The Scotian Margin, one of the least explored sectors covering the area from the Laurentian Channel to the Georges Bank in the North Atlantic, is considered to be one of the major gas provinces (gas, condensate, and gas hydrates). The comprehensive fluid flow visualization of three major units of the Petroleum System approach (play characteristics, hydrocarbon expulsion component, and hydrocarbon preservation structure) has provided a basic framework for such predictions. The entire petroleum system within the Scotian Margin is, however, dependent on the hydrocarbon saturation, nature of reservoir hydrocarbons and the stability of each individual plays.

The hybrid fluid flow in various play types of both the inner and outer Scotian Slope has been controlled by heat flow related to basement fractures, thickness of sedimentary packages, salt tectonics, source rock anoxicity, and timing of the transmissibility or sealing behavior of the major growth faults. Accordingly, the expected hydrocarbon families in the Scotian Slope would be different compared to the shelf and shelf-break petroleum. However, the concept of a petroleum system using geochemical data (from earlier DSDP/ODP and other wells), hydrocarbon pockmarks (seepages), and comprehensive fluid flow modeling suggest that late Triassic to Early Cretaceous organic-rich oil- and gas-prone source rocks could be the key contributors for future gas and condensate discoveries (both for natural gas and gas hydrates) in the slope.

Canada’s involvement in the “Kyoto Protocol” for the Greenhouse Gas Emission control and possible development of Fuel Cell Technology beyond 2010 may increase demand for methane to steer cleaner fossil fuel energy in North America. The abundant prospects of natural gas and gas hydrates within the Scotian Margin and possibly within the northern part of the East Coast will mitigate the future energy demands beyond 2010.