液態空氣儲能市場規模、佔有率及成長預測（2026-2032 年）

預計到 2026 年，液態空氣儲能市場規模將達到 2.4 億美元，到 2032 年將達到 22.5 億美元。這意味著從 2026 年到 2032 年的複合年成長率將達到 45.2%。

液態空氣儲能裝置主要分三個階段運作。充電階段，電力驅動壓縮機和冷凍設備，吸入環境空氣，去除水分和二氧化碳，並將剩餘氣體冷卻至液態。液態空氣以低壓儲存在絕熱的低溫儲存槽中。放電階段，低溫泵將液態空氣加壓，使其汽化並在熱交換器中加熱，然後高壓氣體通過與發電機相連的渦輪機膨脹。冷熱儲存設備回收壓縮產生的熱和膨脹產生的冷量，使其可在後續循環中重複使用。這種結構使液態空氣儲能裝置區別於電化學電池。輸出容量主要取決於由壓縮機、泵浦、渦輪機和發電機組成的系統。儲槽容積和儲存的液態空氣量對能量容量影響很大。因此，即使延長運作時間，也不需要複製整個輸出模組。此外，該系統與同步馬達和專用穩壓裝置結合使用時，還可提供同步慣性、電壓支撐和短路耐受能力。這創造了超越能源套利的價值。該技術受益於成熟的工業供應鏈，例如空氣分離、液化天然氣 (LNG)、低溫儲能、熱交換器和發電等領域。然而，液態空氣儲能需要將這些組件整合到一個最佳化的動態循環中，並達到可接受的往返效率。如果能夠利用工業廢熱或 LNG 再氣化產生的冷能，專案的經濟效益將會提升。住友重工的初日市工廠專門用於評估利用 LNG 冷能提高效率的方法。 Highview 在英國的計畫則著重於電網穩定性和減少可再生能源的棄風棄光。

市場促進因素

• 隨著可再生能源供需調整週期的延長，大容量儲能的價值日益凸顯。在以風電為主的電力系統中，可再生能源的過剩或短缺持續時間可能遠超晚尖峰時段時段。液態空氣儲能技術無需地理位置適宜的儲槽或地下洞穴，即可滿足6小時、10小時、12小時甚至更長的長期儲能需求。英國的《清潔能源靈活性藍圖》指出，到2030年，英國將需要4至6吉瓦的長期儲能容量，並以Highview公司的Carrington計畫為例，說明液態空氣儲能的商業性應用。這一政策環境正在推動後續大規模項目的發展。
• 模組化位置拓展了專案機遇，使其不再局限於抽水蓄能和鹽隧道儲能。液態空氣儲能可安裝在工業用地和棕地，無需像抽水蓄能那樣利用高程差，也無需像許多壓縮空氣項目那樣使用鹽隧道。這使得該計畫能夠選址在輸電變電站、可再生能源發電走廊和大規模需求中心附近。 Highview公司的Carrington計畫充分利用了現有的輸電基礎設施。 Hunterston計畫則建於原工業用地上，與電網連接良好。同樣，NRStor公司在安大略省提案的專案旨在提供電網容量服務，而無需依賴地下儲能地質條件。
• 整合工業熱能和冷能可以提高營運經濟效益。當專案能夠利用原本會被浪費的熱能和冷能時，動態循環的吸引力就會增加。液化天然氣（LNG）再氣化設施會排放大量冷能，利用這些冷能可以減少空氣液化所需的電力。因此，住友重工在初日市LNG接收站安裝了一座5兆瓦、20兆瓦時的商業示範裝置。此外，利用工業廢氣餘熱可以增加擴建工程量。這為與正在進行改造的流程工業和火力發電廠進行聯合選址創造了機會。
• 電網穩定服務有助於實現收入來源多元化。人們越來越期望長期儲能設施能夠支持能源轉型和電網穩定。 Highview 在英國的計畫包含一個“穩定島”，旨在提供慣性、短路耐受能力、電壓支撐和頻率響應，且這些功能獨立於儲能循環。這使得液態空氣儲能計畫能夠獲得僅靠傳統能源套利無法實現的電網服務收入。此外，這也增強了在電網受限或脆弱區域建造儲能電站的合理性。

市場限制因素

• 液態空氣儲能仍是資本密集型產業。專案開發比模組化鋰離子電池儲罐的引入更為複雜。儲能電站需要整合大型壓縮機、低溫設備、儲槽、熱交換器、泵浦、渦輪機、發電機以及土木工程。設計、授權和建設週期也更長。此外，除非熱能和冷能回收得到良好最佳化，或者有外部冷熱源可用，否則其往返效率通常低於鋰離子電池。供應商仍然高度集中。目前只有少數電站達到或接近商業規模運作。因此，專案的資金籌措潛力很大程度上取決於長期收益支援、電網服務合約以及對規模化發展的信心。

