As a result of flooding and accumulations of liquid at the bottomholes, the operating conditions of gas wells become complicated, so that they end up self-squeezing and losing of gas production. A method is proposed for determining the technological parameters of operation of the gas wells with the purpose of removing liquid from the bottom of the wells. Data from the gas dynamics and special studies were used to develop this method, which has been tested on one of the oil and gas condensate fields. It offers the possibility to increase the accuracy of the information provided by the fund and to ensure that the production wells are operated as efficiently as possible with the use of this method. In the case of liquid accumulation in the well that is insignificant, or when water is present in the well, the technique is beneficial in that it allows determining the technological parameters of well operation and ensuring the removal of the liquid from the bottom of the well.

Modeling in the process of oil production has been used almost since the beginning of hydrocarbon field development, when there were ideas about the conditions of formation occurrence and oil flow to wells. An empirical model is proposed to calculate the current production rate of wells in the hydrocarbon field by year. Based on this model, an equation for calculating cumulative production was constructed. The proposed model is compared with known models and actual development history data. The resulting models of current production rates, cumulative production and recoverable reserves most accurately describe the actual results and have a high correlation parameter compared to other models.

The paper presents the results of laboratory and field experiments on a developed polymer gel-forming composition “PSB” that enhances oil recovery. In this composition, two aqueous solutions are used: a polymeric gelling agent and an inorganic crosslinker. An alternating injection of solutions that are mixed directly in the reservoir allows a bulk gel to be formed that blocks water or gas breakthroughs. This leads to an increase in oil production, and a decrease in water cut, resulting in more efficient wells. On five wells in a hydrocarbon field that was located within the Permian-Carboniferous deposits, a series of field tests were conducted. It has been observed that wells treated with this developed polymer gel-forming composition “PSB” show a decrease in water cut, a decrease in liquid flow rates, and an increase in oil production. This technology led to an increase in oil flow rates of 5 tonnes per day per well (2 times) and a decrease in water cut of 10-40%, confirming its effectiveness. According to the values of the cumulative effect as of February 2016, this effect continues to increase oil production by 20-600 tons per well.

In this study, water injection and gas injection technologies are examined for their effectiveness in developing oil rims in gas fields. Considering the need for advanced development of the oil rims within a short period of time, reservoir simulation methods using horizontal wells have been used to rationally develop oil rims. It was confirmed that large volumes of gas must be injected to maximize oil recovery. This happens when gas breakthroughs from the gas cap into the bottom of the production well and from the injection well into the gas section. A cycle process was discovered when gas injection led to the development of an oil rim. The condensate from the gas was taken out, and the dryer gas was then injected back into the reservoir. Condensate concentrations in the gas, specially those near the oil rim, are a major factor contributing to the interest in the proposed concept.

A variety of methods are examined in this study in order to improve oil recovery from low-permeability heterogeneous reservoirs in oil-saturated shale deposits. Calculations based on the fluid flow model revealed that water and gas injection was effective, and that horizontal and directional wells, including those employing hydraulic fracturing are evaluated in this study. Moreover, hydraulic fracturing in directional wells with vertical completions was found to be one of the most effective methods for water injection in this study. However, when hydraulic fracture length is hard to achieve, the gas injection has been found to be a more efficient way to enhance oil recovery than water injection. Furthermore, horizontal drilling technology was most effective in the central part of the reservoir.

A hydrophobic composition containing water repellents and highly volatile solvents is shown in this study to isolate water from the bottom hole formation zone of gas wells and reduce as much as possible the saturation of pore spaces with water. During injection, this composition shows selectivity and mostly penetrates water-saturated porous media. The study shows that the injection of such composition into porous media has a high water-insulating effect, reducing the water permeability of water-saturated porous media by 35 times with a degree of water isolation of 97%.Moreover, while injecting, it has selective action, mainly penetrating water-saturated media rather than gas saturated media. As a result of injecting 0.91 to 0.99 pore volumes (pv) of the composition, the Qwater/Qgas ratio reaches 5.22 to 5.26, indicating high selectivity.

In order to improve the development of reserves, optimal technologies must be introduced to meet the regular increase in demand for hydrocarbons. Injection of low-salinity water is one of these technologies that have been shown to be effective in solving this problem. Accordingly, low-salt water is investigated as a potential method to increase terrigenous oil recovery. Based on modelling the flooding of solutions with different salinities, the effect of salt concentration on oil displacement efficiency during re-injection was assessed. Salinity reduction efficiency was examined by comparing oil recovery after flooding with high salinity water. Due to active interactions at the oil-water interface, including an increase in viscoelasticity, the oil recovery factor increased with a decrease in salinity. Oil recovery increased by 1.3 – 2% as water salinity decreased.

The efficiency of gas injection for developing terrigenous deposits within a multilayer producing object is investigated in this article. According to the results of measurements of the 3D hydrodynamic compositional model, an assessment of the oil recovery factor was made. In the studied conditions, re-injection of the associated gas was found to be the most technologically efficient working agent. The factors contributing to the inefficacy of traditional methods of stimulating oil production such as multistage hydraulic fracturing when used to develop low-permeability reservoirs have been analyzed. The factors contributing to the inefficiency of traditional oil-production stimulation methods, such as multistage hydraulic fracturing, have been analysed when they are applied to low-permeability reservoirs. The use of a gas of various compositions is found to be more effective as a working agent for reservoirs with permeability less than 0.005 µm2. Ultimately, the selection of an agent for injection into the reservoir should be driven by the criteria that allow assessing the applicability of the method under specific geological and physical conditions. In multilayer production objects, gas injection efficiency is influenced by a number of factors, in addition to displacement, including the ratio of gas volumes, the degree to which pressure is maintained in each reservoir, as well as how the well is operated. With the increase in production rate from 60 to 90 m3 / day during the re-injection of produced hydrocarbon gas, this study found that the oil recovery factor increased from 0.190 to 0.229. The further increase in flow rate to 150 m3 / day, however, led to a faster gas breakthrough, a decrease in the amount of oil produced, and a decrease in the oil recovery factor to 0.19 Based on the results of the research, methods for stimulating the formation of low-permeability reservoirs were ranked based on their efficacy.