英國石油天然氣：市場佔有率分析、產業趨勢與統計、成長預測（2026-2031）

英國石油和天然氣市場預計將從 2025 年的 108.5 億美元成長到 2026 年的 111.4 億美元，到 2031 年達到 127.2 億美元，2026 年至 2031 年的複合年成長率為 2.69%。

這項穩定擴張得益於策略轉型，旨在最大限度地釋放北海成熟油田的價值，並有意放緩新探勘活動。自2020年以來，營運商已將鑽井成本降低了15%至20%，在財務負擔日益加重的情況下仍保持了盈利。 2024年的投資金額超過60億英鎊，是監管機構預期的1.5倍，主要用於延長油田壽命計畫和支援碳捕獲基礎設施的中游升級改造。獨立公司之間的整合加速，促成了兩項總額超過20億美元的重大收購，實現了成本協同效應和退役效率的提升。同時，離岸風力發電試驗和平台電氣化降低了柴油消耗，顯示排放合規和生產穩定性可以兼得。

英國油氣市場趨勢與洞察

降低北海採礦成本可提高營運效率

北海鑽井成本大幅下降，使英國營運商在全球能源市場挑戰中擁有了競爭優勢。自2020年以來，海底系統的技術突破和鑽井技術的改進已使每桶生產成本降低了15-20%，從而在日益成長的財務壓力下維持了生產的永續性。這種成本降低的趨勢使英國油田在與國際競爭對手的較量中佔據優勢，尤其是在能源安全問題日益突出、國內石油產量價值不斷提升的情況下。效率的提高得益於先進的儲存管理系統和最佳化的生產計劃，從而在最大限度地提高採收率的同時，最大限度地降低了營運成本。營運商正利用這些成本優勢，為繼續投資那些可能因獲利能力下降而提前退役的成熟資產以及延長油田壽命提供理由。

英國北海轉型協議獎勵重塑投資重點

英國北海轉型協議為在實現淨零排放目標方面取得顯著進展的營運商提供系統性的財政獎勵，從根本上改變了整個產業的資本配置決策。投資補貼和更高的折舊免稅額率鼓勵企業將碳捕獲、利用與儲存（CCUS）技術整合到其營運中，符合條件的計劃可獲得高達合格支出40%的加速稅收合格。該政策框架已承諾從2024年起投入超過20億英鎊用於CCUS投資，將先前無利可圖的計劃轉變為可行的開發機會。該協議為在排放展現技術領先優勢的營運商提供了競爭優勢，有效支持了向低碳油氣生產的轉型。 ISO 14001環境管理系統認證對於獲得這些激勵措施的重要性日益凸顯，營運商正大力投資合規流程。

加速徵收CCS課稅給企業現金流帶來壓力

英國大陸棚上游業者加速徵收捕碳封存（CCS）附加稅，正給整個區域帶來即時的財務壓力。主要生產商的合規成本估計每年高達1.5億至2億英鎊。法規結構要求營運商無論是否參與具體計劃，都必須為國家CCS基礎設施建設做出貢獻，這實際上是透過產業課稅補貼更廣泛的能源轉型目標。這種徵稅結構對缺乏規模來承擔額外成本的中小型獨立運營商造成了不成比例的影響，可能加速邊緣運營商尋求更大的合作夥伴或徹底退出市場。遵守徵稅規定需要加強監測和報告能力，這增加了營運的複雜性，並進一步加劇了資源緊張。

細分市場分析

2025年上游業務71.65%的市佔率占主導地位，顯示開採活動仍是英國油氣業務的核心。然而，中游業務到2031年的複合年成長率（CAGR）為4.18%，預示著該業務將發生根本性轉變，轉向基礎設施和加工投資。上游業務受益於提高採收率技術和油田延壽計劃，這些措施最大限度地提高了現有北海資產的價值。像Harbour Energy這樣的業者在2024年投資超過13億美元用於資產收購，以整合產能。中游業務的加速成長是由碳捕獲、利用和封存（CCUS）計劃所需的關鍵基礎設施所驅動的，這些項目需要對管道網路和加工設施進行重大升級，以滿足二氧化碳運輸和氫氣生產的需求。由於對成品油的需求，下游業務保持穩定，但長期來看，電氣化趨勢和可再生燃料強制令將對其構成挑戰。