目錄

第1章執行摘要

• 市場機會與主要發現
• 長期儲存前景
• 拓展至商業規模及專案儲備

第2章 市場概覽

• 液態空氣儲能器的運行原理
• 空氣的壓縮、淨化和液化
• 低溫儲存
• 電力恢復和擴展
• 熱能回收和冷能回收
• 電網穩定性和混合動力電源的併網

第3章 市場規模及預測（2026-2032 年）

• 全球市場銷售
• 年增率分析
• 設備、EPC 和生命週期收入

第4章 市場：依系統組件分類

• 空氣壓縮和淨化
• 液化設備
• 低溫儲存槽
• 低溫泵
• 熱交換器和儲熱裝置
• 膨脹式渦輪機和發電機
• 電力和電網穩定系統

第5章 市場：依儲存期分類

• 不到8小時
• 8-12小時
• 12-24小時
• 超過24小時

第6章 市場：依工廠配置分類

• 獨立式 LAES
• LNG-低溫整合雷射原子能系統
• LAES，一種整合的工業廢熱。
• 混合式液態鋁電化學儲能系統和鋰離子電池組合
• LAES 和系統穩定島

第7章 市場：依應用分類

• 向可再生能源轉型
• 電網容量和可靠性
• 減少可再生能源輸出的棄用
• 系統穩定服務
• 工業和公共產業微電網

第8章 市場：依專案規模分類

• 小於100兆瓦時
• 100～500 MWh
• 500 MWh～2 GWh
• 2吉瓦時或以上

第9章：地方市場

• 歐洲
  • 英國
  • 其他歐洲國家
• 亞太地區
  • 日本
  • 韓國
  • 其他亞太國家
• 北美洲
  • 加拿大
  • 美國
• 世界其他地區

第10章 市場動態

• 促進因素
  • 在數小時和數天的時間內調整可再生能源的供需。
  • 靈活的位置和地質相關的儲存
  • 廢熱與液化天然氣低溫利用的整合
  • 從系統穩定中獲利
• 抑制因子
  • 高昂的初始投資成本
  • 往返效率
  • 漫長的開發與建設週期
  • 商業營運經驗有限

第11章 競爭格局

• 自主研發LAES技術的公司。
• 承包工程總承包及許可合作夥伴
• 低溫設備供應商
• 渦輪機械和電氣設備供應商
• 專案開發商、投資者和電力公司

第12章：公司簡介

第13章 近期趨勢

第14章附錄

The Liquid Air Energy Storage Market is estimated at USD 0.24 billion in 2026 and is projected to reach USD 2.25 billion by 2032, representing a CAGR of 45.2% over 2026-2032.

A liquid air energy storage plant operates in three main stages. During charging, electricity powers compressors and refrigeration equipment that draw in ambient air, remove water and carbon dioxide and cool the remaining gases until the air becomes liquid. The liquid air is stored at low pressure in insulated cryogenic tanks. During discharge, cryogenic pumps raise the liquid pressure, heat exchangers vaporize and warm it, and the high-pressure gas expands through turbines connected to generators. Thermal and cold stores capture heat from compression and cold from expansion so that both can be reused in later cycles. This architecture makes liquid air energy storage different from electrochemical batteries. Power capacity is mainly determined by the compressor, pump, turbine and generator trains. Energy capacity is strongly influenced by tank volume and stored liquid-air inventory. Increasing duration therefore does not require duplicating the full power block. The system can also provide synchronous inertia, voltage support and short-circuit strength when paired with synchronous machinery or dedicated stability equipment. This creates value beyond energy arbitrage. The technology benefits from mature industrial supply chains in air separation, liquefied natural gas, cryogenic storage, heat exchangers and power generation. However, liquid air energy storage must integrate these components into an optimized thermodynamic cycle with acceptable round-trip efficiency. Project economics improve when waste heat from industry or cold from LNG regasification is available. Sumitomo Heavy Industries' Hatsukaichi plant is specifically designed to evaluate efficiency gains from LNG cold energy. Highview's UK projects emphasize grid stability and renewable-curtailment reduction.

