Modeling Gas Dissolution in BlackOil Models (Russian)
- V. R. Zubov (Rock Flow Dynamics, Gubkin RSU of Oil and Gas) | I. M. Indrupskiy (Ogri Ras) | K. Yu. Bogachev (Rock Flow Dynamics)
- Document ID
- Society of Petroleum Engineers
- SPE Russian Petroleum Technology Conference, 26-28 October, Moscow, Russia
- Publication Date
- Document Type
- Conference Paper
- 2015. Society of Petroleum Engineers
- 5.5 Reservoir Simulation, 5 Reservoir Desciption & Dynamics, 5.5.8 History Matching, 5.4.1 Waterflooding, 5.2.1 Phase Behavior and PVT Measurements, 5.4 Enhanced Recovery, 5.2 Fluid Characterization
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The pdf file of this paper is in Russian.
Light oil fields development often demonstrates some evidence of oil-gas phase transition hysteresis. Phase transition rate depends on the process considered: changing state from dissolved in oil to free gas or reverse gas dissolution (re-solution) in oil . The difference in phase transition dynamics leads to such phenomena as continuous free gas production in reservoirs with pressure above initial bubble point. Reservoir simulators are used for forecasting reservoir dynamics and decision support. For most of the common practical problems, BlackOil model is the choice. The main object of the present study was to analyze reservoir simulators option for controlling gas re-solution and to modify the mathematical model of the option in order to account for the process dynamics known from experimental data.
The existing and new versions of the gas re-solution reservoir simulator option were considered on the example of a waterflood pattern. The process studied was gas liberation during primary oil production followed by waterflooding with increasing reservoir pressure. Fluid properties were taken by data from Sherkalinskaya formation Tala zone of Krasnoleninskoye field, for which the effects of slow gas re-solution were observed. Results of the simulations with different gas re-solution options were compared by basic field development indicators. Also the contact experiment in a pVT bomb was simulated in order to demonstrate physical effects observed for different versions of the mathematical model of gas re-solution.
The suggested extension of the option accounts for two major aspects of gas re-solution known from experimental data. The first one is the dependence of gas re-solution rate on the value of over pressure above the initial bubble point. The second one is the fact that re-solution is a relaxation process which has exponential time dynamics. The developed mathematical model included these two aspects and was implemented in a reservoir simulator. The results of the test runs show considerable influence of a gas re-solution option used on the dynamics of reservoir pressure, gas-oil ratio and oil production.
The presented approach to gas re-solution control in reservoir simulators is based on data of experimental studies of non-equilibrium phase transitions of hydrocarbons. A flexible tool has been developed for history matching of flow models for the reservoirs with pressure increase after primary oil depressurization below bubble point. Matched model can be used to produce physically consistent forecasts of efficiency of various technologies for gas re-solution and further field development.
|File Size||1 MB||Number of Pages||14|
Lobanova, O.A., Zubov, V.R., Indrupskii, I.M. Neravnovesnoe fazovoe povedenie uglevodorodnykh smesei. Chast' 1: eksperimenty [Non-equilibrium phase behavior of hydrocarbon mixtures. Part 1: Experiments]. // Avtomatizatsiia, telemekhanizatsiia i sviaz' v neftianoi promyshlennosti, 2014, no. 11, pp. 18&-23.
Lobanova, O.A., Zubov, V.R., Indrupskii, I.M. Neravnovesnoe fazovoe povedenie uglevodorodnykh smesei. Chast' 2: modelirovanie fil'tratsii [Non-equilibrium phase behavior of hydrocarbon mixtures. Part 2: flow simulation]. // Avtomatizatsiia, telemekhanizatsiia i sviaz' v neftianoi promyshlennosti, 2014, no. 12, pp. 17&-21.
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