Results of Experimental Simulation of the Development of Gas Condensate Deposits of the Coastal Field

Introduction. Experimental development modeling is performed to predict condensate losses in the reservoir under initial reservoir conditions and during field operation. The assessment of gas condensate characteristics in laboratory conditions was carried out on samples of production from the wells of the Beregovoe field. The studies were carried out by stepwise extraction from the PVT-cell of the gas phase while maintaining the equilibrium conditions of the reservoir system. Under the initial thermobaric conditions, the pressure of the onset and maximum condensation of the studied hydrocarbon mixture was determined. At the final stage of the experiment, with the complete depletion of reservoir energy (standard conditions), the total hydrocarbon losses were calculated for the conditions of the Beregovoye oil and gas condensate field and the condensate recovery factor.
Materials and methods of research. Separation gas and saturated condensate samples were used as reservoir gas condensate system models. A series of experiments was carried out using recombined samples according to gas-condensate ratio (cm3/m3). Separation samples were taken during field studies of the wells of the Beregovoe field. The experiments were carried out by the method of contact and differential condensation (at a constant temperature) on a highpressure PVT installation. Modeling data made it possible to build diagrams in the coordinates “pressure - reservoir condensate loss” and determine the loss of hydrocarbons for the entire period of field development.
Results and Discussion. Experimental studies of the production of gas condensate wells of the Beregovoye field have shown that under various temperature and pressure conditions, the samples of the studied fluid differ in composition and its properties. The results of the study of formation gas samples (one of which was taken from the well R-77, during the joint testing of the PK191 and PK192 formations showed that the pressure of the start of condensation of the gas condensate mixture varies greatly (from 16.62 to 25.25 MPa). The reason for the possible discrepancy is due to the conditions For well R-77, the sample from well R-77 was in a two-phase state, which is possible due to the non-heightness of the container or the unreliable determination of the field condensate-gas factor (CGR). pressure.In the study of this gas condensate mixture and the construction of isotherms in the area of maximum condensation pressure, the process of both condensation and evaporation was observed. The resulting isotherms are the basis of the diagram in the coordinates “pressure — formation condensate loss”, on which the critical transition point is fixed.Also based on the simulation properties of hydrocarbon mixtures and shows the features of the transition of the gas condensate system from the gas state to the liquid state. Additionally, to calculate the CFC, the density of the condensate remaining after the studies in the PVT cell was determined. According to the measurement results, the density of the condensate taken from the well R-46 was 0.7913 g/cm3, and the density of the condensate from the well R-77 was lower and equal to 0.7792 g/cm3. The calculated coefficients of condensate recovery from the subsoil according to these samples were 0.76 and 0.72, respectively.
Conclusion. Thus, based on the results of studies of well production samples with different thermobaric conditions, composition and properties of the formation fluid of the Beregovoe field, the pressure of the onset and maximum condensation was determined. As a result, based on the obtained information about the composition of the separator samples, a recombined mixture was created, which was used for experimental modeling of the phase processes of the reservoir system. According to the results of the experiment by the method of contact condensation, it was found that the pressure of the beginning of condensation is consistent with the initial reservoir pressure. The factors influencing the change in the condensategas factor under separation conditions are determined. The obtained data are successfully used to adapt PVT-models, as well as other models used to calculate the field separation system during field development.

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