The middle Jurassic Tyumen sediments have been involved in the development of oil facilities in the territory of the Khanty-Mansiysk Autonomous Okrug — Ugra for the last decade. The Jk2-5 formation is represented by complex interlayering of poorly permeable sandy-aleurite lenses and clay barriers with low reservoir properties. Recoverable oil reserves of the Jk2-5 formation on the Krasnoleninsky arch amounts to several hundred million tons. According to the collector permeability, the reserves of the object are classified as hard-to-recover.
There are no effective technologies to involve such reserves in the development now. Standard methods of drilling and operation of inclined wells doesn't allow achieving acceptable oil production rates under these reservoir conditions.
Based on the analysis of seismic survey data, correlation of well sections, field information, a geological model of a productive reservoir on the Krasnoleninsky arch was created. The multi-step hydrodynamic calculations made it possible to clarify the parameters of the profile of horizontal wells, the number and configuration of operations for multi-stage hydraulic fracturing. Based on the results of the research, recommendations were developed to well placement, drilling and well operation for specific field areas in order to increase the oil resource development efficiency.

Hydrocarbon reserves within the middle Jurassic deposits are predominantly classified as hard-to-recover. The legislation of the Russian Federation stimulates extraction of this type of reserves by providing tax incentives, which currently make field development more attractive for oil companies. A particular interest is the Ju2 deposits of Tyumen suite because they are considered as productive almost on all explored fields. However, at the moment, the majority of deposits within this formation remain undeveloped. The main reason for this is the failure in prediction of net pay (thickness) and as a consequence mistakes in geological models for drilling production wells. This article is dedicated to the problem of spatial depositional environments prediction of the Ju2 deposits of Tyumen suite. As part of the problem solving, the geological model of studied field has been improved by integrated use of geological and geophysical information on different scales involving cutting-edge technologies in seismic interpretation.

The aim of the study was to test the method of electro-facies analysis for mapping reef structures in the conditions of the junction of the Vilyui syneclise and Aldan anteclise. The article presents the results of a study of geoelectric characteristics using the method of electro-facies analysis. The confinement of buried bioherms to fault zones has been established. Facies zones corresponding to paleographic representations of the development of the region were identified. A map of the distribution of electrofacies for the Cambrian section interval was constructed, with boundaries of the distribution of reef deposits in the aisles of the study area. A typical geoelectric section showing the geoelectric properties of a section of the West Yakut barrier reef is given.
Separation of facies based on electrical exploration data is able to provide operational information on the boundaries of the studied area. With insufficient drilling data, electro-facies analysis can speed up the interpretation of electrical exploration data.

The oil field X belongs to the category of large in terms of initial recoverable reserves, multi-layer and complex in geological structure. The US1 object accounts for 20,3 % of the initial recoverable reserves, while the selection from the initial recoverable reserves is only 11,4 %, this makes object the most promising from the point of planning further development of the field. The analysis presented in the article is aimed at identifying problems and features of the development.
During the analysis, we noted low reservoir properties of the object, high watercut of the produced products, the deterioration of the energy state of the deposits, which manifests itself in the form of a decrease in dynamic levels and a decrease in fluid flow rate. Drilling of wells, both production and injection, was carried out using hydraulic fracturing technology.
Given the fact that the deposits of the US1 object are closed, lithological shielded and are characterized by the absence of an oil-water zone, the watering of wells, according to the our opinion, is associated with pulling up water from the underlying water-saturated formation as a result of the propagation of cracks obtained during hydraulic fracturing. The reason for the deterioration of the energy state is the commissioning of injection wells using hydraulic fracturing and the withdrawal of water through hydraulic fracture in the underlying formation.

The article deals with the determination of the reservoir properties of Permian-age carbonate rocks. There is a section dissection technique, taking into account the fossil organisms prevailing for a particular geological age. It was noted a high content of silica in the lower Artinskian deposits of Toravey and Varandey fields of the Komi Republic. The presence of silicon is associated with an increase in the population of siliceous sponges during this period of sedimentation; this fact caused the maximum values of porosity and permeability in the corresponding intervals. However, this was also the reason for the high values of the residual water saturation factor and, as a result, low oil flow rates from the lower Artinskian stage. The need for detailed correlation and accounting for the content of fossils in the rocks when dissecting the well section made it necessary to systematize the available actual material on core and well testing. It became obvious that the separation of reservoirs and stages at the qualitative level isn't possible, so quantitative estimates of the parameters that are significantly different for the upper and lower Artinskian deposits and allow you to dissect the well section were proposed.