Market Drivers

• Longer renewable-balancing periods increase the value of bulk storage. Wind-dominant power systems can experience renewable surpluses and deficits lasting far longer than the evening peak. Liquid air energy storage can be configured for six hours, ten hours, twelve hours or substantially longer without requiring a geographically suitable reservoir or underground cavern. The United Kingdom's Clean Flexibility Roadmap identifies a requirement for 4 GW to 6 GW of long-duration electricity storage by 2030 and cites Highview's Carrington project as a commercial liquid air energy storage case study. This policy environment supports development of larger follow-on projects.
• Modular siting expands the project opportunity beyond pumped hydro and cavern storage. Liquid air energy storage can be located on industrial or brownfield land. It does not require the elevation difference of pumped hydro or the salt caverns used by many compressed-air projects. This allows development near transmission substations, renewable-generation corridors and large demand centers. Highview's Carrington project uses existing transmission infrastructure. Hunterston is being developed at a former industrial site with strong grid connectivity. NRStor's proposed Ontario project similarly targets grid-capacity services without dependence on underground storage geology.
• Industrial heat and cold integration can improve operating economics. The thermodynamic cycle becomes more attractive when a project can use otherwise wasted heat or cold. LNG regasification facilities reject substantial cold energy, which can reduce the electricity required for air liquefaction. Sumitomo Heavy Industries located its 5 MW and 20 MWh commercial demonstration plant at the Hatsukaichi LNG terminal for this reason. Industrial waste heat can also be used during discharge to increase expansion work. This creates opportunities for co-location with process industries and thermal-power sites being repurposed.
• Grid-stability services increase revenue diversity. Long-duration storage assets are increasingly expected to support both energy shifting and power-system stability. Highview's UK projects incorporate a stability island intended to provide inertia, short-circuit strength, voltage support and frequency response independently of the storage cycle. This gives liquid air energy storage projects access to grid-service revenue streams that ordinary energy arbitrage alone may not provide. It also strengthens the case for locating plants at constrained or weak parts of transmission networks.

Market Restraints

• Liquid air energy storage remains capital intensive. Project development is more complex than deploying modular lithium-ion containers. The plant combines large compressors, cryogenic equipment, tanks, heat exchangers, pumps, turbines, generators and civil works. Design, permitting and construction periods are longer. Round-trip efficiency is also generally lower than lithium-ion unless thermal and cold recovery are well optimized or external heat and cold sources are available. The supplier base remains concentrated. Only a small number of plants have operated at commercial or near-commercial scale. Project bankability therefore depends heavily on long-term revenue support, grid-service contracts and confidence in scale-up.

Technology and Segment Insights

• Standalone liquid air energy storage plants use electricity from the grid or co-located renewable generation to liquefy air, store it and later generate power through expansion. Integrated plants add external thermal or cold-energy sources, which can reduce charging energy or increase discharge output. LNG-integrated liquid air energy storage is particularly attractive because the regasification process provides a high-quality cold source that would otherwise be rejected. Hybrid systems can combine liquid air energy storage with lithium-ion batteries or dedicated synchronous equipment. This allows short-duration response, long-duration energy and grid-stability functions to be optimized separately.
• The largest near-term value growth is expected in multi-gigawatt-hour grid projects. Highview's planned UK Millennium Series moves from Carrington's 300 MWh scale to facilities in the 2.5 GWh to 3.2 GWh range. At these sizes, project value increasingly shifts toward large turbomachinery, cryogenic storage, civil works, grid connection and engineering, procurement and construction capability rather than only proprietary process design.
• Air compression and purification compresses and conditions ambient air before liquefaction. This is a major charging-side capital block. The direction is scaling to larger compressor trains. Air liquefaction cools air to cryogenic liquid. It is the core process technology. The direction is efficiency improvement through cold recovery. Cryogenic storage tanks store liquid air at low pressure. This is the primary energy-capacity component. Tank volume grows with storage duration. Cryogenic pumps and heat exchangers pressurize and vaporize liquid air. These are critical discharge and efficiency equipment. The direction is higher integration with waste heat and LNG cold. The expansion turbine and generator converts pressurized gas into electricity. This is the primary discharge power block. The direction is increasing unit size for grid projects. Stability and hybrid equipment provides inertia, voltage support and fast response. This is an additional revenue layer. It is growing in UK grid applications.
• The market is segmented by system component, storage duration, plant configuration, application, project scale and geography. System components include air compression and purification, liquefaction equipment, cryogenic storage tanks, cryogenic pumps, heat exchangers and thermal stores, expansion turbines and generators, and electrical and grid-stability systems. Storage durations include below 8 hours, 8-12 hours, 12-24 hours, and above 24 hours. Plant configurations include standalone liquid air energy storage, LNG-cold integrated, industrial waste-heat integrated, hybrid liquid air energy storage plus lithium-ion, and liquid air energy storage plus grid-stability island. Applications include renewable energy shifting, grid capacity and reliability, renewable curtailment reduction, grid stability services, and industrial and utility microgrids. Project scales include below 100 MWh, 100-500 MWh, 500 MWh to 2 GWh, and above 2 GWh.
• Commercial deployment is moving from 20 MWh-class demonstrations toward 300 MWh and multi-gigawatt-hour projects. The technology uses industrial gas and turbomachinery components rather than critical battery minerals. Waste heat and LNG cold energy can materially improve system efficiency where suitable industrial integration exists. Europe leads the current commercial pipeline, while Japan, Canada and South Korea are creating additional deployment centers.

