental part of the work is to test the hypothesis of the influence of formation water mineralization on the parameters “m” and “n” of the Dakhnov–Archie electrical model under various conditions: atmospheric and formation thermobaric. The theoretical part is devoted to the development of a method for empirical modification of the Dakhnov–Archie equation.

Materials and methods. The paper presents unique results of a laboratory study of the electrical properties of clayey sandstones of the Achimov formation. The studies were conducted under thermobaric conditions using an individual PCRI-807 capillary meter manufactured by Weatherford Laboratories using a cyclic program with a change in the mineralization of the formation water model. The ranges of mineralization changes were from 3 to 200 g/l under atmospheric conditions and from 3 to 10 g/l under thermobaric conditions.

The results of the work are presented in the form of diagrams and the identified patterns of variations in the parameters of the Dakhnov–Archie electrical model. The correlation dependencies of the parameters “m” and “n” on the resistivity of the formation water models are demonstrated.

Conclusion. Based on the identified patterns, a method for modifying the Dakhnov–Archie electrical model has been developed and resented, which may be in demand in cases of complex geological conditions with proven variability of formation water mineralization.

Introduction. The article discusses the main parameters of preformed particle gel injected into the reservoir for conformance control. One of the most important characteristics for its effectiveness is the swelling time. A detailed description of the effect of parameters on the swelling time requires significant time, because of which the use of empirical correlation dependencies is considered relevant.

The aim of the work is to study the swelling process of preformed particle gel and obtain quantitative dependencies on the main influencing factors.

Materials and methods. A methodology for determining such dependencies is proposed, based on the least squares method and containing the completion of missing data using one-parameter correlation polynomial dependencies with a fixed value of other parameters. The main control parameters are distinguished — the salt concentration, its temperature and the weighted average particle size in the initial state. The transition to a dimensionless form is carried out to obtain universal correlations.

Results. A ternary diagram is constructed for the correlation dependence of dimensionless swelling time on the dimensionless control parameters. The obtained dependences approximate the experimental data with satisfactory accuracy.

Conclusion. The proposed method for obtaining correlation dependencies reduces the number of experimental studies by interpolating the available data maintaining the interpolation polynomial order. It was found that the initial weighted average particle size affects the swelling time to the greatest extent compared with other parameters, and with an increase in the initial weighted average particle size, the swelling time increases, since a large particle needs to absorb more water.

Introduction. The article is devoted to the problems of reducing annual oil production levels and a negative trend in the oil recovery factor in Russia and the Khanty-Mansiysk Autonomous District. With the increase in drilling volumes, there is a decrease in the average oil production rate, which indicates a deterioration in the quality of the productive reserves. There are the field maturation, deterioration of the structure of residual reserves and an increase in the share of hard-to-recover reserves that are affected. A promising direction for increasing the profitability of field development and operation is the systematic use of technologies for physical-chemical methods and hydrodynamic EOR, which do not require significant capital investments due to the existing production and social infrastructure on current assets.

The aim. To show the need for a systematic and scientifically based application of EOR and well intervention as one of the important areas of energy sector development in the medterm.

Materials and methods. The paper is based on the analysis of the dynamics and depletion of reserves, calculation of the increase in recoverable reserves, and the results of technological and economic effects from the implementation of various technologies for physical-chemical methods and hydrodynamic EOR. The objects of research are the deposits of the Megion group, which are at the III and IV stages of development.

Results. The necessity of using physical-chemical methods and hydrodynamic EOR is substantiated in order to stabilize the level of oil production, reduce the rate of waterflooding, increase recoverable oil reserves, and reduce operating costs. There are considered the physical-chemical methods and hydrodynamic EOR in terms of ease of implementation, technological efficiency and early payback. The results of using various EOR technologies at the deposits of PJSC Slavneft-Megionneftegaz based on system-targeted approaches are shown.

Conclusion. It is shown that the implementation of physical-chemical methods and hydrodynamic EOR based on the system-targeted approaches on the reservoir in conditions of low permeable reservoirs and high water cut wells contributes to an increase in the efficiency of developing hard-to-recover reserves, increasing oil production and stabilizing the water content of deposits.

Aim. This article is devoted to the study of the phenomenon of self-flowing through annulus in wells equipped with electric submersible pumps (ESP). The main task of the study is to find dependences for determining the fluid partition coefficient between the annular space and tubing during self-flowing taking into account the influence of ESP performance degradation.

Methods. The authors applied a complex approach including theoretical analysis, laboratory studies, numerical modelling and processing of data obtained from a real well. Within the framework of the experimental part, bench tests were carried out, which allowed to establish new dependences of the liquid partition coefficient on the flowing gas content. The developed algorithm for estimating the fluid partition coefficient provides an opportunity to quantify the redistribution of phase flows, which is important for optimising the operation of downhole equipment. Numerical simulation allowed to identify the key parameters influencing the occurrence of selfflowing through annulus, as well as to simulate the behaviour of the system under different operating conditions.

