AB field has undergone secondary recovery of water injection for pressure support and sweep efficiency improvement. From proactive surveillance program, it was further discovered that AB field performance is improving without water injection. Pilot shut-in water injection study initially commenced post 5 years of production. From the pilot water injection shut-in, surveillance data was used for thorough analysis to conclude that secondary recovery through water injection will reduce field recovery due to early water out coupled with moderate to strong aquifer strength. Close pressure monitoring, surveillance database, and other diagnostic plots used to gauge the water injection healthiness in AB field. Reservoir modelling was built to validate the implication of water injection secondary recovery to the field. Complete surveillance data and gathering method will be presented in this paper to permit readers to replicate the analysis prior to conclude secondary recovery type of mechanism, typically water injection, is beneficial to the field or proven otherwise. Pilot shut-in water injection has proven the following: (1) It was observed that AB field pressure still maintains above the pressure target of initial Field Development Study, (2) Watercut performance has significantly increased post pilot water injection shut-in, (3) no substantial impact on the reserves loss, while in contrast, water injection stoping will improve recovery due to delaying the wells watered out time. For this marginal field of AB, an incremental of 0.8-1.7 MMstb reserves recovery will contribute to higher recovery factor. This is also due to the moderate to strong aquifer strength against weak to moderate aquifer strength anticipated earlier in FDP. Casehole contact logging was conducted at two wells in the field to monitor the contact movement. From all the observation and analysis conducted, AB field was further optimize by the Reservoir Management Plan (RMP) revision. Lesson learned from the case study will enhance others' understanding and view prior to deciding on secondary recovery method to any field. RMP study should be updated as the production continues and once more data is acquired from the right surveillance program.

SS Field with its longer production data now available has enabled further validation of the previous assessment (i.e. SPE-17005 by N. Noridah et all, 2013) of the reservoir needs and technology respond in this field to-date. This paper also highlights the effectiveness of the field-wide downhole flow control solution in terms of more oil and managing undesired field water-cut. It is scrutinized based on the actual field Ultimate Recovery (UR) versus the predicted recovery to further optimise recovery in infills plan. Extensive evaluation on production performance was conducted well-by-well to engage the overall field performance. The actual production performances are clustered in the categories from the ‘underperformers’ to the excellent producers, considering the reservoir attributes such as reservoir characterization, geological understanding and contacts movement. Meanwhile, technology responds in terms of zonal control efficiency across the sandface is analyzed for improved comingled oil production multi-zones. The assessment is further applied in the infill well-creaming for the extended development plan in SS field. The study correlates the best reservoir attributes to the technology respond in order to maximize future infill recovery in ensuring fit-for-purpose implementation. Years of production experience have demonstrated a consistently better recovery of SS field against the expected FDP. 75% of the producer meet the FDP production target which contributes towards overall field > 25% EUR despite only near the half of the production life (~20 years). SS Field is the first pilot PETRONAS field applying field-wide downhole flow control (12 wells) and intelligent Completions (2 wells). An integrated evaluation of the production performance in this field with subsurface understanding is paramount for technology replication. It is a case study that serves as a benchmark for development decision in other fields with similar reservoir characteristics. It also serves as best-practices and lesson-learnt to provide a better insight of a downhole flow control solution efficiency in the late-production strategy of suppressing water for further production enhancement via EOR / infills.