optimization of oil production adopting Improved /Enhanced Oil Recovery methods via 3D numerical simulation approach

The optimization recovery from mature resources requires the integration of various modelling resources and geological knowledge. This thesis addresses the challenge of maximising recovery from a mature, compartmentalised offshore reservoir, focusing on the Norne Field (Norwegian Sea). The study’s objective is to quantify the incremental value of Improved/Enhanced Oil Recovery (IOR/EOR) options, with emphasis on optimised waterflooding using a reproducible 3D numerical-simulation workflow. The workflow integrates (i) black-oil dynamic simulation in ECLIPSE with history-consistent controls and field constraints (e.g., injector/producer limits, BHP caps, water-cut and GOR cut-offs), and (ii) scenario design and ranking based on pressure support and incremental recovery. Three forward-forecast scenarios (Nov-2006 to Jan-2020) are tested: a do-nothing base case; targeted new producers selected by remaining-oil and interference criteria; and producer additions combined with strategically placed injectors to improve areal sweep. Results show cumulative oil recovery rising from ~73.3×10⁶ Sm³ (base) to ~74.7×10⁶ Sm³ with added producers, and up to ~77.2×10⁶ Sm³ when new injectors are included—while sustaining higher average reservoir pressure and acceptable water-handling, subject to a field injection capacity of ~42,000 Sm³/d. The analysis indicates that infill production coupled with injector placement delivers the largest, most robust uplift for Norne-type reservoirs, providing practical guidance for life-extension planning in mature North Sea assets.This work indicates that the combination of static and dynamic modelling is crucial to build an efficient IOR plan and improve hydrocarbon recovery efficiency, which will offer guidelines for the productive life of mature fields.