Results. Experimental data confi rmed the existence of a relationship between the gas content in the flow and the gas-liquid mixture (GLM) distribution between the annulus and the tubing. The modelling results indicate that it is possible to estimate the fluid partition coefficient for given boundary conditions. Analysis of highly discrete telemetry data and multiphase flowmeter measurements from Western Siberian fields confirmed the reliability of the developed model.

Conclusion. Implementation of the obtained solutions and optimisation of electric submersible pumps operation can help to prevent abnormal operation modes and improve the overall efficiency of mechanised hydrocarbon production. The proposed methodology can be used to develop new recommendations for well operation, which is of practical importance for the oil and gas industry.

Introduction. Currently, to create a technology for thermochemical effects on kerogen-containing rocks, the main research is focused on the creation of equipment (a supercritical water generator), the study of problems of coolant delivery to the reservoir (development of an intra-well layout that minimizes heat loss from the mouth to the bottom of the well), determining the volume of kerogen-containing rocks, calculating the volume of production of man-made oil obtained during retorting kerogen. This article is intended to draw the attention of researchers to the complications that may arise during the extraction of man-made oil, as well as their impact on field management systems during production (in-field collection, preparation and external transportation of oil).

Aim. To describe the prerequisites for the creation of a pilot plant for the technology of thermochemical effects on the reservoir using a ground-based supercritical water generator, describe the main objects of engineering research, determine criteria for selecting bush sites for the use of technology on them, identify complicating factors that must be taken into account when designing infrastructure facilities, formulate key indicators for assessing the technological readiness of the project for the full-scale implementation of technology for the results of pilot industrial tests.

Materials and methods. The research consisted in generalizing and analyzing the world experience in the application of thermochemical treatment technology to the reservoir during downhole retorting of kerogen. The paper uses computer modeling of the properties of structural materials that can be used for downhole arrangements when pumping supercritical water, as well as modeling changes in pressure and temperature of supercritical water along the length of the well.

Results. The research revealed the advantages and disadvantages of downhole and onshore heat generation plants, listed the main complicating factors that may arise during the extraction of man-made oil and have a negative impact on field management systems during production, which must be taken into account when designing the technological infrastructure of the field. Based on the work carried out, the main directions of further engineering pre-design studies are formulated.

Conclusions. A checklist of the results of pre-design studies has been developed, which is recommended to be carried out before designing the infrastructure for pilot testing of thermochemical impact technology on the reservoir, as well as to take into account the timing of technology implementation when planning them. It is proposed to create an industry integrator to consolidate the competencies and experience of oil companies in this area.

Introduction. Eastern Siberia is a strategically important region for the country’s economy and companies operating in the oil and gas sector. Efficient development of the resource base is limited by the low level of infrastructure development and high load of existing export channels. The development of the vast territory of Eastern Siberia is a significant investment and therefore requires a systematic approach to obtain the best possible effect.

Aim. The aim of the work is to develop a methodology and a tool for assessing the potential of oil and gas infrastructure in Eastern Siberia and prioritizing the directions of infrastructure development.

Materials and methods. The work applies a systematic approach using the methods of conceptual engineering of infrastructure. A methodology for constructing heat maps of infrastructure using automation of spreadsheets and geoinformation analysis in “QGIS” software has been developed and implemented.

Results. Heat maps of minimally profi table cumulative production for different scenarios of fluid saturation (oil, gas, mixed) have been created, reflecting the current and future state of infrastructure. Key zones of investment attractiveness are identified, and the impact of tax regimes on profitability is summarized.

Conclusion. The proposed tool and methodology allow infrastructure zoning of Eastern Siberia, which helps to make informed investment decisions in the field of hydrocarbon production. For accelerated development of the region it is recommended to introduce tax preferences, develop social and transportation infrastructure, and search for synergies between facilities.

Introduction. The concept of pore connectedness (CPC) has been successfully using for the last 10 years in the perimeter of the Gazprom neft companу group for petrophysical modeling of the filtration and capacity properties (FCP) of oil and gas reservoirs. During this time, an extensive information base on the objects of petrophysical modeling has been accumulating. Because of systematization of the experience gained, the basic mathematical patterns were optimizing. In some cases, it was possible to establish functional dependencies between the constants of the models, which made it possible to reduce the number of determining parameters in the equations used and increase their versatility for describing the reservoir properties of rocks of various genesis.

The аim of this work is to modify the mathematical apparatus of the CPC to improve the efficiency of petrophysical modeling of the filtration and capacity properties of rocks.

Materials and methods are basing on the analysis of the key results of constructing petrophysical models of the FCP of productive deposits for more than 80 fields located in the main oil and gas provinces of the Russian Federation.

Results. Modified equations of the CPC for description of reservoir properties.

Conclusion. The modified equations allow more efficient descript of reservoir properties behavior, using a relatively small number of input data. The universality of the obtained regularities for different types of deposits, as well as the identity of the determining constants for deposits — petrophysical analogues are noted.