The expected profiles of the water produced from the mature ADNOC fields in the coming years imply an important increase and the OPEX of the produced and injected water will increase considerably. This requires in-situ water separation and reinjection. The objective of in-situ fluid separation is to reduce the cost of handling produced water and to extend the well natural flow performance resulting in increased and accelerated production. The current practice of handling produced water is inexpensive in the short term, but it can affect the operating cost and the recovery in the long term as the expected water cut for the next 10-15 years is forecasted to incease significantly. A new water management tool called downhole separation technology was developed. It separates oil and & gas from associated water inside the wellbore to be reinjected back into the disposal wells. The Downhole Oil Water Separation (DHOWS) Technology is one of the key development strategies that can reduce considerable amounts of produced water, improve hydrocarbon recovery, and minimize field development cost by eliminating surface water treatment and handling costs. The main benefits of DHOWS include acceleration of oil offtake, reduction of production cost, lessening produced water volumes, and improved utilization of surface facilities. In effect, DHOWS technologies require specific design criteria to meet the objectives of the well. Therefore, multi--discipline input data are needed to install an effective DHOWS with a robust design that economically outperforms and boosts oil and/or gas productions. This paper describes the fundamental criteria and workflow for selecting the most suitable DHOWS design for new and sidetracked wells to deliver ADNOC production mandates in a cost-effective manner while meeting completion requirements and adhering to reservoir management guidelines.

The ever-increasing need for resilient strategies demands the supreme understanding of business uncertainties and the execution risks. For the National Oil Companies like, ADNOC, the annual reservoir performance review (ARPR) is a process of paramount importance, as it provides a holistic overview of the reservoir performance status for each ADNOC field on yearly basis. It unfolds the subsurface performance issues, uncertainties and risks, and steers the decisions of Business Plan sanctions. The ARPR execution demands a tremendous amount of time and effort to assimilate information and create a consolidated decision support package. In the absence of an automated process, the creation of insightful analytics, proper tracking of actions and maturation of value-driven opportunities become unmanageable. Thus, the automation of the process asserted to demonstrate a significant reduction of the data preparation time, increased multidisciplinary collaboration, centralized data archiving and integrated dashboard generation. A multidisciplinary team of ADNOC's subject matter experts joined forces to develop a fit-for-purpose automated solution (i-ARPR) that underpins a sophisticated subsurface knowledge bank that leverages advanced analytics and digital technologies to integrate key reservoir performance parameters automatically and provides insights to support crucial business decisions. It allows users to collaborate via an automated guided web-based workflow to build the analyzed content for the ARPR report for a given Field, using data previously loaded and approved. The content is built bottoms-up from a defined list of Elements (Plots, Tables, Images and Text) along with analysis and insights contributed by Subject Matter Experts (SME's), into sections of the report that are collated and further expanded with insights and conclusions by designated Sections Editors. The solution enables assigning tasks to users at various supervisory and coordinating levels through an automated governance system. It provides means to monitor the progress of the work, approve the content of Elements and Sections, and review the concatenated ARPR document for final approval. All the integrated analyses get stored into the corporate repositories for any future utilization in data mining and advance analytics workflows. The automated solution (i-ARPR) has enabled efficient data gathering, and its visualization has fostered multidisciplinary collaboration and has provided 66% more time to the engineers to analyze the information for identifying risks and opportunities. Over $50 Million OPEX saving is estimated during the first three years of the project implementation in 17 upstream assets within the ADNOC Group.

Reservoir management guidelines are an enabler of, production sustainability, assurance to reservoir health and high ultimate recovery. Monitoring the compliance of the field production against the set of reservoir management guidelines is one of the key processes for ADNOC, being a governing body of major U.A.E. hydrocarbon producing fields. With the business need to ramp up production, field maturation, and the associated operational challenges, it is critical for ADNOC to effectively monitor and regulate its field production plans to assure the long-term production sustainability. In this regard, ADNOC has developed a robust framework that is implemented through an automated analytics platform that enables different ADNOC technical teams to effectively monitor and report the compliance status of each hydrocarbon barrel from produced from ADNOC assets. The paper highlights the features of the workflow implemented, the management of change strategy and the business value created. The automated process allows the consolidation of a variety of well, reservoir and field-level data. The analytical platform enables integrated analysis, KPI calculation and interactive visualization. The framework assesses the compliance based on three governing parameters: well technical rate, gas-oil ratio (GOR), and bottom hole flowing pressure. The compliance analysis is carried out on a monthly basis where the monthly back allocated production data for each well is compared with the set of operating guidelines in an automated data analytics and visualization environment. A pragmatic compliance tolerance is considered in the calculations to accommodate the measurement inaccuracies, as well as the operational limitations while allowing flexibility to exclude nonconformity with valid reasons. The overall process is governed through an automated business process management (BPM) platform, which seamlessly regulates the predefined subroutines among different stakeholders to report and track different corrective actions in a timely manner. The framework implementation has strengthened the overall compliance governance process; and has been instrumental to properly manage asset production capacity in a systematic manner. This has subsequently enabled the preparation of a prompt action plan and has improved the operating efficiency of more than 3% within the first six months of implementation, through restoring, compensating and increasing the effective capacity of overall ADNOC Production. The approach has demonstrated great value both in terms of process alignment, as well as from the production assurance standpoint at a country level, and allows the organization to have an established system, which provides: Consistent compliance monitoring standardsMinimal subjectivityComplete process governanceQuick turnaround timeAuditable history The aim of this paper is to publish a stepwise guide for any operators who might be interested to adopt and implement a similar approach to assure the long-term production sustainability and health of their assets.

The expected profiles of the water produced from the mature ADNOC fields in the coming years imply a 5-fold increase and the OPEX of the produced / injected water will increase considerably. This requires in-situ water separation and reinjection. The objective is to reduce the cost of handling produced water and to extend the well natural flow performance resulting in increased and accelerated production. The current practice of handling produced water is inexpensive in the short term, but it can affect the operating cost and the recovery in the long term as the expected water cut for the next 10-15 years is high. A new water management tool called downhole separation technology was developed. It separates Oil & Gas from produced water inside the wellbore and injects the produced water into the disposal wells. The Downhole Oil Water Separation Technology is one of the key development strategies that will reduce the handling Produced water, improve the recovery, and minimize field development cost by eliminating surface water treatment and disposal well. The main benefits for DHOWS are to accelerate Oil Offtake, reduce Production Cost, Lower Water Production and Improve facility Utilization. DHOWS require specific criteria to meet the objectives of the well. Multi-disciplined inputs are needed to properly install effective DHOWS, but robust design often brings strong performance. This paper describes the fundamental criteria and workflow for selecting the most suitable DHOWS design for new and sidetracked wells to deliver ADNOC production mandates cost effectively while meeting completion requirements and adhering to reservoir management guidelines.