泰國上游油氣市場：市場佔有率分析、產業趨勢與統計及成長預測（2026-2031年）

據 Mordor Intelligence 稱，2025 年泰國上游油氣市場價值 33.3 億美元，預計到 2031 年將從 2026 年的 35.2 億美元成長至 46.2 億美元，預測期（2026-2031 年）複合年成長率為 5.59%。

本報告按部署區域（陸上和海上）、資源類型（原油和天然氣）、油井類型（常規和非常規）以及服務（探勘、開發和生產以及退役）進行細分。市場規模和預測均以美元計價。

泰國上游油氣市場的趨勢與洞察

擴大埃拉旺/邦科特叢集的產能

2024年，PTTEP以28億美元收購了雪佛龍在泰國的油氣資產組合，並立即啟動了鑽井和設施維修宣傳活動。該計畫旨在2026年將Erawan和Bongkot油田的總合產量提升至8億標準立方英尺/日（MMSCFD）。透過共用相鄰區塊的壓縮、加工和物流資產，一體化管理已將單位開發成本降低了約15-20%。遵守泰國「單一天然氣價格」政策確保了可預測的長期利潤率，這將使在更深的地層引入增產技術成為可能，並有可能將油田的壽命延長至多10年。 PTTEP的人工智慧與機器人創投部門已部署了預測性維護無人機和邊緣分析感測器，這些設備已有效減少了兩個油田設施的意外運作。

對第24期和第25期油氣許可競標和產品分成協議（PSC）進行根本性審查

2024年的監管改革在傳統採礦權的基礎上引入了產品分成合約（PSC），旨在平衡國家財政收入與投資者利潤成長。第24輪授予的8個礦區吸引了21億美元的投資承諾，第25輪則專門開放了16個陸上區域用於傳統型技術開發。產品分成合約機制在油價高企時增加政府收益，在油價低迷時保護營運商利益，這對於利潤率低、盈利能力差的油田來說尤其具有吸引力。簡化的環境核准程序和標準化時間表的引入，使探勘啟動的平均延遲時間比2024年之前縮短了近40%。

成熟淺海油田產量下降

在1980年至2010年間鑽探的現有油田中，隨著儲存壓力的下降，產量每年下降8%至12%。雖然可以透過水力注水和改進壓縮設備來減緩產量下降速度，但即使維持穩定的供油量，也需要每年2億至3億立方英尺/天的成本效益高的替代生產方案。剩餘蘊藏量位於密度較高的區域，需要鑽探水平井或進行選擇性增產，但鑑於目前高昂的維護成本，這些都是資本密集措施。

細分市場分析

截至2025年，海上區塊將佔泰國上游油氣市場規模的89.10%，預計到2031年將以5.78%的複合年成長率成長。生產主要集中在湄公灣淺水區，泰國國家石油公司（PTTEP）正在透過油田間管道和共用天然氣處理設施整合Bongkot、Erawan和Althit區塊，從而降低單位營運成本（OPEX）。目前處於評估階段的深水油田可能會推動泰國上游油氣市場轉向海底完井系統和動態定位鑽機，這將增加資本支出（Capex）需求，但也能延長資產的使用壽命。

目前僅佔總產量10.90%的陸上採礦業正受惠於新的產品分成合約（PSC）財務架構。探勘集中在呵叻高原，該地區緻密的砂岩地層與鄰國的高產砂岩地層相似。雖然基礎設施落後於沿海中心，但模組化加工撬裝設備和卡車運輸的液化天然氣可以彌補早期商業化進程中的差距，直到管道連接得到改善。

預計到2025年，天然氣將佔供應量的77.85%。這主要得益於電力產業的基本負載需求以及與西班牙能源和天然氣公司（EGAT）達成的穩固協議。東海岸天然氣管道和加工廠的長期飽和，鞏固了天然氣作為其他液態燃料價格決定因素的地位。原油預計年複合成長率（CAGR）為5.66%，這主要歸功於深海油田的發現，這些油田原油採收率更高，以及現有油田的二次採油項目旨在提高總液體產量。一些前景良好的深海區域的高二氧化碳含量增加了經濟難度，但運作的碳捕集與封存（CCS）設施有望抵消這些不利因素，並吸引新的投資。

其他好處：

• 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 市場狀況

• 市場概覽
• 市場促進因素
  • 擴大埃拉旺/邦科特叢集的產能
  • 對第24屆和第25屆許可競標和產品分成協議（PSC）的審查
  • 液化天然氣價格的波動正在提振國內上游產業。
  • CCS/EGR試點計畫能夠利用地下蘊藏量。
  • 利用人工智慧技術對歷史地震資料進行重新處理
  • 用於包圍氣穴的模組化繫繩
• 市場限制因素
  • 成熟淺海油田產量下降
  • 與環境影響評估和當地居民進行了長時間的磋商
  • 新發現礦區二氧化碳含量高
  • 石油工程人才流向可再生能源領域
• 供應鏈分析
• 技術展望
• 監理情勢
• 原油產量和消費量預測
• 天然氣生產與消費預測
• 非傳統資源（緻密油、油砂、深海油田）資本投資預測
• 波特五力模型
• PESTLE分析