中游基礎設施投資尤其集中在東海岸叢集，其中Kerath Midstream的H2NorthEast工廠擁有1吉瓦的藍氫生產能力，這將需要大規模的管道維修和新建壓縮站。預計到2025年，英國中游市場規模將達到21.9億美元，年成長率將比產業平均高出1.5個百分點。英國天然氣輸送系統由超過7,600公里的高壓管道組成，國家電網每年投資25億英鎊用於網路維護和升級計劃，以支援傳統的天然氣輸送和新興的氫能應用。浮式生產儲油卸油設備）的引入正在擴大處理能力，並使以前難以開發的蘊藏量得以開發。同時，戰略石油儲備的要求以及平滑季節性需求的需求也促進了儲能基礎設施的發展。

其他福利：

• Excel格式的市場預測（ME）表
• 3個月的分析師支持

目錄

第1章 引言

• 研究假設和市場定義
• 調查範圍

第2章調查方法

第3章執行摘要

第4章 市場情勢

• 市場概覽
• 市場促進因素
  • 北海採礦成本呈下降趨勢。
  • 英國北海過渡協議的獎勵
  • 浮動式風力發電平台快速增加（降低探勘和生產成本）
  • 蒂斯河畔和亨伯河畔地區的再工業化（藍氫需求）
  • 基於人工智慧的探勘影像處理的成功率
• 市場限制
  • 加快對上游企業課稅碳捕獲與封存稅。
  • 併網離岸風力發電可望取代天然氣尖峰時段需求。
  • 加強退役保證金要求
• 供應鏈分析
• 監管環境
• 技術展望
• 原油產量和消費量預測
• 天然氣生產與消費預測
• 已安裝管道容量分析
• 非傳統資源資本支出展望（緻密油、油砂、深水）
• 波特五力模型
  • 供應商的議價能力
  • 消費者議價能力
  • 新進入者的威脅
  • 替代品的威脅
  • 競爭對手之間的競爭
• PESTEL 分析

第5章 市場規模與成長預測

• 按行業
  • 上游部門
  • 中游產業
  • 下游產業
• 按安裝位置
  • 陸上
  • 離岸
• 透過服務
  • 建造
  • 維護和檢修
  • 退休

第6章 競爭情勢

• 市場集中度
• 策略性舉措（併購、聯盟、購電協議）
• 市場佔有率分析（主要企業的市場排名和佔有率）
• 公司簡介
  • Shell plc
  • BP plc
  • Harbour Energy plc
  • TotalEnergies SE
  • Equinor ASA
  • Chevron Corp.
  • Centrica plc
  • Valaris plc
  • INEOS Group Ltd
  • ConocoPhillips UK Ltd
  • EnQuest plc
  • Ithaca Energy plc
  • Neptune Energy Group
  • Cadent Gas Ltd
  • Dana Petroleum Ltd
  • ESSO UK Ltd
  • BG Group Ltd
  • Premier Oil（Chrysaor）
  • Wood plc
  • Subsea 7 SA

第7章 市場機會與未來展望

The United Kingdom Oil And Gas market is expected to grow from USD 10.85 billion in 2025 to USD 11.14 billion in 2026 and is forecast to reach USD 12.72 billion by 2031 at 2.69% CAGR over 2026-2031.

A strategic shift toward squeezing maximum value from mature North Sea reservoirs, paired with a deliberate slowdown in greenfield exploration, underpins this measured expansion. Operators have reduced lifting costs by 15-20% since 2020, thereby protecting profitability even as fiscal burdens increase. The 2024 investment outlay of more than £6 billion, half again above regulator expectations, flowed mainly into life-extension programs and midstream upgrades that support carbon-capture infrastructure. Consolidation among independents accelerated, with two headline acquisitions totaling more than USD 2 billion, unlocking cost synergies and decommissioning efficiencies. At the same time, floating-wind pilots and on-platform electrification cut diesel burn, proving that emissions compliance and production stability can coexist.

