The paper demonstrates that the hydrophilic behavior of productive formations is primarily determined by water retaining capacity. Especially it concerns reservoirs the water retaining capacity is greatly affected by variability of gel cement clay there may present correlational relationship between hydrophilic behavior and water retaining capacity of a productive reservoir.
ExtEndEd AbstrAct:The displacement factor is important information when it is necessary to evaluate oil production dynamics and the prospects of development intensification and oil recovery enhancing methods, including nanotechnological methods. However, up to date there are no reliable oil-field methods to predict this parameter in situ well, under conditions of the natural reservoirs occurrence, and that causes this important parameter not to be taken into account when the impact on the bottomhole formation zone effectiveness is evaluated.In this paper the authors propose a methodology for prediction of the displacement factor that employs field geophysics data and that makes it possible to estimate this parameter in each geological cross-section both in the section and in the deposit area.The method is based on the use of two complex parameters characterizing the filtration properties and the productive formation hydrophilicity (hydrophobicity) degree. The both complex parameters are easily determined by the standard well logging complex data. MAchinE-rEAdAblE inforMAtion on cc-licEnsEs (htMl-codE) in MEtAdAtA of thE pApErReferences: At present the technologies that use solutions containing SiO 2 nanoparticles are becoming more and more popular in oil production intensification and enhanced oil recovery process.The proposed calculation method for residual oil saturation and displacement coefficient can be used to obtain the reference values of the corresponding parameters when the efficiency of oil production intensification and enhanced oil recovery methods including nanotechnological ones is evaluated.
A b s t r a c tThe sensitivity analysis of field-geologic parameters influence on the productivity factor of deposits was conducted in conditions of various groups of objects in carbonate reservoirs. The character and degree of parameter influence were revealed. Patterns allowing to predict the efficiency of bed productivity from indirect data coming from geologic-physical and physical-chemical properties of layers and fluids saturating them, and also the bedding terms of productive layers were created. We presented the algorithm of the received data application for effective development of low productive objects of oil recovery.
The reservoir wettability nature should be taken into account while well logging conducting, reservoir engineering, methods of oil recovery enhancement and intensification selecting with the aim of residual oil reserves involvement into the development. In this respect, the development of a methodology for reservoirs’ wettability quantitative assessment on the basis of well logging data is very urgent and relevant. In this article, basing on the analysis of laboratory data on the wettability index and reservoir characteristics, a methodology for quantifying the wettability index from field geophysical data assesment has been developed, and the results of the method application in carbonate reservoirs of the Ural-Volga region are presented. For the first time, the analytical expressions between wettability and reservoir characteristics are obtained. It is shown that the formation wettability at its microlevel is determined by the average thickness of the residual water film on the filtration channels surface, and at the macrolevel – by the residual water saturation volume of the effective part of the productive strata void space. A methodology for wettability index by the residual reservoir water saturation volume quantitative assessment was worked out, and the necessary analytical expressions were obtained. The proposed methodology is as follows: –on the reservoir core samples collection in the laboratory environment, the following parameters are determined: wettability index, porosity, residual water saturation;–using the laboratory core studies data, the dependence diagram of the wettability index on the residual water saturation volume (volumetric moisture content) is plotted;–basing on the reservoir resistivity, determined by the prior to development geophysical studies, the residual water saturation volume of the formation is estimated and, using the graph, the wettability index is determined. The worked out wettability index quantitative assessment methodology has been successfully proven in the Ural-Volga region carbonate reservoirs. The method allows the wettability degree according to the geophysical data in every layer intersection assessment both in the cross-section and in the deposit area. The information about the reservoir nature and wettability degree will make it possible to proceed more rationally to the development analyzing, controlling, regulating and enhanced oil recovery methods engineering and, as a consequence, to reduce the risks of their practical implementation.
Based on studies on the interaction and heat resistance of some heat-resistant polymer additives at 128 °C, a sulfonated polyacrylamide polymer AN-125 is proposed as an additive for improving the viscosity of a surfactant composition. The results of experimental studies of a new surfactant composite prepared based on a mixture of ethoxylated and propoxylated sulfate, α-olefin sulfonate and alkylphenol ethoxylate with a concentration of 500 ppm and additives to improve the viscosity in the reservoir model from the deposit basement samples showed that the surface tension at the oil-solution boundary before the exposure to temperature is 0.19 mN/m, and after exposure to temperature 91 °C – 0.21 mN/m. The experimental studies of water and surfactant compositions injection on 5 prefabricated models composed of core samples of basement rocks covering a wide range of reservoir properties showed that the injection of the oil rim with compositions based on the mixture of ethoxylated and propoxylated sulfate, α-olefin sulfonate and alkylphenol ethoxylate with a concentration of 800 ppm and an additive of polymerasulfonated polyacylate increases the oil displacement ratio.
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