Modeling and monitoring injectivity evolution during cold CO <sub>2</sub> injection with field evidence from aquistore carbon capture and storage operations
低温CO2圧入時の注入性進化のモデリングとモニタリング：Aquistore CCS実証事業からの現場証拠 (AI 翻訳)
Alireza Rangriz Shokri, Stephen Talman, Erik Nickel, Rick Chalaturnyk
🤖 gxceed AI 要約
日本語
カナダのAquistore CCS実証サイトで5年間の低温CO2圧入データを解析し、注入性が時間とともに改善することを実証。非等温THMプロセスが注入性向上の主因であり、応力依存の浸透率変化が関与することを示した。長期的なCO2封留とコンフォーメンス評価に重要な知見を提供する。
English
Analysis of 5 years of cold CO2 injection data at the Aquistore CCS site reveals injectivity improvement over time, driven by non-isothermal THM processes and stress-dependent permeability changes. Findings highlight the importance of THM effects for long-term CO2 containment and conformance in deep saline aquifers.
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事業の本格化が進み、苫小牧等での実証が行われている。本研究成果は、CO2圧入時の注入性評価やモニタリング手法に示唆を与え、国内のCCSプロジェクトの設計・運用に役立つ。
In the global GX context
Globally, CCS is critical for climate targets, and this study provides field-based evidence on injectivity evolution, informing best practices for CO2 storage operations and monitoring. It contributes to the understanding of THM processes in saline aquifers, relevant for CCS scale-up.
👥 読者別の含意
🔬研究者:Provides field data and modeling framework for non-isothermal THM effects on CO2 injectivity, useful for reservoir simulation and monitoring.
🏢実務担当者:Informs CCS project operators on injectivity management and monitoring strategies, potentially reducing operational risks.
🏛政策担当者:Supports evidence-based decision-making for CCS deployment and regulatory frameworks, highlighting long-term containment considerations.
📄 Abstract（原文）
Abstract This study examines the evolution of carbon dioxide (CO 2 ) injectivity during intermittent cold injection at the Aquistore site, a Canadian CO 2 capture and storage demonstration project. Continuous monitoring over 5 years of CO 2 injection, supported by two highly instrumented injection and observation wells, reveals a general improvement in injectivity performance with time. Bottomhole temperature records indicate persistent cooling near the injector, with injectivity performance inversely correlated to downhole temperature. A non‐isothermal modeling and monitoring framework is applied to interpret these trends through thermo‐hydro‐mechanical (THM) processes. Analysis of injection data using the injectivity index suggests that stress‐dependent non‐isothermal mechanisms and semi‐reversible changes in near‐wellbore permeability govern the observed behavior. During cold injection episodes, minimum effective stresses may exceed the tensile strength of the host rock, leading to aseismic pore deformation, tensile micro‐cracking, and reactivation of critically stressed fractures. Processes such as CO 2 /brine chemical interaction, rate‐dependent pore flow, and CO 2 phase behavior are not expected to enhance injectivity. While stress‐induced permeability changes may improve injectivity performance, non‐isothermal stress redistribution could also create flow pathways through low‐permeability formations, including caprock units. These findings highlight the importance of THM processes in injectivity modeling and underscore non‐isothermal effects as a critical consideration for long‐term CO 2 containment and conformance in deep saline aquifers.
🔗 Provenance — このレコードを発見したソース
- openalex https://doi.org/10.1002/dug2.70116first seen 2026-08-07 05:02:44
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