Changes in the Physical Properties of Hydrocarbon Reservoir as a Result of an Increase in the Effective Pressure During the Development of the Field

Abstract

The change in reservoir pressure and its effect on the physical properties of the reservoirunder the development of the hydrocarbon fields has always been of great interest to many researchers in the oil industry. One of the tasks of core research is to obtain interpretation models that provide quantitative processing of well logging data. The effects of the change of effective pressure on the reservoir properties of productive reservoir rocks in the simulation conditions of the reservoir are studied. Reservoir conditions were simulated, and under these conditions, the main physical properties of each sample were determined. The field development process was simulated by a decrease in reservoir pressure, accompanied by an increase in effective pressure by 10.0 MPa. This has shown that we can expect a decrease in the average formation porosity (φ) value by 0.05 absolute percent or 0.24%, and a decrease in the permeability (K) by 0.24 md, or 0.14 %. The data on changes in some petrophysical parameters are analyzed from the point of view of their dependence on changes in the effective pressure of the reservoir, obtained in the first approximation of the assessment of these changes

Assessment of the Condition of the Near-Wellbore Zone of Repaired Wells by the Skin Factor

“…It should be noted that in almost all published works related to the study of the U-formation, there is a high heterogeneity and a complex geological structure. The heterogeneity of reservoirs often manifests itself in the form of high variability in total and effective thickness, local thinning of deposits and clay zones [31][32][33]. Therefore, in many fields within individual layers zones with completely different values of flow rates and productivity are found, which in our case for layer Yu vary from 0.48 to 12 m 3 / day, from 0.003 to 0.237 m 3 / day/kgf/cm 2 .…”

Calculation Method for Determining the Gas Flow Rate Needed for Liquid Removal from the Bottom of the Wellbore

“…It follows from the above equations that the gas velocity at which all the liquid is brought to the surface does not depend on the flow rate of the liquid entering the wellbore, which is not consistent with the physical process. In practice, critical velocities vary considerably depending on the production well, and are dependent on the design of the well bottom and pipe suspension, the density of the formation fluid (product), the presence of mechanical and chemical impurities, among other factors (Al-Obaidi S. et al 2018;Al-Obaidi S. et al 2010;Al-Obaidi S. et al 2012).…”

Determination of the Upper Limit Up To Which the Linear Flow Law (Darcy's Law) Can Be Applied

“…Traditionally, to determine the upper limit of applicability of Darcy's law, a comparison of the flow Reynolds number (Re) with its critical value (Rec) has been proposed. This issue has been addressed in many literatures, beginning in the first half of the last century [6]- [10]. However, due to the diversity of the proposed expressions for calculating the flow numbers Re and the large dispersion of their critical values, the application of this method in practice proves to be impossible.…”