The North Sea Super Basin is a trilete rift system located in the maritime waters of the United Kingdom, Norway, Denmark, Germany, and the Netherlands. Created after a phase of regional thermal doming in the Middle Jurassic, the rift basin consists of the Viking Graben, Central Graben, and Moray Firth Basin and their surrounding platform areas. Synrift extensional activity occurred during the Upper Jurassic followed by postrift thermal subsidence from the Cretaceous to the present day. The basin’s main Upper Jurassic (Humber or Viking Group) source rocks were deposited contemporaneously with rifting. Their subsequent subsidence history led to progressive maturation, initially focused in the grabens, but becoming ever more extensive with time. Maximum burial of the Upper Jurassic occurs at the present day leading to the efficient charge of a diverse array of overlapping plays. The only exception occurs in western parts of the Moray Firth rift arm, where Cenozoic uplift arrested the maturation of Upper Jurassic source intervals. However, Middle Jurassic (paralic), Lower Jurassic (marine), and Middle Devonian (continental) lacustrine source rocks reached maturity there too and created an additional local petroleum system. The North Sea’s reservoirs span the entire geological column and all of the post-, syn- and prerift megasequences. Despite being stratigraphically older, the Devonian–Middle Jurassic (prerift) reservoirs receive charge because the Upper Jurassic source rocks lie structurally deeper in the graben.  Since oil first flowed from the North Sea in 1975, 15 fields have been found to contain more than 1 billion BOE in recoverable reserves and more than 95 billion BOE have been extracted to date, making it one of the most significant petroleum basins in the world. Production from the area allowed the United Kingdom and Norway to exceed their energy needs and become net exporters for two decades. However, rates have declined significantly, and the rift system is now considered to be a mature petroleum province. Despite the smaller volumes and reduced size of accumulations, companies continue to seek, identify, and drill prospects that will extend the life of the basin. The continued exploration activity and field development has led to an estimate that approximately 10–20 billion bbl of oil equivalent remains to be developed. With many fields now depleted, efforts are increasingly focused upon decommissioning and the repurposing and reemergence of the basin for an alternative (renewable) low-carbon future that faces the energy transition and challenge to meet stringent net zero emission targets. These include the evaluation of safe subsurface storage sites for carbon dioxide, hydrogen, methane, and compressed air, and the development of new energy integration projects such as coupled blue hydrogen, green hydrogen, platform electrification using wind turbines, geothermal energy, gas-to-wire, and geothermal initiatives. The latter will all become increasingly important as the basin addresses the energy transition and challenge to meet net zero emission targets.