Abstract
This study investigates the production performance of gas hydrate-bearing reservoirs using a full-field reservoir model developed through geostatistical and dynamic simulations. The model integrates stratigraphic and petrophysical properties derived from well-log data and evaluates production scenarios under varying operational conditions, including the influence of aquifer drive. Depressurization is identified as the primary production mechanism, and its impact on gas hydrate dissociation and methane recovery is analyzed across multiple wells (e.g., NGHP-02-16A, 17A, 20A, 23A, and 24A). The results highlight significant variability in production performance due to reservoir heterogeneity. NGHP-02-24A achieves the highest cumulative gas recovery (243 million m³) and, NGHP-02-20A exhibits the lowest cumulative recovery (75.3 million m3), underscoring the need for tailored strategies to enhance performance. Simulations further reveal that aquifer-driven production significantly improves gas recovery, with cumulative recovery reaching 3716.7 million m3 with a significant increment in water production, compared to 661.73 million m3 without aquifer support. The investigation signifies that the location (Area B) has significant potential for commercial development with NGHP-02-16A as the best location to develop a field development plan for field trials. Location-specific investigations incorporating geomechanical impacts are essential to refine predictions and optimize reservoir management strategies.
