As a result of Reservoir Monitoring Plan, a Non-uniform Saturation has been identified in the Southern part of the reservoir. High gas saturation, coming from gas injection in underlying units, was observed within the first 10 to 30 Ft. TVD of top-most section of the reservoir. Therefore, in order to mitigate the potential problems that this gas production can generate on the well production performance which could shorten the well productive life, a flow control strategy was implemented in the lower completion designs of six new drilled wells. Following the best practices as per ADNOC Standard Operating Procedure and after performing an opportunities screening, inflow control device ‘ICD’ was found as the technology to be used on these cases. A steady state modelling was performed for identifying the most suitable ICD design for the new wells drilled during 2021-2022. In order to consider the changes on the reservoir fluid conditions over time along the wellbore, a sensitivity analysis was conducted during the steady state modelling. Likewise, the final ICD design took into account that production profile should be adhered to reservoir management guidelines. The result of wellbore simulations provided insights about the optimum solution for the well completion. This called for both adequate well positioning along the reservoir section and the utilization of ICD technologies as a means for GOR control, making feasible a more efficient practice for well and reservoir management. A successful trial of installing the first Autonomous or self-regulating ICDs have been completed and deployed as an innovation in the field to optimize and balance downhole influx profile, which will allow to minimize the impact of the gas breakthrough GBT while maintaining wells productivity. Overdesigned ICDs was avoided since they not just increase the cost of well completion, but also will impact the well performance negatively. Most of wells with segmented completion with Autonomous Inflow control Device AICD pertaining to PAD drilling project, will be commissioning in Q2 2023. One out of the six wells is currently flowing and an evaluation program and results will be further discussed in this publication.

Horizontal wells has been used across fractured reservoirs for field development, in presence of ununiformed water/gas saturation, introducing challenges for reservoir management. Premature water/gas production cause a higher bypassed oil, impacting its recovery and the business profitability. Wells performance can be enhanced through advanced and sustainable technologies, conveying in the use of integrated lower completion (i.e. ICV, ICD/AICD, DHPG, PPL). This paper discusses well/reservoir criteria, completion design and impact of incorporating these technologies in the Reservoir 1 development plan. Early water/gas breakthrough, zonal isolation, cost, well productivity, complexity of deployment, and material availability have been part of the essentials to be considered in the process workflow from planning, execution and deployment phase. Dedicated Steady-state numerical solutions inflow parameters such as permeability and water-cut profiles modeling were carried out to provide the most suitable lower completion design. The simulation was performed for separate scenarios where Flow control devices (FCD) and Intelligent Completion IC were incrementally implemented. The outcomes were compared in terms of well cumulative oil and water/gas production thru the scenarios and their value quantified. This opportunity screening and lower completion design (LCD) workflow have recently been applied at Reservoir 1 development plan. Based on the simulation cases outcomes, Six (6) new wells drilled in 2020-2022 are provided with FCD, IC, PPL expecting an incremental oil production and oil recovery with less gas and less water production consequently prolonging the well life. In Addition with the environmental benefits associated with less emissions that are achieved by reducing un-wanted fluids production. There is a planned to be drilled three (3) more wells with LCD in the next five years as part of the new field development strategies that will improve the sweeping efficiency and oil recovery tackling the production of undesired fluids in a proactive manner. Less associated emissions – The environmental benefits are achieved by reducing gas and water production, which supports company's commitments to emissions reduction target within their total production operations.

ADNOC has development and implemented a robust automated sector performance review (SPR) process using state-of-the-art analytics and business process management tool (Khan et al., 2019). In this paper, we will present the achieved results and the defined opportunities by implementing SPR across some targeted reservoirs during the previous last 2 years. With the necessity of having analysis at sector level, the main objective of this work is to conduct an integrated reservoir dynamic synthesis, identify all challenges and opportunities to come up with robust and practical action plan aiming for best reservoir management and ultimately obtain best oil recovery by sector. Applying Integrated Reservoir Management (IRM) Workflow on Giant Onshore Field, It was decided to start the project on one major Reservoir A (divided by 3 sectors) as a project pilot. First data were collected from operations database, data management in spreadsheets, simulation output format, maps and images. All data were organized into the automated SPR workflow through a web based Business Process Management (BPM) that provided mechanism for the user to load, validate and approve technical data. Setting the workflow to focusing on analyzing the reservoir performance at sector level, the data is illustrated in an integrated visualization environment including panels for the reservoir KPI, production plan compliance status and reservoir pressure maintenance, diagnostic plots, production and injection summary, etc., opening the possibility for the user to identify new opportunities and areas that needs further investigations. Few key enhancements are listed and were suggested to the solution as a next phase. Following a methodical SPR automated workflow these conclusion are drawn: Technical data can be approved with appropriate notification for task execution. Data processing cycles, visualization and performance analysis dashboard time frame was reduced. It was identify the underperforming areas into the sectors. The Opportunity Management proactive system was used to identify reservoir profitable opportunities through a centralized platform. Action plans include well and surface intervention. 20% of the activities were successfully implemented and provided significant added values. Implementation of the automated SPR workflows as part of Digital technologies is renovating the traditional work process into very effective and advanced analytics and has achieved excellence in reservoir management and reserves recovery.