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MENA国営石油会社の脱炭素化における技術・戦略アーキテクチャ：BOE当たり10kg-CO2e未満の上流操業とギガトン規模のCCUS・水素バックボーンの結合

The Technical and Strategic Architecture of MENA NOC Decarbonization, Coupling Sub-10 kg CO2e Per BOE Upstream Operations with a Gigatonne-Scale CCUS–Hydrogen Backbone (原題)

Mrinal Bhardwaj, Anurag _, Amaresh Mishra, Rahul Choudhary, Aditya Saraswat

ADIPEC📚 査読済 / 学会2026-11-02#CCUS経営インパクト: 調達リスク対象セクター: power
DOI: 10.2118/236374-ms
原典: https://doi.org/10.2118/236374-ms
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🤖 gxceed AI 要約

日本語

MENA国営石油会社4社の上流資産を対象に、BOE当たり10kg-CO2e未満の炭素強度を実現する貯留層管理・メタン抑制・電化などの技術的要因を分解した。GCCの169Gt貯留容量と約1,300Mtpaの排出源を基にCCUSハブの均等化コストを推計し、高濃度源で30〜60ドル/t、難脱炭素産業で90〜140ドル/tと大西洋圏より低コストであることを示す。残る障壁は技術ではなく、輸送・貯留の事業モデルや孔隙空間の権利、長期責任移転といった商業・規制面にあると結論づける。

English

Decomposing upstream Scope 1+2 intensity across eight operational drivers, the study shows MENA NOCs achieve sub-10 kg CO2e/boe through deliberate reservoir management, methane control and field electrification, not geology alone. A bottom-up CCUS cost model calibrated to 169 Gt of GCC storage finds abatement at USD 30–60/t for high-concentration sources and USD 90–140/t for hard-to-abate industry, below Atlantic-basin benchmarks. The key remaining barrier is commercial-regulatory: bankable transport-and-storage models, pore-space title and long-term liability transfer.

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

日本の石油・ガス企業や商社が中東上流権益とCCUS事業に関与する中、炭素強度競争力とCCUSコストの定量比較は、SSBJ開示におけるScope1+2戦略や移行計画の説得材料になりうる。資源外交・水素供給網の観点でも示唆が大きい。

In the global GX context

Offers a rare asset-level, cost-curve view of upstream carbon intensity and CCUS economics in the lowest-cost producing region, directly relevant to ISSB/TCFD transition-plan disclosure and to global debate on whether hydrocarbon producers can credibly pair production with abatement infrastructure.

👥 読者別の含意

🔬研究者:Provides a replicable asset-level decomposition and bottom-up CCUS cost framework linking operational drivers to carbon intensity benchmarks.

🏢実務担当者:Useful for benchmarking own upstream Scope 1+2 intensity and for framing CCUS/hydrogen investment cases and partner due diligence in the Gulf.

🏛政策担当者:Highlights that pore-space title, transport-and-storage business models and liability transfer are the binding constraints for CCUS scale-up, not technology.

📄 Abstract（原文）

Abstract MENA National Oil Companies (NOCs) operate under a dual mandate: maximize near-term hydrocarbon revenues to fund economic diversification while delivering verifiable decarbonization. The literature has largely treated this mandate as a strategic narrative; this paper treats it as an engineering problem. Anchored on the asset bases of Saudi Aramco, ADNOC, QatarEnergy, and Kuwait Petroleum Corporation (KPC), the study quantifies (i) the reservoir- and production-engineering drivers behind sub-10 kg CO2e/boe upstream carbon intensity, and (ii) the regional techno-economic envelope for a gigatonne-scale CCUS–hydrogen backbone built on an estimated 169 Gt of GCC geological storage capacity (≈41 Gt in depleted reservoirs and ≈119 Gt in saline aquifers) and approximately 1,300 Mtpa of aggregate point-source emissions. The analytical framework combines three layers: an asset-level decomposition of upstream Scope 1+2 carbon intensity across eight operational drivers; a bottom-up CCUS levelized-cost model spanning capture, transport, and storage, calibrated against the Bachu volumetric framework; and scenario stress-testing across Brent price, implicit carbon price, and IEA demand pathways. The results, supported by proprietary analytics benchmarking six global producers on breakeven price and carbon intensity, show that MENA NOCs occupy a globally singular position in the cost-carbon competitive quadrant, sub-USD 20/bbl upstream breakevens paired with sub-10 kg CO2e/boe carbon intensity, produced by deliberate engineering choices in reservoir management, methane control, and field electrification, not inherited from favorable geology alone. Integrated GCC CCUS hubs can deliver all-in abatement at USD 30–60/t for high-concentration sources and USD 90–140/t for hard-to-abate industry, materially below Atlantic-basin benchmarks. With a cumulative global oil supply deficit approaching 9.7 MMbbl/d by 2040 and regional CCUS capacity scaling from roughly 4 MTPA today toward more than 30 MTPA by 2030, a trajectory now subject to near-term geopolitical repricing as the region is positioned as the lowest-cost marginal supplier of both molecules and abatement. The primary remaining barrier is commercial-regulatory rather than technical: bankable transport-and-storage business models, pore-space title, and long-term liability transfer.

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