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炭酸水圧入を用いたオフショアCCUS

Offshore CCUS With Carbonated Water Injection (原題)

P. Bergmo, T. Holt

Petroleum Technology2026-06-07#CCUSOrigin: EU経営インパクト: コスト削減対象セクター: power
DOI: 10.1115/omae2026-180872
原典: https://doi.org/10.1115/omae2026-180872

🤖 gxceed AI 要約

日本語

北海のNorne油田を模した貯留層モデルを用い、炭酸水圧入（CWI）を既存の水攻法に追加するオフショアCCUSの経済性を評価した。CWIは油の膨張と界面張力低下により回収率を高め、CO2税費用を削減する可能性がある。CO2回収・圧縮・混合、坑井材の更新、分離プラントなどのコストを考慮し、20年・40年のプロジェクト期間で異なる油種・坑井配置ごとに収益性を分析した。

English

This study assesses the economic feasibility of offshore CCUS via carbonated water injection (CWI) added to standard waterflooding, using a Norne Field-inspired reservoir model with three oil types. CWI can boost oil recovery through oil swelling and reduced interfacial tension while cutting CO2 tax costs. Costs include CO2 capture, compression, mixing, well upgrades, and separation, evaluated over 20- and 40-year horizons.

Unofficial AI-generated summary based on the public title and abstract. Not an official translation.

📝 gxceed 編集解説 — Why this matters

日本のGX文脈において

日本ではCCS/CCUSの商業化と炭素税・GXリーグの議論が進む中、石油増進回収とCO2貯留を組み合わせた経済性評価は、国内のCCUS事業モデル検討やコスト低減の参考になる。ただし対象は北海油田であり、日本への直接適用には地質・制度面の調整が必要。

In the global GX context

Globally, CCUS is central to net-zero pathways and transition finance, and this paper offers a quantitative cost-benefit lens on combining enhanced oil recovery with CO2 storage under carbon pricing. It contributes empirical evidence on offshore CCUS economics relevant to TCFD/ISSB transition-plan disclosures and carbon-tax-driven project viability.

👥 読者別の含意

🔬研究者:炭酸水圧入の貯留層シミュレーションと経済性評価の手法を、CCUS研究のベンチマークとして活用できる。

🏢実務担当者:オフショアCCUSを既存水攻法に追加する際のコスト項目と回収率・CO2税削減効果の見積もりに役立つ。

🏛政策担当者:炭素税やCCUSインセンティブ設計が石油増進回収とCO2貯留の経済性に与える影響を検討する材料になる。

📄 Abstract（原文）

The economic feasibility of applying carbon capture, utilization, and storage (CCUS) offshore is examined by looking at carbonated water injection as an added activity to a standard water injection operation. This added activity requires new equipment and methods, which means additional costs. However, it can also increase oil production and reduce CO2 tax expenses. Injecting carbonated water has the potential to improve oil recovery by swelling the oil and lowering the interfacial tension between oil and water, allowing it to flow more easily. The efficiency of this process will, in addition to depending on reservoir properties and well placements, depend on concentration of CO2, salinity, oil properties, temperature, pressure and injection rate. To study the potential effects of carbonated water injection at field scale, reservoir simulations were run using a model inspired by the Norne Field model, initialized with three different types of oil to reflect the range of oil qualities in the North Sea. The economic performance of carbonated water injection was analysed based on the increase in oil recovery and the net amount of CO2 stored for different oils and combinations of wells. Project costs included CO2 capture, compression and mixing, upgrading of the well materials to handle carbonated water, as well as a plant to separate CO2 from the produced gas. Economic assessments were performed for project durations of 20 and 40 years.

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