Investigation into the Improvement of Condensate Recovery in Gas Condensate fields by Gas Injection

Abstract

When the flowing bottom-hole pressure falls below the dew point pressure, gas condensate reservoirs experience losses in well productivity due to near wellbore condensate dropout. Existing oil and gas industry approaches include pressure maintenance and gas cycling.

Dry gas is injected into a retrograde gas condensate reservoir to help the condensate vaporise and raise its dew point. In this work, the phase diagram has first been produced based on the composition of the reservoir. The impact of injections of carbon dioxide, pure methane, ethane and methane, nitrogen, and pure methane on reservoir recovery has been examined and contrasted with the natural depletion scheme. The effect of each type of injection on condensate and gas production is examined while simulating the whole system simultaneously, including two separators and a stock tank. In every injection that has been looked at, full mixing has been assumed.

According to this study, carbon dioxide had the highest liquid recoveries at the lowest injection rate, followed by a mixture of 20% ethane and 80% methane. According to this study, carbon dioxide had the highest liquid recoveries at the lowest injection rate, followed by a mixture of 20% ethane and 80% methane.