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.
In the practice of hydrodynamic calculations the linear flow law, commonly called Darcy's law, is now widely used. It is well known that it is violated at large pressure gradients. This means that there is a certain limit value of the pressure gradient Δp* above which a deviation from the linear character of the flow law begins. This value of the pressure gradient is the upper limit of applicability.A method is presented for the direct determination of the upper limit of the validity of the linear flow law (Darcy's law) for any porous media. The method is based on the principles of percolation modelling of fluid flows in porous media. The influence of the structure of the pore space on the value of the boundary gradient is analysed. A qualitative comparison with the experimental data is performed.
Carbonate rocks of the Triassic deposits of the South Mangyshlak basin are investigated in this paper for their boundary values, which are important for interpretation of field geophysical data as well as perforation and blasting.Based on their lithological composition, Triassic deposits are classified as either terrigenous or carbonate reservoirs. Carbonate reservoirs are found in the Middle Triassic strata containing volcanogenic dolomite and volcanogenic limestone rocks. A complex type of reservoir characterizes these rocks: porous-fractured, porouscavernous, and fractured. Upper Triassic sediments are formed by the intercalation of tuffaceous, siltstone-sandy, and mudstone rocks overlying Middle Triassic sedimentary rocks. Oil deposits are confined to polymictic sandstones, which are oil-saturated to varying degrees.In order to substantiate the quantitative criteria of the reservoir, experimental studies of the core samples were carried out in the laboratory. Fluid flow studies were performed where physical and hydrodynamic characteristics were determined when oil was displaced by displacing reagents. On the basis of the parameters obtained, correlations between reservoirs and non-reservoirs were constructed. Based on relationships between reservoir properties such as porosity and permeability versus residual water content, as well as effective porosity and permeability versus dynamic porosity, the boundary values were determined. Using these results, the porosity limit for the Middle and Upper Triassic strata has been determined to be 7%, the permeability limit for the Middle Triassic has been determined to be 0.02 X 10-3 μm2, and the permeability limit for the Upper Triassic has been determined to be 0.3 X 10-3 μm2.
scite is a Brooklyn-based organization that helps researchers better discover and understand research articles through Smart Citations–citations that display the context of the citation and describe whether the article provides supporting or contrasting evidence. scite is used by students and researchers from around the world and is funded in part by the National Science Foundation and the National Institute on Drug Abuse of the National Institutes of Health.
hi@scite.ai
10624 S. Eastern Ave., Ste. A-614
Henderson, NV 89052, USA
Copyright © 2024 scite LLC. All rights reserved.
Made with 💙 for researchers
Part of the Research Solutions Family.