第5章 市場規模與成長預測

• 按部署位置
  • 陸上
  • 離岸
• 按資源類型
  • 原油
  • 天然氣
• 按井類型
  • 傳統的
  • 傳統型
• 按服務
  • 探勘
  • 開發和生產
  • 退休

第6章 競爭情勢

• 市場集中度
• 策略趨勢（併購、聯盟、購電協議）
• 市場佔有率分析（主要公司的市場排名和佔有率）
• 公司簡介
  • PTT Exploration & Production（PTTEP）
  • Chevron Thailand E&P
  • Valeura Energy
  • Mitsui Oil Exploration（MOECO）
  • Mubadala Energy Thailand
  • Palang Sophon Ltd.
  • KrisEnergy
  • TotalEnergies SE
  • Schlumberger（SLB）
  • Halliburton
  • Baker Hughes
  • Weatherford
  • Saipem
  • TechnipFMC
  • McDermott
  • KBR
  • Subsea 7
  • EMAS Energy Services（Thailand）
  • Bangchak Corp.（Upstream JV）
  • PT Pertamina（Thai JDA partner）

第7章 市場機會與未來展望

According to Mordor Intelligence, the Thailand oil and gas upstream market size was valued at USD 3.33 billion in 2025 and estimated to grow from USD 3.52 billion in 2026 to reach USD 4.62 billion by 2031, at a CAGR of 5.59% during the forecast period (2026-2031).

This report is Segmented by Location of Deployment (Onshore and Offshore), Resource Type (Crude Oil and Natural Gas), Well Type (Conventional and Unconventional), and Service (Exploration, Development and Production, and Decommissioning). The Market Sizes and Forecasts are Provided in Terms of Value (USD).

Thailand Oil And Gas Upstream Market Trends and Insights

Ramp-up of Erawan/Bongkot Gas Clusters

PTTEP closed its USD 2.8 billion acquisition of Chevron's domestic portfolio in 2024 and immediately began a drilling and facilities-upgrade campaign aimed at lifting combined output from Erawan and Bongkot to 800 MMSCFD by 2026. Integrated control has trimmed per-unit development costs an estimated 15-20% by sharing compression, processing, and logistics assets across neighboring blocks. Alignment with Thailand's Single Pool Gas Price policy secures predictable long-term margins, enabling enhanced recovery methods in deeper horizons that could stretch field life by up to 10 years. PTTEP's AI & Robotics Ventures unit deploys predictive-maintenance drones and edge-analytics sensors that have already reduced unplanned downtime across both complexes.

24th & 25th Licensing Rounds Plus PSC Overhaul

The 2024 regulatory reboot introduced production-sharing contracts beside legacy concessions, balancing state revenue capture with investor upside. Eight blocks awarded under the 24th round attracted USD 2.1 billion in committed spending, while the 25th round released 16 onshore areas tailored for unconventional techniques. The PSC construct raises government take during price peaks yet cushions operators during troughs, a feature that is especially attractive for tight-margin, marginal fields. Streamlined environmental approvals now include standardized timelines, reducing the average exploration start-up delay by almost 40% compared to the pre-2024 practice.

Declining Output from Mature Shallow-Water Fields

Legacy fields drilled between 1980 and 2010 are exhibiting annual decline rates of 8-12% as reservoir pressure drops. Although water-injection and compression upgrades can soften the descent, cost-effective replacement volumes of 200-300 MMCFD each year are still required merely to maintain a flat supply. Remaining reserves reside in tighter compartments, demanding horizontal wells and selective stimulation, both of which are capital-intensive under today's service-cost inflation.

Other drivers and restraints analyzed in the detailed report include:

1. LNG-Price Volatility Pushing Domestic Upstream
2. CCS/EGR Pilots Unlocking Stranded Reserves
3. Lengthy EIA & Community-Consultation Cycles

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

Segment Analysis

Offshore acreage accounted for 89.10% of Thailand's oil and gas upstream market size in 2025 and is expected to grow at a 5.78% CAGR through 2031. Production is anchored in shallow Gulf waters, where PTTEP integrates Bongkot, Erawan, and Arthit through cross-field pipelines and shared gas-processing trains, thereby driving down unit operating expenses (opex). Deeper plays now entering appraisal may tilt the Thailand oil and gas upstream market toward subsea completion systems and dynamic positioning rigs, lifting capex requirements yet lengthening asset life.