United Kingdom Oil And Gas Market Trends and Insights

Declining North Sea Lifting Costs Drive Operational Efficiency

North Sea lifting costs have decreased substantially, creating competitive advantages for UK operators amid global energy market challenges. Technological breakthroughs in subsea systems and enhanced drilling techniques have cut per-barrel extraction costs by 15-20% since 2020, sustaining production viability despite heightened fiscal pressures. This cost reduction trajectory positions UK fields favorably against international alternatives, particularly as energy security concerns elevate domestic production value. The efficiency gains result from advanced reservoir management systems and optimized production scheduling, which maximize recovery rates while minimizing operational expenses. Operators leverage these cost improvements to extend field life and justify continued investment in mature assets that might otherwise face early decommissioning.

UK North Sea Transition Deal Incentives Reshape Investment Priorities

The UK North Sea Transition Deal offers structured fiscal incentives to operators demonstrating measurable progress toward net-zero emissions targets, thereby fundamentally altering capital allocation decisions across the sector. Investment allowances and enhanced depletion rates reward companies that integrate carbon capture, utilization, and storage technologies into their operations, with qualifying projects receiving accelerated tax relief worth up to 40% of eligible expenditures. This policy framework has catalyzed over £2 billion in committed CCUS investments since 2024, transforming previously uneconomical projects into viable development opportunities. The deal creates competitive advantages for operators demonstrating technological leadership in emissions reduction, effectively subsidizing the transition toward lower-carbon hydrocarbon production. ISO 14001 environmental management certification has become increasingly critical for accessing these incentives, with operators investing heavily in compliance processes.

Accelerated CCS Levy Strains Operator Cash Flows

The introduction of accelerated carbon capture and storage levies on upstream operators has created immediate financial pressure across the UK Continental Shelf, with compliance costs estimated at £150-200 million annually for major producers. This regulatory framework requires operators to contribute to national CCS infrastructure development regardless of their individual project participation, effectively subsidizing broader energy transition objectives through sector-specific taxation. The levy structure disproportionately impacts smaller independents who lack the scale to absorb these additional costs, potentially accelerating consolidation as marginal operators seek larger partners or exit the market entirely. Compliance with the levy requirements demands enhanced monitoring and reporting capabilities, which add operational complexity and further strain resources.

Other drivers and restraints analyzed in the detailed report include:

1. Floating Wind Platform Integration Reduces Operational Carbon Intensity
2. Teesside and Humber Industrial Clusters Create Blue Hydrogen Demand
3. Offshore Wind Grid Integration Reduces Peak Gas Demand

For complete list of drivers and restraints, kindly check the Table Of Contents.

Segment Analysis

The upstream segment's commanding 71.65% market share in 2025 reflects the continued centrality of extraction activities to UK oil and gas operations, yet the midstream segment's 4.18% CAGR through 2031 signals a fundamental shift toward infrastructure and processing investments. Upstream activities benefit from enhanced recovery techniques and extended field life programs that maximize value from existing North Sea assets. Operators like Harbour Energy have invested over USD 1.3 billion in asset acquisitions during 2024 to consolidate production capabilities. The midstream segment's accelerated growth stems from critical infrastructure requirements for carbon capture, utilization, and storage projects, with pipeline networks and processing facilities requiring substantial upgrades to handle CO2 transport and hydrogen production. Downstream operations maintain steady performance through refined product demand, though the segment faces long-term headwinds from electrification trends and renewable fuel mandates.

Midstream infrastructure investments are particularly concentrated in the East Coast Cluster, where Kellas Midstream's H2NorthEast facility represents a 1 GW blue hydrogen production capability that necessitates extensive pipeline modifications and the installation of new compression stations. The UK oil and gas market size for midstream operations reached USD 2.19 billion in 2025, with annual growth rates exceeding the sector average by 1.5 percentage points. The UK's gas transmission system spans over 7,600 km of high-pressure pipelines, with National Grid investing £2.5 billion annually in network maintenance and enhancement projects that support both traditional gas transport and emerging hydrogen applications. Processing capabilities are expanding through the deployment of floating production, storage, and offloading vessels, which enable the development of previously stranded reserves. Meanwhile, storage infrastructure benefits from strategic petroleum reserve requirements and seasonal demand balancing needs.

The United Kingdom Oil and Gas Market is Segmented by Sector (Upstream, Downstream, and Midstream), Location (Onshore and Offshore), and Service (Construction, Maintenance and Turn-Around, and Decommissioning). The Market Sizes and Forecasts are Provided in Terms of Value (USD).