Competitive and Strategic Outlook

• Highview Power remains the principal proprietary liquid air energy storage technology developer and the company with the largest announced commercial pipeline. Its platform integrates liquefaction, thermal storage, cryogenic storage, power recovery and grid-stability functions. The company has also licensed the technology internationally, enabling deployment by partners such as Sumitomo Heavy Industries.
• Sumitomo SHI FW provides turnkey engineering, procurement and construction solutions using licensed Highview technology and remains an active liquid air energy storage solution provider. Sumitomo Heavy Industries operates the Hatsukaichi demonstration plant within the same corporate group and is therefore not counted as a separate competitor. NRStor is a project developer. Alfa Laval, Siemens Energy and other cryogenic, turbomachinery and engineering, procurement and construction companies are treated as equipment or project-ecosystem suppliers rather than standalone liquid air energy storage technology vendors.
• The market remains highly concentrated. Highview provides the proprietary liquid air energy storage platform. Sumitomo SHI FW offers licensed turnkey liquid air energy storage solutions.
• Europe is the leading commercial market for liquid air energy storage. The United Kingdom has created the most advanced combination of demonstration experience, project finance, long-duration-storage policy and announced multi-gigawatt-hour pipeline. Highview Power operated an earlier 5 MW demonstrator near Bury and is now constructing the 50 MW and 300 MWh Carrington facility. The project has attracted backing from the National Wealth Fund, Centrica and other institutional investors. This gives liquid air energy storage a commercial financing precedent rather than only public research support.
• The next phase is significantly larger. Highview has announced a programme of four follow-on plants at approximately 2.5 GWh each, including Hunterston in Scotland. Hunterston is being developed in phases, with grid-stability infrastructure preceding the liquid-air storage build-out. The project model is important because it allows revenue from inertia, voltage support and short-circuit strength to complement the energy-storage value of the liquid air energy storage plant.
• United Kingdom policy is also supportive. The government's long-duration electricity storage cap-and-floor mechanism is intended to reduce revenue uncertainty for projects with high upfront capital cost and long asset life. Highview's Hunterston and Killingholme projects were selected for further consideration under this framework. The broader Clean Power 2030 programme estimates several gigawatts of additional long-duration storage will be needed. This creates a sizeable addressable market if liquid air energy storage projects achieve targeted cost and efficiency.
• Asia Pacific is the second most important development region. Japan's Hatsukaichi facility is already operating commercially as a demonstration project and tests the use of LNG cold energy. South Korea is developing its first large-scale facility with cryogenic equipment from Alfa Laval. North America is emerging through NRStor's proposed 200 MW and 2,000 MWh Ontario project. Other regions remain at an earlier stage of project development.
• Recent developments confirm accelerating market activity. In July 2026, NRStor held a public open house for its proposed St. Clair Township liquid air energy storage project in Ontario, planned at up to 200 MW and 2,000 MWh. In May 2026, Highview appointed Peter Jones as Chief Executive as the company advances construction and scale-up of its UK long-duration-storage programme. In 2026, Alfa Laval announced a partnership with South Korea's Institute for Advanced Engineering to supply cryogenic heat exchangers and a high-pressure pump for the country's first large-scale liquid air energy storage facility. In 2026, Highview continued development and consultation for the Hunterston project, including phase-two liquid-air storage plans following the grid-stability phase. In December 2025, Sumitomo Heavy Industries began commercial operation of the 5 MW and 20 MWh Hatsukaichi liquid air energy storage demonstration plant in Hiroshima Prefecture. In November 2025, Highview formally broke ground on the 50 MW and 300 MWh Carrington commercial-scale liquid air energy storage facility in Greater Manchester.

