Power Engineering, Procurement, and Construction (EPC) - Market Share Analysis, Industry Trends & Statistics, Growth Forecasts (2026-2031)

The power engineering, procurement, and construction market size is expected to grow from USD 1.43 trillion in 2025 to USD 1.51 trillion in 2026 and is forecast to reach USD 2.12 trillion by 2031 at 6.97% CAGR over 2026-2031. This report is Segmented by Power Generation EPC [Technology (Thermal, Nuclear, and Renewables), Capacity Band (Up To 100 MW, 100 To 499 MW, and Above 500 MW), End-User (Regulated Utilities, Independent Power Producers, Industrial Captive Power, and Public Sector and SOE), and Geography], and Power Transmission and Distribution (T&D) EPC (Geography).

Global Power Engineering, Procurement, And Construction (EPC) Market Trends and Insights

Growing Power Demand in Emerging Economies

Electricity use in emerging markets is increasing at 5-7% annually, pushing utilities to accelerate EPC tenders for gas turbines and utility-scale solar assets that close supply gaps. India added 24 GW of renewables in 2024, yet industrial states still record peak shortages that channel USD 8 billion each year into captive EPC contracts. Sub-Saharan Africa’s electrification hit 54% in 2025, but grid-extension costs of USD 3,000 per rural connection steer donor programs toward mini-grid EPC packages bundling solar, storage, and prepaid metering. Local fabrication yards and vendor networks gain an advantage because transformer import duties can swell project costs by up to 20%. The contract model is shifting from turnkey lump-sum to EPCM frameworks that leave schedule risk with owners yet preserve contractor equipment margins.

Accelerated Renewable-Energy Build-Out

Global renewable additions hit 507 GW in 2024, but EPC execution trails equipment availability by 12-18 months due to land and grid connection delays. The 3.5 GW Terra Solar complex in the Philippines demonstrates scale changes; prefabricated racking slashes on-site installation to 14 months on a USD 3.5 billion contract. Offshore wind is spreading into the Atlantic seaboard, yet limited Jones Act vessels move first-turbine dates into late 2026, leaving a USD 12 billion backlog for marine EPC firms. Floating offshore wind below 1 GW today requires niche mooring know-how possessed by fewer than a dozen contractors. Tighter rules, such as the EU’s one-year window for environmental assessments, compel EPC bidders to front-load ecological studies, balancing risk and speed.

High Upfront Capex and Financing Risk

Utility-scale projects demand USD 1-4 billion in capital, yet emerging-market debt spreads hover 450-650 basis points over U.S. Treasuries, curbing bank appetite. Currency devaluation of 10% can shave 200-300 basis points off returns when equipment is dollar-denominated. Contractors increasingly structure build-own-operate-transfer deals that defer payment until COD, although balance-sheet exposure limits the number of parallel jobs. Inflation in steel, copper, and cement, up 12-18% between 2023 and 2025, triggers force-majeure claims on fixed-price contracts, steering owners toward cost-plus-fee models.

Other drivers and restraints analyzed in the detailed report include:

• National Net-Zero Mandates Unlocking EPC Pipelines
• Hyperscale Data-Center Micro-Grids
• Permitting Delays for Large Infrastructure

Segment Analysis

Renewables accounted for 60% of the Power generation EPC market share in generation spending during 2025 and are tracking a 7.8% CAGR to 2031. Utility-scale solar EPC costs have fallen to USD 850 per kW for fixed-tilt arrays, but bifacial modules and trackers add USD 100-150 per kW, compressing contractor margins to 6-8%. Offshore wind maintains gross margins above 12% as unit costs sit near USD 4,000 per kW due to marine logistics. Hybrid solar-storage projects already represent 18% of renewable awards, driven by grid operators mandating 2-4 hours of dispatchable capacity.

Second-order dynamics underpin this lead. Renewable debt lines price at 4-6% in OECD markets compared with 8-12% for coal and nuclear, and lenders prefer the shorter build cycles of solar and onshore wind. Contractors with digital-twin workflows cut commissioning errors by 20%, shortening time to revenue. Stranded-asset concerns degrade new-build coal awards, now just 8 GW, concentrated in a handful of emerging economies. Thermal repowering into gas or biomass offers a niche for brownfield specialists. Nuclear EPC firms bank on small modular reactors, yet first-mover risk and supply-chain depth remain constraints.

Complete Report Scope:

• Power Generation EPC
  • By Technology
    • Thermal
    • Nuclear
    • Renewables
  • By Capacity Band
    • Up to 100 MW (DER, micro-grid)
    • 100 to 499 MW
    • Above 500 MW
  • By End-User
    • Regulated Utilities
    • Independent Power Producers
    • Industrial Captive Power
    • Public Sector and SOE
  • By Geography
    • North America
    • Europe
    • Asia-Pacific
    • South America
    • Middle East and Africa
• Power Transmission and Distribution (T&D) EPC
  • By Geography
    • North America
    • Europe
    • Asia-Pacific
    • South America
    • Middle East and Africa

Geography Analysis

Asia-Pacific controlled 59.4% of the power generation EPC value in 2025, fueled by China’s 120 GW annual renewable build and India’s 24 GW addition. China’s coal EPC slipped to 8 GW in 2024 as policy pivots to wind, solar, and nuclear for its 2060 neutrality pledge. India preserved 12 GW of thermal EPC for reliability, but now layers 60% domestic-content rules on solar projects above 500 MW.

South America is the fastest-growing region (power generation EPC) at a 7.5% CAGR through 2031, anchored in Brazil’s 15 GW of 2024 auction wins at sub-USD 30 per MWh rates and Chile’s 25 GW hydrogen-linked pipeline. Argentina and Colombia add niche gas and offshore wind jobs, although currency controls and differing vessel laws adjust cost structures.

North America and Europe share bottlenecks. Interconnection queues defer 60 GW of shovel-ready assets into 2027-2028 and elevate the role of behind-the-meter builds. The Inflation Reduction Act’s domestic-content rules push Fluor and Bechtel to onshore transformers, adding 8-12 months to procurement but unlocking 30% tax credits. Europe’s next growth spurt rests on floating offshore wind platforms where EPC costs sit 40% above fixed-bottom solutions.

List of Companies Covered in this Report:

• Bechtel Corporation
• PowerChina
• Larsen & Toubro
• Fluor Corporation
• McDermott International
• Saipem SpA
• Kiewit Corporation
• John Wood Group PLC
• KBR Inc.
• Black & Veatch
• China Energy Engineering Corp
• ACS Group - Cobra
• Hitachi Energy
• Siemens Energy AG
• General Electric Vernova
• ABB Ltd
• Schneider Electric SE
• Eaton Corporation
• Linxon
• AECOM
• Chiyoda Corporation
• Adani Infrastructure
• Tata Power Solar EPC
• Samsung C&T

Additional Benefits:

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