The Lower Jurassic Bridport Sand Formation records net deposition in the Wessex Basin, southern UK of a low-energy, siliciclastic shoreface that was dominated by storm-event beds reworked by bioturbation. Shoreface sandstones dip at 2-38 to define (subaerial?) clinoforms that pass distally into a near-horizontal platform, and then steepen again to form steep (2-38) subaqueous clinoforms in the underlying Down Cliff Clay Member. The overall morphology indicates mud-dominated clinoforms of compound geometry. Compound clinoforms are grouped into progradational sets whose stacking reflects tectonic subsidence and sediment dispersal patterns, and also controls basin-scale reservoir distribution and diachroneity of the formation.Each shoreface clinoform set consists of an upward-shallowing succession that is several tens of metres thick with a laterally continuous mudstone interval at its base. The successions are punctuated by calcite-cemented concretionary layers of varying lateral continuity, which formed along bioclastic lags at the base of storm-event beds. Concretionary layers thus represent short periods of rapid sediment accumulation, while their distribution likely results from variations in stormwave climate, relative sea-level, and/or sediment availability. The distribution of impermeable mudstone intervals that bound each clinoform set and concretionary layers along clinoform surfaces controls oil drainage in the Bridport Sand Formation reservoir.An understanding of time-stratigraphic relationships is important within hydrocarbon-bearing basins, because it facilitates prediction of the distribution of lithological units, including source rocks, reservoirs, and seals (e.g. Van Wagoner et al. 1990). Such understanding is most commonly developed via the application of sequence stratigraphic methods at either relatively large spatial scales (tens to hundreds of kilometres laterally) to define the constituent elements of hydrocarbon plays during exploration, or at smaller scales (hundreds of metres to tens of kilometres laterally) to define flow units within producing hydrocarbon reservoirs. These spatial scales typically translate into temporal scales of 10 5 -10 8 yr for hydrocarbon exploration applications and 10 2 -10 6 yr for hydrocarbon production applications, although there may be considerable uncertainty in these estimated time spans in the absence of appropriate biostratigraphic age control.In this paper, we present a case study of the hydrocarbon exploration and production applications of time-stratigraphic relationships to a shallow-marine siliciclastic sandstone, the Jurassic Bridport Sand Formation of the Wessex Basin, UK. At exploration scale, we focus on using time-stratigraphic relationships to constrain the spatial distribution of reservoir lithologies, particularly via the application of a revised depositional model that relates sedimentological facies to seismically resolved geomorphology (after Morris et al. 2006) (at time spans labeled for 'subaqueous clinoform set' in Fig. 1). These time-...