This paper describes an efficient approach to implement IAOM project and evaluate subsurface well performance and surface network facilities of a supergiant oil field flowing from multilayered carbonate reservoirs. The field is produced via several gathering stations and pumping stations. The current manifold pressures at the RDS stations are high, which will increase by the introduction of gas lift and by the additional production from new wells. In IAOM implementation process, individual well strings and robust network model was built for the asset on the IAOM platform. This model was further utilized in meeting various production optimization challenges such as well surveillance, production and Injection optimization, forecasting and allocation and field development planning. This paper demonstrates how IAOM project was used to run different production optimization scenarios, describing the objective, methodology, analysis and results to address various challenges in production optimization. Following case studies were carried out for this purpose: Well potential rate analysis and optimization: To determine well potential rate based on the well performance, reservoir guidelines and back pressure in the network system.New producer well tie-in to existing network: To investigate optimal option for a new producer well flowline tie-in to existing well flowlines carrying fluid to remote degassing station and study well flowline performance after tie-in.Wellhead shut-in pressure analysis and optimization: To estimate wellhead shut-in pressure at which well ceases to flow when reservoir pressure is increased to new pressure.New pattern injectors tie-in to existing clusters: To estimate tie-in options for new water injector wells for new developments project to the existing clusters based on availability of water supply and closest distance.
In a super-giant field onshore Abu Dhabi; the production strategy is to maintain the sustainable capacity but due to increase in water production the need of artificial lift is mandatory to maintain the production plateau. However, accurate well integrity management in such field is critical due to fluid characterization, souring environment and field extension (35 X 20 Km).The selection of the artificial lift technique plays an important role in improving the ultimate recovery. However managing the integrity of the artificial lift wells is more challenging under the presence of H2S, CO2 and high P & T. The loss of production caused by integrity related issues and the need to determine specifications and accurate future integrity management plan lead to need for a gas lift pilot. For the future it is envisaged that integrity assurance plans needs to be an integral part of the field-development planning, ensuring that asset value is maximized.More challenges will exist when dealing with Gas Lift as it is a long term artificial lift technique affecting well design for long life completion. Therefore, Gas lift was piloted to better understand real integrity challenges and measure corrosion trends with time to gain operational and technical experience and to compare them with initial theories.The pilot was monitored closely with intensive program. An optimization process was followed, assisted by modelling. Although the initial thought that the corrosion might affect the top part of the completions because of the injected gas specification, but the time-laps corrosion logs gave a completely different and unexpected picture. The pilot results enabled the overall project to be concluded; the lessons learnt from the pilot were captured and used as building block for the full-field development options.The paper describes the pilot results, the integrity challenges and the contoured problems, the philosophy of monitoring the corrosion evolution, the findings and how it was different from the initial expectation. Finally the clear impact on the integrity management process to ensure proper long-life well design and completion strategy.
This paper presents the process and results from the applicationof an Integrated Subsurface/Surface Model (Digital Twin) for computing capacity at the country level, or Integrated Capacity Model – ICM, to generate additional revenue through increased gas production from the existing asset facilities.The model is the foundation of the ICM system, a platform that allows ADNOC to evaluate different production scenarios at a field, asset, or country level for operational and planning purposes. The presented case and results are focused specifically on a gas maximization scenario, a very relevant scenario considering the global market tendencies and interest in cleaner provision of energy. The scenario maximizes the gas production of the country while adhering to oil targets and reservoir management guidelines. Integrated Capacity Model (ICM) is one of ADNOC'sindustry leading technical solution for managing its vast (both in number and size) oil and gas reserves being exploited by thousands of wells and providing stabilized oil and gas to the various export points and processing plants. It is the world's first such large-scale model-based solution. The solution provides several predefined daily runs in an automated manner which can be visualized via an interactive web-based dashboard across the organization. ICM also allows for the configuration of ad-hoc or alternate scenarios to allow for the analysis and evaluation of special operating cases and business plan development. These alternate scenarios address the requirements to evaluate the opportunities and capability of the infrastructure to deliver in exceptional circumstances and for special needs. This paper presents the configuration details and results of one such scenario. The paper shares the implementation and challenges of maximizing natural gas products across the ADNOCintegrated value chain. This scenario is achieved by setting up a multi-objective optimization function across every asset in theICM model to maximize its gas production while maintaining crude oil targets as required by market and ensuring that well and reservoir management guidelines are honored. The results of the scenario demonstrate the capability to increase gas production by up to 30% across through the adjustment of the country wide production profile.It is demonstrated that producing a substantial incremental gas volume is possible while honoring any oil targets, particularly in assets with large gas-oil-ratio (GOR) variation. The additional gas availability is achieved through a number of well choke changes, therefore the size of the opportunities in terms of wells and strings can be ranked in such order to balance the practicality with field operations.
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