タイ北東部の枯渇ガス炭酸塩岩貯留層におけるCO2地下利用・貯留容量の動的検証
Dynamic validation of subsurface CO2 utilization and storage capacity in depleted gas carbonate reservoirs, northeastern Thailand (原題)
Thotsaphon Chaianansutcharit, Sukonmeth Jitmahantakul, Pornphun Pornkulprasit
🤖 gxceed AI 要約
日本語
タイ北東部シンプーホーンガス田を対象に、数値シミュレータでCCS/CCUSの実現可能性を評価した先駆的ケース。実フィールドの動的データと履歴整合によりOGIPを絞り込み、CO2貯留容量を再評価。20年間の注入で圧力が780→1,010psiに回復し、EGRにより回収率が4〜7%向上することを示した。
English
A pioneer CCUS case study of the Sin Phu Horm gas field in northeastern Thailand, using the Intersect IX simulator with history matching to refine OGIP and CO2 storage capacity. Over 20 years of injection at 0.19 MtCO2/yr, reservoir pressure rebounds from 780 to 1,010 psi, and CO2-EGR adds 4-7% incremental recovery while meeting gas sales CO2 constraints.
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
日本企業が東南アジアでCCUS事業を展開する際の貯留層評価ワークフローとして参考になる。JOGMEC等の海外CCS案件検討や、枯渇ガス田活用の事業性評価に示唆を与える。
In the global GX context
Adds an emerging-economy onshore depleted-gas-field case to the global CCUS evidence base, complementing CCS hubs in the US, EU, and Australia. Relevant to transition finance and Article 6 / cross-border CCS discussions where storage security and commercial gas recovery must be jointly demonstrated.
👥 読者別の含意
🔬研究者:枯渇炭酸塩岩貯留層におけるCCS-EGR統合評価の実データ検証手法を学べる。
🏢実務担当者:枯渇ガス田をCCUS資産化する際の貯留容量・回収率評価の実務ワークフローとして活用可能。
🏛政策担当者:タイ等新興国でのCCS規制・インセンティブ設計や炭素貯留ポテンシャル評価の基礎資料になる。
📄 Abstract（原文）
To address Environmental, Social, and Governance (ESG) concern, regarding climate action, the Intersect IX numerical simulator was used to evaluate a potential for carbon dioxide (CO2) geological storage and Carbon Capture Utilization and Storage (CCUS) opportunities in the Sin Phu Horm gas field, northeastern Thailand. The actual field dynamic data, comprising pressure and production records, were applied to narrow down the ranges of uncertainties on the original gas-in-place (OGIP) of the reservoir model via the history matching process. Permeability anisotropy, representing the natural fracture network, was incorporated to accommodate well-level pressure matching. The results reveal a smaller OGIP volume than previously estimated, which alter CO2 storage capacity. After the end of the simulated field life, the gas recovery factor from this reservoir is forecasted to be 81%, with reservoir pressure of 2.2 ppg. - considerable depletion level and CO2 storage potential. The simulated results, after 20 years of Carbon Capture and Storage (CCS) process, indicate that reservoir pressure rebounds from 780 to 1,010 psi, from 0.19 MtCO2 per year injection rate, leaving significant remaining spare capacity. Enhanced Gas Recovery (EGR) potential, CCUS, from CO2 injection could add 4 to 7 percent incremental recovery factor benefit to the field reserves while meeting a gas sales CO2 composition constraint. This integrated CCS-EGR study provides, as a pioneer case for a Thailand onshore gas field, a workflow to assess both storage security and commercial gas recovery, showing that CCUS is technically viable in a mature Thailand depleted gas fields.
🔗 Provenance — このレコードを発見したソース
- semanticscholar https://doi.org/10.4186/ej.2026.30.9.1first seen 2026-10-04 05:12:21 · last seen 2026-10-07 05:32:40
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