List of Companies Covered in this Report:

1. Shell plc
2. BP plc
3. Harbour Energy plc
4. TotalEnergies SE
5. Equinor ASA
6. Chevron Corp.
7. Centrica plc
8. Valaris plc
9. INEOS Group Ltd
10. ConocoPhillips UK Ltd
11. EnQuest plc
12. Ithaca Energy plc
13. Neptune Energy Group
14. Cadent Gas Ltd
15. Dana Petroleum Ltd
16. ESSO UK Ltd
17. BG Group Ltd
18. Premier Oil (Chrysaor)
19. Wood plc
20. Subsea 7 SA

Additional Benefits:

• The market estimate (ME) sheet in Excel format
• 3 months of analyst support

TABLE OF CONTENTS

1 Introduction

• 1.1 Study Assumptions & Market Definition
• 1.2 Scope of the Study

2 Research Methodology

3 Executive Summary

4 Market Landscape

• 4.1 Market Overview
• 4.2 Market Drivers
  • 4.2.1 Declining North Sea lifting costs
  • 4.2.2 UK "North Sea Transition Deal" incentives
  • 4.2.3 Surge in floating-wind-powered platforms (E&P cost cuts)
  • 4.2.4 Re-industrialisation of Teesside & Humber (blue hydrogen demand)
  • 4.2.5 AI-enabled seismic imaging success rates
• 4.3 Market Restraints
  • 4.3.1 Accelerated CCS levy on upstream operators
  • 4.3.2 Grid-connected offshore wind cannibalising peak-time gas demand
  • 4.3.3 Heightened decommissioning bond requirements
• 4.4 Supply-Chain Analysis
• 4.5 Regulatory Landscape
• 4.6 Technological Outlook
• 4.7 Crude-Oil Production & Consumption Outlook
• 4.8 Natural-Gas Production & Consumption Outlook
• 4.9 Installed Pipeline Capacity Analysis
• 4.10 Unconventional Resources CAPEX Outlook (tight oil, oil sands, deep-water)
• 4.11 Porter's Five Forces
  • 4.11.1 Bargaining Power of Suppliers
  • 4.11.2 Bargaining Power of Consumers
  • 4.11.3 Threat of New Entrants
  • 4.11.4 Threat of Substitutes
  • 4.11.5 Intensity of Competitive Rivalry
• 4.12 PESTLE Analysis

5 Market Size & Growth Forecasts

• 5.1 By Sector
  • 5.1.1 Upstream
  • 5.1.2 Midstream
  • 5.1.3 Downstream
• 5.2 By Location of Deployment
  • 5.2.1 Onshore
  • 5.2.2 Offshore
• 5.3 By Service
  • 5.3.1 Construction
  • 5.3.2 Maintenance and Turn-around
  • 5.3.3 Decommissioning

6 Competitive Landscape

• 6.1 Market Concentration
• 6.2 Strategic Moves (M&A, Partnerships, PPAs)
• 6.3 Market Share Analysis (Market Rank/Share for key companies)
• 6.4 Company Profiles (includes Global level Overview, Market level overview, Core Segments, Financials as available, Strategic Information, Products & Services, and Recent Developments)
  • 6.4.1 Shell plc
  • 6.4.2 BP plc
  • 6.4.3 Harbour Energy plc
  • 6.4.4 TotalEnergies SE
  • 6.4.5 Equinor ASA
  • 6.4.6 Chevron Corp.
  • 6.4.7 Centrica plc
  • 6.4.8 Valaris plc
  • 6.4.9 INEOS Group Ltd
  • 6.4.10 ConocoPhillips UK Ltd
  • 6.4.11 EnQuest plc
  • 6.4.12 Ithaca Energy plc
  • 6.4.13 Neptune Energy Group
  • 6.4.14 Cadent Gas Ltd
  • 6.4.15 Dana Petroleum Ltd
  • 6.4.16 ESSO UK Ltd
  • 6.4.17 BG Group Ltd
  • 6.4.18 Premier Oil (Chrysaor)
  • 6.4.19 Wood plc
  • 6.4.20 Subsea 7 SA

7 Market Opportunities & Future Outlook

• 7.1 White-space & Unmet-Need Assessment