Abstract The high-pressure–high-temperature Jasmine Field lies 270 km east of Aberdeen in the UK Central North Sea and forms part of Chrysaor’s J-Area. Hydrocarbons were discovered at Jasmine in 2006, in Middle–Late Triassic fluvial sandstones of the Joanne Sandstone Member of the Skagerrak Formation. Appraisal proved a greater than 2000 ft hydrocarbon column and, in 2010, the Jasmine Field development was sanctioned. Five development wells were pre-drilled between 2010 and 2013, and the field was brought on line in November 2013, after which one further appraisal and three additional production wells were drilled. Jasmine infrastructure comprises an accommodation platform and a wellhead platform tied back to a riser platform adjacent to the Judy processing and export facility. Rapid early pressure depletion, a highly layered fluvial reservoir, structural complexity and variable fluid types present significant challenges for both static and dynamic modelling. Following production start-up, acquisition of new post-production reservoir pressure and flow data, and incorporation of allocated well production data, have been used to address these modelling challenges, and to provide encouragement for future infill and near-field exploration drilling opportunities.