Integrated Geological-Dynamic Analysis and Development Optimization of Interlayer Connectivity in an Offshore Calcareous-Barrier-Controlled Stacked Reservoir

Heterogeneous barriers influence pressure support and water entry in offshore stacked reservoirs, but their development implications are difficult to evaluate where well control in the upper zone is sparse. This study integrates drilled barrier interpretation, operation-screened production dynamics, geological monitoring priorities, and reservoir simulation for Zone B and the underlying Zone C of the LFA field. The mixed clastic–carbonate barrier becomes thinner and more calcareous-sandstone-rich northward and thicker and more limestone-dominated southward. Drilled barrier intervals are 0.63–2.50 m thick, with interpreted permeabilities of 0.05–1.50 mD where available. Production records through 28 February 2026 show a positive association between A10H and the screened Zone C common factor (r = 0.554, n = 549), while the residual association of every candidate well becomes indistinguishable from zero once the shared Zone C signal is removed. A conductance-and-spacing prior, evaluated across 1,107 scenarios, consistently places A8H, A1H, A6H, and A2H in the upper monitoring group, followed by A5H. These observations support thin-barrier, transition, and thick-barrier development domains within combined edge–bottom-water and edge-water-drive interpretations. Field-history-matched 1-, 5-, and 9-well schemes forecast Zone B recovery factors of 10.2%, 30.8%, and approximately 37% by 2045, with approximately 1.51 × 106 m3 of cumulative Zone B oil production in the full scheme. Subsequent early production from A18H, A19H, and A20M spports the implemented thick-barrier and transition-domain deployment. The workflow connects barrier heterogeneity and the scale of dynamic evidence to traceable monitoring and phased development decisions without equating production association with direct hydraulic validation.