The EPC Constraint: How Execution Capacity Is Reshaping Global Energy Investment

EXECUTIVE SUMMARY

The global energy industry is experiencing its most expansive capital deployment cycle in decades. According to the International Energy Agency's World Energy Investment 2026 report, global energy capital expenditure is expected to reach $3.4 trillion in 2026, a 5% increase on the $3.2 trillion recorded in 2025, itself a post-pandemic high. The IEA now describes 2025 as a record year for LNG project Final Investment Decisions, with more than 100 billion cubic metres (bcm) of new liquefaction capacity approved, over 90% of it in the United States alone.

Projects are being sanctioned. Financing is flowing. Regulatory approvals, once the perennial bottleneck, are clearing. The key question is no longer whether the industry can finance projects, but whether it can build them.

This blog examines why execution scarcity is replacing capital scarcity as the defining challenge of the decade, and what that means for energy developers, investors, and policymakers.

While the phenomenon is most visible in LNG, similar pressures are increasingly evident across petrochemicals, power infrastructure, carbon capture and industrial decarbonisation projects.

SECTION 1: THREE INVESTMENT CYCLES CONVERGING SIMULTANEOUSLY

To understand the EPC constraint, one must first appreciate the scale and timing of what is being built, and crucially, the fact that three distinct investment waves are cresting at the same moment.

Wave 1: LNG Infrastructure - A Once-in-a-Generation Buildout

The IEA's Gas 2025 report describes what is happening in LNG as unprecedented: approximately 300 bcm per year of new LNG export capacity is expected to be added globally by 2030, a record, driven primarily by the United States and Qatar. The agency's Global LNG Capacity Tracker (updated May 2026) notes that annual liquefaction capacity additions are expected to rise from around 35 bcm/year in 2025 to a peak of approximately 95 bcm/year in 2028 before gradually tapering. The 2026–2028 window is likely to see some of the largest-ever annual expansions in LNG capacity in the industry's history.

In the United States alone, projects under construction represent 130 bcm of annual export capacity - enough to nearly double America's existing export footprint. Between 2019 and mid-2025, the IEA tracked more than 420 bcm/year of LNG export capacity reaching FID globally - averaging over 55 bcm/year annually, more than double the rate seen during the 2014–2018 period.

Many of these are already in execution, consuming fabrication capacity, specialised equipment orders, and engineering hours on a scale the industry has rarely seen simultaneously.

Wave 2: Middle Eastern National Expansion

Qatar is executing one of the most capital-intensive infrastructure programmes in modern energy history. QatarEnergy's North Field expansion will raise the country's LNG production capacity from 77 Mtpa to 142 Mtpa - nearly doubling output from a single complex. The North Field East project, sanctioned at $28.75 billion, adds four liquefaction trains. The North Field West project, awarded in February 2026 to a joint venture of Technip Energies, Consolidated Contractors Company, and Gulf Asia Contractor, adds two more at an estimated budget of $17 billion. All of this is happening concurrently.

The consequence for the supply chain is already visible and has a single dominant focal point. Baker Hughes holds approximately 90% market share in the turbomachinery used for LNG liquefaction. Its Industrial & Energy Technology division, which manufactures the gas turbines and refrigerant compressors central to every LNG train, ended 2025 with a record backlog of $32.4 billion, rising further to $33.1 billion by Q1 2026 with a book-to-bill ratio of 1.5x. The company is simultaneously supplying critical equipment for Corpus Christi Trains 8 & 9, Rio Grande LNG Trains 4 & 5, Port Arthur Phase 2, Commonwealth LNG, and North Field West - all in overlapping execution windows. When the world's largest LNG equipment cycle is being processed through a single supplier's order book at record depth, delivery sequencing ceases to be a logistical detail and becomes a strategic constraint for the entire industry.

Wave 3: The Energy Transition - Additive, Not Substitutive

A widespread assumption held that the energy transition would reduce aggregate EPC demand as simpler renewable installations displaced complex hydrocarbon facilities. That assumption has not held. The IEA's World Energy Investment 2026 report notes that global clean energy investment is growing to $2.2 trillion in 2026 - almost double that of fossil fuels - with clean energy investment in advanced economies and China growing at 7% year-on-year. Permitting and supply chain constraints for key components such as transformers and cables are already raising execution flags. Meanwhile, CCUS investment is projected to rise more than tenfold by 2027 from then-current levels.

SECTION 2: WHAT BACKLOG DATA IS TELLING US

Order backlog data from some prominent contracting companies offers a reliable read on the forward demand picture for execution capacity - and the current data is sending a clear signal.

