Successful Implementations of Integrated Asset Modeling

Hoda, Mohammad Faizul; Hoffmann, A.; Dahouk, Mohamad Majzoub; Kuntadi, Arif; Astutik, W.; Juell, A.; Whitson, Curtis Hays

doi:10.2118/187471-ms

Cited by 9 publications

(3 citation statements)

References 4 publications

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“…11. Cumulative production -the comparison of two production forecast after (1) and before (2) optimization Fig. 12.…”

Section: The Analysis Of the Possibilities Of Increasing Gas Productimentioning

confidence: 99%

“…Deploying such approach significantly mitigates any potential uncertainties and risks on each stage hydrocarbon field lifecycle, considering various development plans with their further optimization process. Since integrated asset approach consider all segments and respective pressures drops over the total system, production profiles and forecasts are more reliable and consistent, comparing to the traditional standalone approach which consist of modeling each part of the system separately from the others, excluding upstream-downstream interactions [1].…”

Section: Introductionmentioning

confidence: 99%

“…In petroleum industry there are available numerous of advanced computer applications which allow to describe, optimize and manage each segment in upstream and downstream system. To these tools we can include reservoir simulators, wells, pipelines and network simulators, surface process facility simulators and economic applications [1].…”

Section: Introductionmentioning

confidence: 99%

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Implementation of the integrated hydrocarbon reservoir management system by the example of exploiting Polish Lowland’s natural gas reservoirs

Dudek¹,

Podsobiński²,

Potera³

et al. 2019

drill

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Nowadays, because of the smaller and smaller chances of discovering new hydrocarbon deposits with abundant resources as well as significant technological advance, the proper strategy of reservoir management connected with simultaneous optimization of its production parameters is the key element in the process of development the most economically advantageous variant of reservoir management and field development. In Polish Oil and Gas Company, the project called as "Digital reservoir" based on the interactive IAM platform was initiated, thanks to which the work of all upstream segments was integrated, starting from geophysics, geology through reservoir engineering, production engineering, process engineering ending with the economic model that allows for verification of the economic efficiency of the investment. This paper presents the methodology of integration all of the above elements and the results of the IAM system implementation with further production forecasts, on the example of selected natural gas reservoirs in the Polish Lowlands being PGNiG S.A. assets.

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“…11. Cumulative production -the comparison of two production forecast after (1) and before (2) optimization Fig. 12.…”

Section: The Analysis Of the Possibilities Of Increasing Gas Productimentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

See 1 more Smart Citation

Implementation of the integrated hydrocarbon reservoir management system by the example of exploiting Polish Lowland’s natural gas reservoirs

Dudek¹,

Podsobiński²,

Potera³

et al. 2019

drill

View full text Add to dashboard Cite

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Integrated Field Management System for LNG Assets: Optimising Recovery and Managing Deliverability under Complex Constraints

Khan

Ali

Elfeel

et al. 2020

Day 1 Tue, November 17, 2020

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The sustained increase in global demand for cleaner fuels continues to drive the gas industry growth. Liquefied natural gas (LNG) has been a key enabler for this growth by making sizeable remote gas re-serves, which are unreachable by pipeline, accessible to the major and emerging gas markets. Every segment of the LNG supply chain has its own set of technical challenges. On the upstream side, many gas resources require significant pre-treatment before liquefaction, and the feed gas to the LNG facility is typically a mixture of various compositions from multiple sources; this composition mix evolves over the life of the project. The main challenge is development planning for the contributing reservoirs under the constraints imposed by the processing facility– managing reservoir deliverability, scheduling & sequencing of wells, and downtime management while maintaining the inlet stream specification. To aid with long-term planning for such assets, a virtual field management system is needed that can emulate a real-world hydrocarbon producing asset by capturing all operational constraints, resource lim-its, and complex operating logic. This paper describes a comprehensive field management framework that can create an integrated vir-tual asset by coupling reservoir, wells, network, and facilities models and provides an advisory system for efficient asset management. The field management component can replicate any operational logic, exercises holistic control over the sub-surface model, integrates with the surface network model, and provides optimization capabilities. This paper demonstrates this for a complex LNG asset that is fed by sour gas of different compositions from multiple reservoirs. We describe the different levels of constraints the asset needs to operate under, including treatment plant capacity, the LNG production capacity, the contractual LNG specifications, the disposal of gas impurities and imposes them on the model by utilizing a flexible and extensible logic framework. Con-straints applied at different levels can be mutually competing and their combination with recovery opti-mization goals increases complexity. The unified field management system uses a robust scheme to bal-ance the coupled system under these constraints while optimizing overall recovery. The optimization is enabled through the ability provided by the field management system to query and retroactively control flow entities during the simulation at the desired frequency. Customization through scripting was necessary to implement this advanced logic and was enabled by the extensible nature of the field management framework. This extensibility, along with native capabili-ties, ensures that any level of complexity can be captured, and the workflow described in this paper can be applied to any hydrocarbon producing asset for short-term and long-term development planning.

