Perpustakaan Digital ITB

Hydraulic fracturing is a well stimulation technique widely used to improve productivity, particularly in lowpermeability reservoirs. In gas-condensate systems, its application becomes even more crucial due to the risk of condensate banking, a phenomenon that impairs gas flow near the wellbore as pressure drops below the dew point. This study focuses on the design and evaluation of hydraulic fracturing treatment in Well A2, a vertical gascondensate well located in the Riau Islands, which penetrates several formations, including the Lower Gabus. The well is characterized by relatively low permeability (0.01–11 mD) and a high condensate yield (100–200 bbl/MMSCFD), with a narrow margin between initial reservoir pressure and dew point pressure, indicating a strong tendency for condensate banking. The study begins with formation selection based on shale break intervals and flow potential (????. ?), followed by fracture geometry design using available petrophysical and geomechanical data. Simulation results show that the proposed design improves reservoir connectivity and near-wellbore flow capacity. Post-fracturing performance is evaluated using nodal analysis, with production forecasted to increase from 3.65 MMSCFD to approximately 7.75 MMSCFD. Pressure drawdown is found to be significant; however, it is not sufficient to fully eliminate condensate banking. The resulting fracture conductivity of 4892 ????????. ???????? is expected to alleviate near-wellbore flow restrictions. This study demonstrates that hydraulic fracturing can significantly enhance performance and partially mitigate the effects of condensate banking in near-critical pressure environments.