Investigation of synergy between extended oil recovery and hydrogen storage in a producing field using the Norne reservoir model

0 ENERGY & FUELS

Gas Science and Engineering Pub Date : 2025-07-14 DOI:10.1016/j.jgsce.2025.205729

Behzad Amiri , Pål Østebø Andersen , Mojtaba Ghaedi , Xiaodong Luo

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引用次数: 0

Abstract

This research investigates the feasibility and effectiveness of combining Underground Hydrogen Storage (UHS) with enhanced oil recovery (EOR) and carbon dioxide (CO₂) sequestration in an active oil reservoir, utilizing the Norne field as a case study.

CO₂-water-alternating-gas (CO₂-WAG), continuous gas (CO₂) and water flooding (CGWF), and water flooding (WF) are utilized for oil extraction. UHS is executed in six scenarios: three during oil extraction and three post-depletions. The UHS efficiency, oil recovery, and H₂ recovery efficiency in the two UHS systems are first examined by employing an EOR well converted into a UHS well. Subsequent examination of UHS during oil production utilizing CO₂-WAG investigates the impacts of elevated UHS well rates, well positioning, prior well applications, and the use of smart wells to limit H₂ breakthrough.

The low rate UHS cases with H₂ constraint did not adversely impact oil recovery. CO₂-WAG had the highest efficacy in EOR and could store around 60 % of the injected CO₂, and resulted in the maximum efficiency for UHS during oil production, as CO₂ reduced H₂ dissolution in oil and residual trapping. Conversely, the WF method yielded the highest H₂ recovery for storing H₂ in the depleted reservoir, owing to a lower pressure near the H₂ well and higher pressure in distant areas compared to the two other cases. Additionally, 22 % of H₂ was produced by the oil wells. Smart oil wells, constraining H₂ production, improved UHS well H₂ recovery from 73.6 % to 80.2 %. The efficiency of oil recovery and UHS is contingent upon the interplay of well location and H₂ injection and production rate. Implementing UHS during oil production with CO₂-WAG could boost oil recovery, UHS, and CO₂ sequestration. The optimization of H₂ injection and production rates, H₂ well placement, and cushion gas volume is essential, alongside proper monitoring of the oil production stream.

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利用Norne储层模型研究生产油田提高采收率与储氢之间的协同作用

本研究以Norne油田为例，探讨了地下储氢（UHS）与提高采收率（EOR）和二氧化碳（CO2）封存相结合的可行性和有效性。采用CO2-水-气交替（CO2- wag）、连续气（CO2）水驱（CGWF）和水驱（WF）进行采油。UHS在六种情况下执行：三种在采油期间，三种在耗尽后。首先，通过将一口EOR井转换为UHS井，对两种UHS系统的UHS效率、原油采收率和H2采收率进行了测试。在采油过程中，利用CO2-WAG对UHS进行了后续检查，研究了UHS井速升高、井位、之前的井应用以及使用智能井限制H2突破的影响。具有H2约束的低速率UHS病例没有对石油采收率产生不利影响。CO2- wag在提高采收率方面的效率最高，可以储存约60%的注入二氧化碳，并在采油过程中实现UHS的最高效率，因为CO2减少了油中H2的溶解和残留的捕集。相反，与其他两种情况相比，WF方法在耗尽储层中储存H2的H2回收率最高，因为H2井附近的压力较低，而远处的压力较高。此外，22%的氢气是由油井生产的。智能油井控制了氢气产量，将UHS井的氢气采收率从73.6%提高到80.2%。采油效率和UHS取决于井位、注氢和产量的相互作用。在采油过程中，利用CO2- wag技术实施UHS，可以提高采收率、UHS和二氧化碳封存能力。优化H2注入和生产速率、H2井位和缓冲气量是至关重要的，同时还要对产油流进行适当的监测。

本文章由计算机程序翻译，如有差异，请以英文原文为准。

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来源期刊

Gas Science and Engineering

CiteScore

11.20

自引率

0.00%

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