In the modern practice of gas field operation, there is a problem associated with the inflow of bottom water to the bottom hole of the well.
One of the ways to solve this urgent problem is the introduction of water isolation technologies in the development of gas fields and the use of special compositions and technological equipment for pumping liquids into the watered layers of gas wells.
The article deals with the application of a set of special technological measures, such as installation of surface equipment for working in a gas well using coiled tubing, descent of a flexible pipe through a column of pump and compressor pipes with a packer, construction of an inflatable packer, as well as the use of a selective water-insulating composition of the well by pumping it through existing perforation channels in the casing string.
Liquids based on ethyl silicate create a kind water shut-off screen between the gas- saturated and water-saturated parts of the gas well formation.

When developing hard-to-recover reserves of oil fields, methods of enhanced oil recovery, used from chemical ones, are massively used. To establish the actual oil-washing characteristics of surfactant grades accepted for testing in the pore space of oil-containing reservoir rocks, a set of laboratory studies was carried out, including the study of molecular-surface properties upon contact of oil from the BS₁₀ formation of the West Surgutskoye field and model water types with the addition of surfactants of various concentrations, as well as filtration tests of surfactant technology compositions on core models of the VK₁ reservoir of the Rogozhnikovskoye oil field. On the basis of the performed laboratory studies of rocks, it has been established that conducting pilot operations with the use of Neonol RHP-20 will lead to higher technological efficiency than from the currently used at the company's fields in the compositions of the technologies of physical and chemical EOR Neonol BS-1 and proposed for application of Neftenol VKS, Aldinol-50 and Betanol.

In the article, the author conducts a qualitative and quantitative analysis of parametric diagnostics techniques of the technical condition of centrifugal blowers of natural gas. He reveals the advantages and disadvantages of the techniques. In addition, he determines the direction of eliminating the main drawback of the techniques; it is their low accuracy.

In conditions of declining production and significant watercut in most of producing oil fields in Western Siberia, secondary recovery methods such as waterflooding are ineffective. Promising methods for increasing oil recovery are chemical enhanced oil recovery methods such as surfactant-polymer (SP) flooding. Designing the chemical composition for SP flooding one should take into account the geological, physical and geochemical features of the oil field: reservoir temperature, composition and properties of reservoir fluids and rocks. The aim of the article is to create the optimum formulation of surfactant-polymer system for certain oil field in Western Siberia. The integrated laboratory studies are conducted to prove successful of SP formulation. The aqueous solubility, phase behavior experiment, low interfacial tension, admissible values of dynamic adsorption and oil produced (40 %) during coreflood experiments shows that SP formulation T01 meet the requirements for effective SP flooding.

The high resource potential of the Arctic determines the active exploration and development of these territories, in particular the Arctic continental shelf. The development of offshore fields is directly related to the issues of marine communications construction and operation in freezing waters. They are associated with minimization of environmental risks, reducing the cost of construction work, and ensuring reliable operation of underwater systems. The ice loads, especially, loads from ice gouging are considered one of the most significant loading conditions for such systems. Deformations of the soil around the pipeline during gouging may cause unacceptable deformations as a result of bending, which may lead to emergency situations. The article discusses the main features of ice gouging and the development of research and assessment methods for ice gouging impact on offshore pipelines. The article also provides the analysis of the research methods, their applications and limitations, and points out further research directions.

Nowadays the share of hard-to-recover reserves is growing, and to maintain oil production on necessarily level, we need to involve hard-to-recover reserves or to increase oil production efficiency on a brownfields due to enhanced oil recovery.
The efficiency of enhanced oil recovery can be estimated by oil saturation reduction. Single-well-chemical-tracer-test (SWCTT) is increasingly used to estimate oil saturation before and after enhanced oil recovery application. To interpret results of SWCTT, reservoir simulation is recommended.
Oil saturation has been calculated by SWCTT interpretation with use of reservoir simulator (CMG STARS).
Distribution constants has been corrected due to results of real core sample model, and core tests has been successfully simulated. Obtained values of oil saturation corresponds with real oil saturation of samples.
Thus, SWCTT as a method of oil saturation estimation shows good results. This method is promising for enhanced oil recovery efficiency estimation.

As the title implies the influence of the electrolysis on the nature and magnitude of residual stresses in the steel base and the chrome coating during restoration of parts has been considered. It has been shown that with an increase in compressive stresses on the surface, a decrease in tensile stresses in the chromium deposit and transition of tensile stresses to compressive ones near the boundary of the base are observed. A correlation between the parameters of the crystal lattice of electroplated chromium and the steel base has been established. The values of the tensile residual stresses in the chromium deposit decrease with increasing the compressive residual stresses in the base.

The article identifies the factors that affect the electrical conductivity of the soil. The most common methods of implementation of the grounding system, used in cold regions in permafrost conditions, are considered. A new design of the anchor electrode has been developed to prevent the ejection of the ground rod due to the effect of frost heaving of the soil. This article aims to describe the factors that should be considered when planning a grounding system for permanent and temporary installations in regions where there are seasonal frosts and permafrost.