Onshore prospects, which account for just 10.90% of current output, benefit from the new PSC fiscal regime. Exploration focuses on the Khorat Plateau, where tight-sand formations mirror productive analogs in neighboring countries. While infrastructure lags coastal hubs, modular processing skids and trucked LNG could bridge early commercialization gaps until pipeline connectivity improves.

Natural gas supplied 77.85% of 2025 volumes thanks to power-sector baseload demand and firm offtake contracts with EGAT. The long-term saturation of gas pipelines and processing plants across the Eastern Seaboard solidifies gas as the price setter for competing liquid barrels. Crude's 5.66% CAGR outlook stems from deeper-water finds holding higher oil cuts and from brownfield secondary-recovery programs aimed at lifting aggregate liquids yield. High CO2 ratios in some deep prospects complicate economics, yet upcoming CCS facilities could neutralize these penalties and attract new capital.

Complete Report Scope:

• By Location of Deployment
  • Onshore
  • Offshore
• By Resource Type
  • Crude Oil
  • Natural Gas
• By Well Type
  • Conventional
  • Unconventional
• By Service
  • Exploration
  • Development and Production
  • Decommissioning

List of Companies Covered in this Report:

1. PTT Exploration & Production (PTTEP)
2. Chevron Thailand E&P
3. Valeura Energy
4. Mitsui Oil Exploration (MOECO)
5. Mubadala Energy Thailand
6. Palang Sophon Ltd.
7. KrisEnergy
8. TotalEnergies SE
9. Schlumberger (SLB)
10. Halliburton
11. Baker Hughes
12. Weatherford
13. Saipem
14. TechnipFMC
15. McDermott
16. KBR
17. Subsea 7
18. EMAS Energy Services (Thailand)
19. Bangchak Corp. (Upstream JV)
20. PT Pertamina (Thai JDA partner)

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 Ramp-up of Erawan/Bongkot gas clusters
  • 4.2.2 24th & 25th Licensing Rounds plus PSC overhaul
  • 4.2.3 LNG-price volatility pushing domestic upstream
  • 4.2.4 CCS / EGR pilots unlocking stranded reserves
  • 4.2.5 AI-augmented re-processing of legacy seismic
  • 4.2.6 Modular tie-back of marginal gas pockets
• 4.3 Market Restraints
  • 4.3.1 Declining output from mature shallow-water fields
  • 4.3.2 Lengthy EIA & community-consultation cycles
  • 4.3.3 High-CO2 content in new discoveries
  • 4.3.4 Petroleum-engineering talent flight to renewables
• 4.4 Supply-Chain Analysis
• 4.5 Technological Outlook
• 4.6 Regulatory Landscape
• 4.7 Crude-Oil Production & Consumption Outlook
• 4.8 Natural-Gas Production & Consumption Outlook
• 4.9 Unconventional Resources CAPEX Outlook (tight oil, oil sands, deep-water)
• 4.10 Porter's Five Forces
  • 4.10.1 Threat of New Entrants
  • 4.10.2 Bargaining Power of Suppliers
  • 4.10.3 Bargaining Power of Buyers
  • 4.10.4 Threat of Substitutes
  • 4.10.5 Competitive Rivalry
• 4.11 PESTLE Analysis

5 Market Size & Growth Forecasts

• 5.1 By Location of Deployment
  • 5.1.1 Onshore
  • 5.1.2 Offshore
• 5.2 By Resource Type
  • 5.2.1 Crude Oil
  • 5.2.2 Natural Gas
• 5.3 By Well Type
  • 5.3.1 Conventional
  • 5.3.2 Unconventional
• 5.4 By Service
  • 5.4.1 Exploration
  • 5.4.2 Development and Production
  • 5.4.3 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 PTT Exploration & Production (PTTEP)
  • 6.4.2 Chevron Thailand E&P
  • 6.4.3 Valeura Energy
  • 6.4.4 Mitsui Oil Exploration (MOECO)
  • 6.4.5 Mubadala Energy Thailand
  • 6.4.6 Palang Sophon Ltd.
  • 6.4.7 KrisEnergy
  • 6.4.8 TotalEnergies SE
  • 6.4.9 Schlumberger (SLB)
  • 6.4.10 Halliburton
  • 6.4.11 Baker Hughes
  • 6.4.12 Weatherford
  • 6.4.13 Saipem
  • 6.4.14 TechnipFMC
  • 6.4.15 McDermott
  • 6.4.16 KBR
  • 6.4.17 Subsea 7
  • 6.4.18 EMAS Energy Services (Thailand)
  • 6.4.19 Bangchak Corp. (Upstream JV)
  • 6.4.20 PT Pertamina (Thai JDA partner)

7 Market Opportunities & Future Outlook

• 7.1 White-space & Unmet-need Assessment