The article deals with theoretical and practical issues of improving the efficiency of operation of high-water cut oil wells by developing and applying double-acting pumping systems based on electric submersible pumps. This combination is providing down-hole gravitational separation of oil and produced water, lifting low-water-cut oil to the surface with simultaneous injection of most of the separated water into the absorbing formation without lifting to the surface. Moreover, it is providing low-cost regulation of the ratio of the volumes of the lifted product and the injected water, as well as monitoring the quality of the injected water with the required frequency.
The dynamics and performance of major oil deposits in late (final) stage of development of large oil fields are given the current rates of oil recovery. The high oil recoveries are resulted as a consequence of the favorable geological and physical characteristics of the development objects, application of development systems and optimal density well spacing, adequate geological structure, maintain during the process of the development the optimal rates of technological development, the modes of operation of wells and a project of the fund of production wells, continuous improvement of the project systems taking into account the dynamics of the reserves development and the clarification of the geological structure.
In oil industry, one of the most worldwide used methods a among the hydrodynamic enhanced oil recovery methods is the water flooding, including the cyclic water flooding. The efficiency of cyclic water flooding is affected by a number of geophysical and field technological factors. In this work and based on three-dimensional hydrodynamic simulation, it is shown that anisotropy of formation permeability has significant effect on justification of the half-cycle time and the technological effectiveness of the method.
In the oil industry, the inflow of water into the gas and oil wells represents always an important issue that needs to deal with. In this study a water-repellent composition, which is based on volatile hydrocarbon solvent,was proposed for handling of water isolating work in gas wells. As a volatile hydrocarbon solvent, it was quite promising to use gas condensate and its primary processing products (like stable gas condensate SC and light distillate of gas condensate DGCL). Initially, we studied the effect of compositions based on the ABR water repellent, M100 fuel oil and solvents SC, DGCL and mixed in equal volumes of DGCL + SC on gas permeability ofgas-saturated porous medium. The article presents the results of studies, conducted on physical models of the formation, confirming the efficiency and selectivity of the water-repellent composition impact on the water-cutinterval.
Most of the liquid oil of all types estimated today represents the category of heavy-oils. This leads to decrease in oil production and more extraction of water. Enhanced oil recovery is a method using sophisticated techniques that can deal with such sort of oils and alter the original properties of oil. Thermal Enhanced Oil Recovery (EOR) remains the most frequently used method for extraction of heavy oils. In this work, irreversible changesin rocks that lead to an increase in formation permeability have been studied and, as a result, to an increase in the production flow rate of production wells and for injection wells, an increase in their injectivity. New methods and technologies have been developed for the intensification of thermocyclic well treatments.A computer program based on mathematical model was developed, which allows predicting changes occurring in the well and near the well space. In this model, the main characteristics of the process of cyclic thermal impact on the bottom-hole zone can be used to predict field temperatures in the well and in the formation, as well as changes in the permeability of rocks. To improve the efficiency use of the model and increase the heating zone, a new method of thermal cycling impact on the bottom-hole zone of the well was developed.
There is a significant effect of the hydro confining pressure of the core holder on the flowing properties of the formation rocks. This effect is caused due to the mechanical elastic deformation of the core when carrying outlaboratory studies of the waterproof and polymer compositions. Consequently, this deformation will cause changing in the permeability and voids storage capacity of the studied core samples. Therefore, under the laboratory conditions and when dealing with such studies on formation cores, it is necessary to consider the changes of permeability and voids storage capacity of these cores.
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 analysed. 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.
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