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Laying the Foundations of a Digital Gas Field Development in a Greenfield Cluster Using Integrated Modelling: A Case Study

Ramdzani

Talabi

Chua

et al. 2021

Day 3 Thu, October 14, 2021

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Field X located in offshore South East Asia, is a deepwater, turbidite natural gas greenfield currently being developed using a subsea tieback production system. It is part of a group of fields anticipated to be developed together as a cluster. Due to the nature of this development, several key challenges were foreseen: i) subsurface uncertainty ii) production network impact on system deliverability and flow assurance iii) efficient use of high frequency data in managing production. The objective of this study was to demonstrate a flexible and robust methodology to address these challenges by integrating multiple realizations of the reservoir model with surface network models and showing how this could be link to "live" production data in the future. This paper describes the development and deployment of the solutions to overcome those challenges. Furthermore, the paper describes the results and key observations for further recommendation in moving forward to field digitalization. The process started with a quality check of the base case dynamic reservoir model to improve performance and enable multiple realization runs in a reasonable timeframe. This was followed by sensitivity and uncertainty analysis to obtain 10 realizations of the subsurface model which were integrated with the steady-state surface network model. Optimization under uncertainty was then performed on the integrated model to evaluate three illustrative development scenarios. To demonstrate extensibility, two additional candidate reservoirs for future development were also tied in to the system and modelled as a single integrated asset model to meet the anticipated gas delivery targets. Next, the subsurface model was integrated with a multiphase transient network model to show how it can be used to evaluate the risk of hydrate formation along the pipeline during planned production start-up. As a final step, in-built application programming interface (API) in the integration software was used to perform automation, enabling the integrated model to be activated and run automatically while being updated with sample "live" production data. At the conclusion of the study, the reservoir simulation performance was improved, reducing runtime by a factor of four without significant change in base case results. The results of the coupled reservoir to steady-state network simulation and optimization showed that the network could constrain reservoir deliverability by up to 4% in all realizations due to back pressure, and the most optimum development scenario was to delay first gas production and operate with shorter duration at high separator pressure. With the additional reservoirs in the integrated model, the production plateau could be extended up to 15 years beyond the base case without exceeding the specified water handling limit. For hydrates risk analysis, the differences between hydrate formation and fluid temperature indicated there was a potential risk of hydrate formation, which could be reduced by increasing inhibitor concentration. Finally, the automation process was successfully tested with sample data to generate updated production forecast profiles as the "new" production data was fed into the database, enabling immediate analysis. This study demonstrated an approach to improve forecasting and scenario evaluation by using multiple realizations of the reservoir model coupled to a surface network. The study also demonstrated that this integrated model can be carried forward to improve management of the field in the future when combined with "live" data and automation logic to create a foundation for a digital field deployment.

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Successful Implementations of Integrated Asset Modeling

Cited by 9 publications

References 4 publications

Implementation of the integrated hydrocarbon reservoir management system by the example of exploiting Polish Lowland’s natural gas reservoirs

Implementation of the integrated hydrocarbon reservoir management system by the example of exploiting Polish Lowland’s natural gas reservoirs

Integrated Field Management System for LNG Assets: Optimising Recovery and Managing Deliverability under Complex Constraints

Laying the Foundations of a Digital Gas Field Development in a Greenfield Cluster Using Integrated Modelling: A Case Study

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