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ADMA-OPCO is currently pursuing the development of several undeveloped structures offshore Abu Dhabi. in addition to the two giant fields that have been on production for many years. At ADIPEC in 2010, ADMA outlined plans for real time well surveillance offshore. This paper describes the implementation of the first phase of these plans for three existing facilities, one of the new fields, and HQ. This paper presents some of the details of that implementation and the opportunities this creates for improved well management.The paper covers:• Hardware architecture and design • Software philosophy and integration with existing capability at ADMA OPCO • Areas of business value incremental to prior practices • Workflows and visualization of key well and facility dataThe challenges ADMA-OPCO faces offshore Abu Dhabi dealing with a high number of complex wells, are to ensure adequate drainage and optimum flux rates, to enhance overall recoveries, from reservoir intervals in both existing, and more complex new fields. Real time well and facility data, transformed with the addition of both modelling capability and workflows, can translate into automation of some key processes and the addition of value by guiding scarce engineer time into the areas requiring the most attention. With ADMA OPCO's activity growth, the well to engineer ratio is increasing. To enhance organizational efficiency, ADMA will be able to automate some previously manual tasks by implementation of automated workflows.A phased approach to the introduction of real time data in an evolutionary, rather than revolutionary approach, preserving and augmenting the functionality of existing tools enables the implementation to follow the pace of introduction of additional control and surveillance capability into the Brownfield environment.

The super-giant field under study is one of largest oil producers in Middle East and been producing for more than 50 years from a multilayered carbonate reservoir. Long-term sustainability of production of the field is a key mission for the field operator and national oil company, considering both productivity and recovery of the field. Gas lift has been considered as an effective and economically feasible method to increase production of the wells and as a solution to revive the closed wells and to maintain the production of flowing wells. Prior to full field implementation, a gas lift pilot has been initiated in the field. The objective of the pilot is to collect further essential information and evaluate the challenges prior to the full field implementation. At the well scale, managing the well lift rate allocation, monitoring the performance of gas lift valves and running diagnostics, and optimizing the production rate are the main challenges for the gas lift pilot. At the full field network level, the backpressures of the lifted wells are affecting the production of the other wells producing naturally. A commercial three-phase flow simulator was used to build the well models as well as the pilot network, with certain boundary conditions to develop a scalable solution to enable the operations and headquarters teams to provide a timely solution to the mentioned challenges. To integrate all inputs from various disciplines, the information from the monitoring activities and from reservoir saturation and production logging tools in addition to well test data and gas lift surveys was used to develop the solution. The gas lift management solution was evaluated in the pilot area to diagnose the gas lift valves, validate well tests, optimize gas lift allocation, enhance well production, and perform field-wide production optimization The solution also reveals gas lift candidate wells with the potential to increase the production and directs redistribution of the lift gas in the pilot area to minimize gas utilization. Additionally, to introduce scalable solution which can be utilized at very large wells count, automation of the workflow process has been considered to provide efficiency for engineers which will get advise from the solution.

Production engineers frequently use back allocation to estimate actual production volumes from wells based on frequent well test data or theoretical calculations using well and reservoir characteristics. PETRONAS executed a centralized production data management system from early days of production to establish a scalable and reliable workprocess among the organization. The production and operation data management system of the field supports data collection, QC, validation and production back allocation as well as production downtime optimization. The new system provides a means to visualize complex networks, verify the production streams, track gathering systems functionality through time and derive the allocation networks. The various downtime coding and quantifications, helped Petronas to quantify the root cause of production shortfalls and optimized the unwanted shut downs. The new system has improved the data quality and reliability and has made the data transparently available to the various stakeholders in the organization. After the new back allocation system became fully operational, Petronas started to realize the following benefits from this successful implementation. Determine the production quantities of each well and reservoir for production accounting.Quality check and approval for the test data before being used for further calculationsAbility to allocate production, where accurate measurements are not possible or cost effective.Ability to determine fluid flow quantities through every strategic point in the network The current paper describes the challenges and benefits of the subjected system implementation.

This paper describes an efficient approach to evaluate the water supply-to-injection cluster facilities capacity and also to define the required upgrades and areas of optimization.The supergiant filed understudy is located in Abu Dhabi and is producing for decades from multilayered carbonate reservoirs. The field is under peripheral water injection to maintain reservoir pressure and also to enhance the oil recovery.Total of 53 water injection clusters have been commissioned in the field to support water injection operation for reservoir management purpose. The water clusters consists of producing wells from water bearing formations and multiple injection wells completed in different reservoirs. Frequent down time in the water supply wells and existing bottle necks in the water supply to injection system has led Abu Dhabi Company for Onshore Operation to evaluate the clusters looping option to enhance the water injection capacity of the field and optimal re-distribution of the water through the clusters.By this strategy, the high capacity water supply wells will be able to feed the candidate clusters required extra water or the clusters with the closed water supply well under maintenance.To achieve this strategy, a fully integrated water supply to water injection system was built using a commercial fluid flow simulator. The integrated model consists of water supply well equipped with ESP, water injection facilities network with surface pumps, strainers and choke manifolds as well as injection wells. The system was validated against most reliable measured data at a snap shot of time.The full integrated water supply to injection model was used to evaluate the opportunities to loop the high capacity clusters to high demanding clusters, identify the bottlenecks in the system and also to determine the various options in the clusters facilities to enhance the water injection capacity of the field.