Natural gas hydrate is ice‐like mixture of gas (mostly methane) and water that is widely found in sediments along the world's continental margins and within and beneath permafrost and glaciers in a near‐surface depth interval where the pressure is sufficiently high and temperature sufficiently low for gas hydrate to be stable. We categorize the myriad of geological gas hydrate deposits into five characteristic types. We then review the multiple quantitative models that have proposed to describe the genesis of these deposits and describe how each may have formed. We emphasize the importance of coupling multiphase flow (free gas and liquid water) and multicomponent reactive transport with geological history to describe the dynamical processes of gas hydrate formation and evolution in geological systems. A better insight into the kinetics of methane formation from microbial biogenesis and the processes of multiphase flow at the pore scale will advance our knowledge of how these systems form. By understanding the generation and evolution of gas hydrate through time, we will better decipher the role of gas hydrate in the carbon cycle, its potential to contribute to climate change and geohazards, and how to design optimal strategies for gas production from hydrate reservoirs.

We form methane hydrate by injecting methane gas into a brine‐saturated, coarse‐grained sample under hydrate‐stable thermodynamic conditions. Hydrate forms to a saturation of 11%, which is much lower than that predicted assuming three‐phase (gas‐hydrate‐brine) thermodynamic equilibrium (67%). During hydrate formation, there are temporary flow blockages. We interpret that a hydrate skin forms a physical barrier at the gas‐brine interface. The skin fails periodically when the pressure differential exceeds the skin strength. Once the skin is present, further hydrate formation is limited by the rate that methane can diffuse through the solid skin. This process produces distinct thermodynamic states on either side of the skin that allows gas to flow through the sample. This study illuminates how gas can be transported through the hydrate stability zone and thus provides a mechanism for the formation of concentrated hydrate deposits in sand reservoirs. It also illustrates that models that assume local equilibrium at the core‐scale and larger may not capture the fundamental behaviors of these gas flow and hydrate formation processes.

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We show with a two‐dimensional multiphase flow and multicomponent transport model that free gas flow is a viable mechanism to form concentrated methane hydrate in meter‐scale, dipping sandstones far above the base of the hydrate stability zone (BHSZ). In this model, gas preferentially flows updip along the top of sandstone due to buoyancy. This drives hydrate formation, increasing the local salinity to the stability limit and developing three‐phase (gas, liquid, and hydrate) equilibrium above the BHSZ. With time, the gas and the hydrate solidification front (HSF) advance together updip. Behind the HSF, hydrate continues to form as the elevated salinity diffuses away. High hydrate saturations reduce the sediment permeability significantly. As a result, as the gas and HSF move updip, they are also pushed perpendicularly from the top to the base of the sandstone. The hydrate system ultimately self‐seals itself due to reduced permeability across the entire thickness of the sandstone. Gas starts to retreat downdip and accumulates below the BHSZ. With this model high hydrate saturations form far above the BHSZ at high methane supply rates while hydrate is concentrated at the BHSZ or no hydrate forms at low methane supply rates. This study provides further insights into hydrate formation by free gas flow, which can be used to design the best strategies for economic and environmental production of methane from hydrate reservoirs.

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