Feasibility of Gas Injection Efficiency for Low-Permeability Sandstone Reservoir in Western Siberia: Experiments and Numerical Simulation

Alexey Sorokin, Alexander Bolotov, Mikhail Varfolomeev, Ilgiz Minkhanov, Azat Gimazov, Evgeny Sergeyev and Angelica Balionis
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Alexey Sorokin: Department of Petroleum Engineering, Kazan Federal University, Kremlevskaya Street 18, 420008 Kazan, Russia
Alexander Bolotov: Department of Petroleum Engineering, Kazan Federal University, Kremlevskaya Street 18, 420008 Kazan, Russia
Mikhail Varfolomeev: Department of Petroleum Engineering, Kazan Federal University, Kremlevskaya Street 18, 420008 Kazan, Russia
Ilgiz Minkhanov: Department of Petroleum Engineering, Kazan Federal University, Kremlevskaya Street 18, 420008 Kazan, Russia
Azat Gimazov: Gazpromneft STC LLC, 75–79 Liter D Moika River Emb., 190000 St. Petersburg, Russia
Evgeny Sergeyev: Gazpromneft STC LLC, 75–79 Liter D Moika River Emb., 190000 St. Petersburg, Russia
Angelica Balionis: Gazpromneft STC LLC, 75–79 Liter D Moika River Emb., 190000 St. Petersburg, Russia

Energies, 2021, vol. 14, issue 22, 1-12

Abstract: Gas injection is one of the prospective methods in the development of unconventional oil reserves. Before implementation in the field, it is necessary to justify the effectiveness of using gas agents in specific object conditions. Experiments of oil displacement on physical models with subsequent numerical modeling can provide the information necessary to justify the feasibility of using gas injection in specific reservoir conditions. This work is devoted to a series of experiments determining the minimum miscibility pressure (MMP) on a slim tube model and the analysis of oil displacement dynamics for various gas compositions, as well as numerical modeling. Displacement experiments were carried out using a recombined oil sample from one of the fields in Western Siberia. The MMP was determined by the classical method of inflection point on the displacement efficiency versus injection pressure curve, which was 34.6 MPa for associated petroleum gas (APG) and 49.9 MPa for methane. The dysnamics of oil displacement for different gas compositions at the same injection pressure showed that APG and carbon dioxide (CO 2 ) are the most effective in the conditions of the studied field. The influence of the gas composition on the gas breakthrough point was also shown. It is revealed that the change in the concentration of the displacing agent in the outgoing separation gas helps define in more detail the process of displacement and the processes implemented in this case for various displacing gas agents. Similarly, it is shown that the displacing efficiency of a gas agent in a miscibility injection mode is affected by the configuration of wells when it is necessary to achieve MMP in reservoir conditions. For the immiscible gas injection mode, no influence of the well configuration was observed.

Keywords: MMP; slim tube; gas injection; physical and numerical modeling; APG; methane (search for similar items in EconPapers)
JEL-codes: Q Q0 Q4 Q40 Q41 Q42 Q43 Q47 Q48 Q49 (search for similar items in EconPapers)
Date: 2021
References: View references in EconPapers View complete reference list from CitEc
Citations: View citations in EconPapers (2)

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