The work is connected with geological features of deep-marine channels in the case of oil fields of Nadim-Purovsky region. The aim was to understand the geological features with the help of geological and geophysical data in order of stiffening the value of consistency of the data.
On the basis of core analysis, well logging and seismic interpretation it was claimed that the geological concept is connected with the multiple aggradation cycles with the lateral migration. This claim was used in a found of geological model with the purpose to exclude the non-physical ways to history matching.
The results of the work can be used for the same geological objects with the purpose of considering the accurate ways of start and cumulative fluid production, pressure maintenance, infill drilling and well completions.

Nowadays Western Siberia is still the main oil and gas basin of Russia. However, shortage of perspective recourses in traditional reservoirs and traps leads to active search of new perspectives in nonanticlinal traps. In this case, studying of Achimov sediments is very interesting to hold production oil capacity on the necessary level. It is very important to collaborate all project connected with Achimov formation and recognize its key problems and uncertainties in all scales of studying in order to make optimal exploration program and economically profitable development of these reservoirs in the Company.

In most cases, the existing simplified geological models do not correspond to the current level of geological knowledge. The authors also faced such contradiction when calculating the reserves of BP₁₂ horizon of the Vyngayakhinskoye field.
The productive layers of the BP₁₂ horizon were plane-parallel according to well logs in previous works. However, the new drilling started to contradict the existing geological model.
Clinoform structure was confirmed as a result of a new seismogeological interpretation of the horizon internal structure. Different seismic attributes taken directly from the reflective horizons BP₁₂¹, BP₁₂² and BP₁₂³ (BP₁₅) used to outline lithological bodies. Well correlation was performed taking into account all seismic data.
Generalized facies maps for the layers give a presentation about the distribution of the thickness and reservoir properties in traced lithological bodies.
A more correct estimation of hydrocarbon reserves of BP₁₂ horizon was made using geological model based on local facial patterns.

The article indicates example of complex data analysis for geological structure comprehension for U1 reservoir of Vasuganskaya formation. Special attention gives to Facies analysis which defines reservoir characteristics. Different seismic facies zones and prediction of reservoir net sand are based on dynamic interpretation of seismic data. Estimation of reserves was calculated on uncertainty parameters. Methodology is actual for optimization field development system and searching for new drilling sites.

The main aspects of seismic attributes analysis application at geological modeling are considered. The conceptual geological model is positioned as complex idea of geological characteristics of the field and generalizes sedimentatsionny, petrophysical and seismofacial models which creation is based on the analysis of seismic attributes. Application of different attribute analysis types allow to create the model which is a basis for creation of the integrated concept of field research and exploration. It is also possible to specify values and ranges of uncertainty of capacitor parameters of layer and the parameters characterizing quality of a deposit and to estimate field reserves.

In order of static reservoir model creation detailed analysis of core description and determination of mineral-structural features of rocks and their correlation with results other studies is required.
A template for representing the results of thin section analysis in numerical form proposed. Analysis of petrographic data carried out using this template is the basis for construction lithologic sedimentation models of carbonate reservoirs. An algorithm for processing petrographic data and its correlation with petrophysical parameters has developed. The proposed algorithm makes it possible: to select lithotypes based on numerical parameters of mineralstructural features of rocks, identify the lithogenetic factors that affect reservoir properties and highlight significant facial features of the rocks, creating an objective basis for constructing conceptual and static models.
An example of proposed method approbation for one of the carbonate assets of PJSC Gazprom Neft is given.

It is known the interest to carbonate fields is getting stronger. At the same time requirements of comprehensive approach to investigation for such fields are increased. Usage of typical metods of logs interpretation for carbonate formations can cause a high level of uncertainty in future. The main ghoal of petrophysics in terrigenous formations is geological while in carbonate formations petrophysics strongly influence on reservoir engineering. Significant heterogeneity in vertical and lateral directions increase the number of petrophysical parameters. Neglecting of these parameters can cause failure in yield achievement. There are three problems appeared during the field development became reasons for this work: 1. First problem connected with significant vary in wells yield (from 200 m³/day to 2000 m³/day). It is known facial analysis of carbonate formations is a complex problem due to different secondary processes. Therefore the next ghoal was set – try to find regularity in logs data. 2. Typical approach to net thickness estimation by porosity cut-off criteria had mistakes, thus, don’t suit for carbonate formations. The perforation of non-reservoir by logs interpretation was held relying on master log. As the result well inflow was increased. 3. The last problem was connected with intensive fall of reservoir pressure. Taking into account depletion regime of field development the reservoir pressure is a crucial parameter.

The article presents a mathematical model of the inflow to the fracture on PEBI grids. In the proposed approach, the fracture is represented as a set of faces, where each face has its own properties (permeability, width, cross-sectional area). A well corresponds to a node from which a fracture or several fractures emanate at specified angles. The boundary condition at the node is a constant pressure or a constant flow of liquid. Flows from the cells to the faces correspond to flows from the matrix to the fracture, additional flows are recorded in the fracture itself through the faces to the well, taking into account its conductivity.

For various reasons at each stage of the creation of the reservoir simulation model, errors may occur. As a result it leads to the deterioration in the quality of the model and decrease its forecast abilities. The article describes typical errors that occur during the transition from the geological model to the simulation model, and also gives recommendations for identifying and correcting such errors.

When designing oil treatment facilities in order to increase the efficiency of field development, increase output and reduce oil losses, it is necessary to envisage processes for extracting heavy hydrocarbons from associated petroleum gas and returning them to oil, provided that the requirements for saturated vapor pressure of commercial oil are met. Comparison of heavy hydrocarbon separation technologies from low-pressure gas determines the choice in favor of the absorption method as compared to low-temperature separation. Despite the lower amount of hydrocarbons recovered, the absorption method has better economic indicators: lower total cost of ownership (capital and operating costs), positive net cash flow.

Currently, one of the most actual directions of development of oil and gas companies (both operators and service companies) is the transition to the integrated operations management. Reducing investment to operations support while maintaining or even improving the quality of this support is the main aim of companies in the implementation of this transition. This goal could be achieved as a result of a significant increase in labor productivity in a fairly short period of time, as well as providing continuous real-time engineering support of complex operations. A distinctive feature of the integrated operations management system is their specificity: there is no universal effective model of IOMS and every company is faced with the task of developing its own model taking into account the specifics of its production, organizational structure and approaches to real-time decision-making. At the same time, the basic principles of integrated operations management system are universal and could be applied for creation of any integrated operations management systems.
This article presents the main principles of the integrated operational management systems on the example of realized project of construction of the drilling operations support center of Gazprom neft group.

At this paper described a common approach for reservoir complexity index calculation for field development. This approach is a further evaluation of method that was described early in one of previous works. Reservoir complexity index which calculated based on probabilistic estimates and machine learning algorithms helps to get a potential achievable recovery factor estimation.

The development of the Arctic offshore fields requires special approaches to the issues of operational safety on offshore platforms. The success of the development of the Prirazlomnoye oil field can serve as an example for other promising assets in this region. The implemented solutions on the Prirazlomnaya platform in terms of ensuring integrated production safety give an idea of how much attention is paid to these issues in the company Gazprom Neft Shelf. Absolute provision of integrated security on the platform is one of the main goals of the company.