A review on gas hydrate production feasibility for permafrost and marine hydrates

Methane gas hydrate is a potential energy reserve that would supplement the current energy supply in the world. This study presents a review of methane hydrate production through various simulations and field trial tests. The simulated production data of three classes of gas hydrate reservoirs were evaluated and compared. In line with that, factors such as porosity, permeability, gas saturation, pressure, temperature, surface area were discussed and analyzed. It was revealed that in all methane hydrate reservoirs classes, production factors such as injection rate, temperature, and pressure drop, as well as reservoir parameters suit of permeability, porosity, and surface area show substantial gas production. On the contrary, CMG STARS and TOUGH + HYDRATE have better prediction results than other studied simulators. Methane hydrate reservoirs classes 1, 2, and 3, depressurization and thermal techniques have a recovery rate of 75% and 49.06%, respectively while CO2 injections and combination methods have a recovery rate of 64%, and 87.5%. Reformation of hydrate near the wellbore, sand production, the rise of bottom well pressure, and geomechanical effects are methane production challenges.

Automated summary

This study reviews methane hydrate production through simulations and field tests, comparing the production data of different reservoirs. Factors such as porosity, permeability, pressure, and temperature are discussed. The study reveals that injection rate, temperature, pressure drop, and reservoir parameters have a significant impact on gas production. CMG STARS and TOUGH + HYDRATE show better prediction results. Depressurization and thermal techniques have high recovery rates, while CO2 injections and combination methods have lower recovery rates. Challenges in methane production include hydrate reformation, sand production, well pressure rise, and geomechanical effects.