In this work, the capabilities of the Nuclear magnetic resonance (NMR) method fordetermining the petrophysical parameters of reservoir rocks were considered. For thispurpose, rock samples from several oil fields have been investigated. NMR investigationmethod was used as one of the rapid methods for assessing the potential properties ofreservoir rocks without causing damage to the studied models. It was shown that the resultsof measurements on the cuttings agree with the results obtained by core samples. It wasrevealed that this method can be used for quantitative assessment of the content of clayminerals and determination of their type. Moreover, the nature of the dependence of the porosity parameter on the NMR porosity, which satisfies the well-known equations, has been experimentally established.

The non-Newtonian nature of fluid flow represents one of the most important features of the development of high-viscosity oil (HVO) deposits .The deviation from the linear law of the fluid flow is associated, first of all, with the formation of a strong spatial structure due to the presence of high-molecular components and dissolved gases in the composition. The stress required to destroy the formed structure is called the shear stress of the ultimate destruction of the structure. In this regard, in order to ensure the flow of HVO through the pore space, it is necessary to create certain values of pressure gradients above the dynamic shear pressure gradient (DSPG). With increasing pressure gradients above the DSPG, the oil structure begins to collapse, and after overcoming the critical value of the pressure gradient of the ultimate destruction of the structure (PGUDS), flow begins to be described by the Newtonianlaw. The article considers the influence of various factors on the oil flow rate of a horizontal well (HW) that exploits the HVO Deposit. At the same time, numerical experiments were carried out on a hydrodynamic model for the non-Newtonian oil flow regime (in the presence of DSPG) and the results obtained were compared with calculations of the oil flow rate using an analytical formula.

The transportation of heavy gas condensate through the pipeline system is conducted in accordance with the approved delivery plan, which provides for the operation of the system in various modes and circumstances. One of the main problems in transporting such gas condensate is the low (negative) ambient temperature.The results of this work are presented, on the basis of which two methods of solving the problem of transporting "heavy" gas condensates in the winter conditions of the North are proposed. The first method involves the use of overpressure, which prevents the formation of structures in gas condensates at sub-zero temperatures; the second method involves the useof a solvent than which it is proposed to use "light" gas condensates.

In terms of oilfield terminologies, separators are used to separate oil, gas, and water and to remove material such as entrained solid impurities from the crude oil produced from the wells. Optimization of separation process represents a challenging operation that can be achieved by improve the separation performance .This article is devoted to the analysis of changes in the process of separation of oil-containing liquid coming from field wells. It investigate the first stage of separation at the installation of preliminary water discharge and oil treatment, when the temperature and pressure of the liquid of the incoming medium change. It was observed that with an increase in temperature and a decrease in pressure, the process of gas separation increases.

Currently, the share of new fields in many places over the world, which are at the initial stage of development, is constantly growing.Fields often have a complex heterogeneous structure with hard-to-recover reserves, therefore, for their effective development, it is necessary to use completely new approaches, including improving existing methodsof enhanced oil recovery.In this work, experimental verification of a new technology using oil-soluble polymers and comparing it with technology based on the use of water-soluble polymers has been performed. In laboratory conditions, a newtechnology for polymer flooding at an early stage of development using oil-soluble polymers was developed and experimentally confirmed. The new technology has made it possible to increase the degree of reservesrecovery by an average of 30% compared to existing methods of enhanced oil recovery and to solve a number of problems arising from the use of water-soluble polymers. Such problems are the freezing of aqueouspolymer solutions in winter and the poor solubility of polymers in formation waters with a high salt content. The use of new technology can also reduce energy costs by 25%.

Production wells that have penetrated low-permeability reservoirs do not provide adequate oil production due to the degraded condition of the near-wellbore zones of the reservoir. Objective assessment of the condition of the near-wellbore formation zone of exploration and production wells by determining the magnitudes and values of skin effects using well tests allows timely implementation of measures to increase the productivity of wells and oil production.In this article, the following aspects of difficult-to-recover oil production were examined:- The analysis of the dependence of well productivity on the magnitude and significance of the skin effect, in order to assess the condition of the bottomhole formation zone for further planning and implementation of oil and gas inflow stimulation measures;- The influence of the magnitude and significance of the skin effect on the condition of the bottomhole formation zone on the experience of developing exploration wells penetrated into low-permeability formations in the fields of Western Siberia;- Criteria (based on the value and magnitude of the skin effect) for selecting methods of stimulating the bottomhole formation zone to increase the productivity of low-rate wells.