Conclusion

• The liquid air energy storage market is at an early commercial stage with very high growth potential. Growth is driven by multi-hour and multi-day renewable balancing, flexible siting, waste heat and LNG cold integration and grid-stability revenue. Commercial deployment is moving from 20 MWh-class demonstrations toward 300 MWh and multi-gigawatt-hour projects. Europe leads the current commercial pipeline. Asia Pacific and North America are creating additional deployment centers. High upfront capital cost, round-trip efficiency and limited commercial operating history remain the key restraints. The market is highly concentrated around Highview Power and its licensed partners. The market is projected to grow from USD 0.24 billion in 2026 to USD 2.25 billion by 2032 at a CAGR of 45.2%.

Key Benefits of this Report

• Insightful Analysis: Detailed market insights across regions, customer segments, policies, socio-economic factors, consumer preferences, and industry verticals.
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• Market Drivers and Future Trends: Assess major growth forces and emerging developments shaping the market.
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Report Coverage

• Historical data from 2021 to 2024, Base year 2025, and Forecast years from 2026 to 2032
• Growth opportunities, challenges, supply chain outlook, regulatory framework, and trend analysis
• Competitive positioning, strategies, and market share evaluation, and trade analysis
• Revenue growth and forecast assessment across segments and regions
• Company profiling including strategies, products, financials, and key developments

TABLE OF CONTENTS

1. Executive Summary

• 1.1. Market Opportunity and Key Findings
• 1.2. Long-Duration Storage Outlook
• 1.3. Commercial Scale-Up and Project Pipeline

2. Market Overview

• 2.1. Liquid Air Energy Storage Operating Principle
• 2.2. Air Compression, Purification and Liquefaction
• 2.3. Cryogenic Storage
• 2.4. Power Recovery and Expansion
• 2.5. Thermal and Cold Recovery
• 2.6. Grid Stability and Hybrid Integration

3. Market Size and Forecast, 2026-2032

• 3.1. Global Market Revenue
• 3.2. Annual Growth Analysis
• 3.3. Equipment, EPC and Lifecycle Revenue

4. Market by System Component

• 4.1. Air Compression and Purification
• 4.2. Liquefaction Equipment
• 4.3. Cryogenic Storage Tanks
• 4.4. Cryogenic Pumps
• 4.5. Heat Exchangers and Thermal Stores
• 4.6. Expansion Turbines and Generators
• 4.7. Electrical and Grid-Stability Systems

5. Market by Storage Duration

• 5.1. Below 8 Hours
• 5.2. 8-12 Hours
• 5.3. 12-24 Hours
• 5.4. Above 24 Hours

6. Market by Plant Configuration

• 6.1. Standalone LAES
• 6.2. LNG-Cold Integrated LAES
• 6.3. Industrial Waste-Heat Integrated LAES
• 6.4. Hybrid LAES plus Lithium-Ion
• 6.5. LAES plus Grid-Stability Island

7. Market by Application

• 7.1. Renewable Energy Shifting
• 7.2. Grid Capacity and Reliability
• 7.3. Renewable Curtailment Reduction
• 7.4. Grid Stability Services
• 7.5. Industrial and Utility Microgrids

8. Market by Project Scale

• 8.1. Below 100 MWh
• 8.2. 100-500 MWh
• 8.3. 500 MWh-2 GWh
• 8.4. Above 2 GWh

9. Regional Market

• 9.1. Europe
  • 9.1.1. United Kingdom
  • 9.1.2. Rest of Europe
• 9.2. Asia Pacific
  • 9.2.1. Japan
  • 9.2.2. South Korea
  • 9.2.3. Rest of Asia Pacific
• 9.3. North America
  • 9.3.1. Canada
  • 9.3.2. United States
• 9.4. Rest of World

10. Market Dynamics

• 10.1. Drivers
  • 10.1.1. Multi-Hour and Multi-Day Renewable Balancing
  • 10.1.2. Flexible Siting versus Geology-Dependent Storage
  • 10.1.3. Waste Heat and LNG Cold Integration
  • 10.1.4. Grid-Stability Revenue
• 10.2. Restraints
  • 10.2.1. High Upfront Capital Cost
  • 10.2.2. Round-Trip Efficiency
  • 10.2.3. Long Development and Construction Period
  • 10.2.4. Limited Commercial Operating History

11. Competitive Landscape

• 11.1. Proprietary LAES Technology Developers
• 11.2. Turnkey EPC and License Partners
• 11.3. Cryogenic Equipment Suppliers
• 11.4. Turbomachinery and Electrical Suppliers
• 11.5. Project Developers, Investors and Utilities

12. Company Profiles

13. Recent Developments

14. Appendix