Technip Energies: A Barometer of the Cycle

Technip Energies' FY 2025 results (released February 2026) reported full-year adjusted revenue of €7.186 billion, a 10% year-on-year increase, driven by growth in LNG, decarbonisation, and offshore project activity. The company entered 2026 with an adjusted backlog of €15.95 billion - 2.2x its annual revenue - and net cash of approximately €1 billion. Management guided that the backlog is expected to grow to approximately €24 billion by H1 2026 following recent major awards.

The commercial pipeline underpinning that expectation reflects the breadth of concurrent demand cycles. Q3 2025 saw the award of a major (above €1 billion) contract for the Commonwealth LNG export facility in the United States and preliminary activities on the Coral Norte FLNG unit in Mozambique. Q4 2025 included a large authorisation from Commonwealth LNG for key equipment purchase orders, a detailed engineering contract for PTTEP's Carbon Capture and Storage facilities in the Gulf of Thailand, and marine loading arm supply contracts for Norway's Northern Lights CO₂ transport and storage project. In February 2026, the North Field West EPC contract was added.

The CEO of Technip Energies stated in February 2026 that the company expects to achieve its highest-ever annual order intake in 2026, with a commercial pipeline described as 'rich' and a long-term market outlook termed 'compelling.' It is a forward-looking statement grounded in a contracted backlog that already extends more than two years.

Saipem: Scale and Recovery Confirmed

Saipem's FY 2025 results, published in February 2026, showed revenue of €15.5 billion - growth of 6.5% year-on-year - and EBITDA of €1.7 billion, an increase of 29.1%. Free cash flow after lease liabilities reached €792 million, up 56.8% year-on-year. Order intake for the full year amounted to €13 billion, with strong acceleration in Q4 2025, maintaining the company backlog above €31 billion.

The merger with Subsea 7 to form Saipem7 - combining revenues of approximately €21 billion and a backlog of €43 billion - will create an offshore EPC entity of a scale rarely seen in the industry's history. The transaction is expected to close in H2 2026.

Yet the very scale of these backlogs introduces its own category of risk - one that the industry has encountered before, and that current conditions make particularly acute. When order intake significantly outpaces a contractor's ability to resource and staff new awards, the consequences tend to surface not at contract signing but deep into execution: schedule overruns, cost escalation, margin erosion, and in the most severe cases, project disputes and write-downs. Saipem itself experienced precisely this dynamic in the early 2020s, when a portfolio of legacy contracts - many awarded during the previous boom at compressed margins - produced a prolonged period of financial distress that required significant balance sheet restructuring. The company's recovery since then has been disciplined, marked by selective bidding and a deliberate focus on margin quality over volume. Its current guidance explicitly references a "selective approach on order intake" as a driver of profitability improvement.

The risk in the present cycle is that competitive pressure, developer urgency, and the sheer volume of work being sanctioned simultaneously creates conditions where that discipline erodes. Contractors awarded more work than their engineering bandwidth can absorb - particularly in specialist domains where experienced project managers and lead engineers are genuinely scarce - face the prospect of diluting execution quality across a stretched portfolio. For developers, this is a genuine concern: a contractor with a €30+ billion backlog and insufficient senior talent to staff it presents schedule and cost risks that no contract structure fully transfers away.

The concentration of global LNG and offshore EPC capacity among a small number of firms means that a delivery failure at one major contractor reverberates across multiple projects and geographies simultaneously. Hence, backlog is a leading indicator of both future revenue and future execution stress, and the two are not always distinguishable at the point of award.

SECTION 3: EXECUTION SCARCITY IS ALREADY AFFECTING COSTS

From a skewed demand-supply equation, the consequences of constrained EPC appear first, and most visibly, in project economics.

LNG construction costs today are materially higher than in the previous US buildout cycle. The first wave of US Gulf Coast liquefaction projects - Sabine Pass, Cove Point, Corpus Christi - achieved unit construction costs of approximately $500–600 per tonne of nameplate capacity, a benchmark that made American LNG structurally competitive. That benchmark no longer holds. Woodside's Louisiana LNG project, with Bechtel as EPC contractor, was estimated at $900–960 per tonne at the time of its late 2024 EPC contract signing - nearly double the earlier cycle low. Venture Global's CP2 LNG project, meanwhile, saw total project costs revised upward to a range of $32.5–33.5 billion by March 2026, up from prior estimates of $28–29.5 billion - an increase of roughly 15% before construction has fully ramped. The driver, in each case, is not commodity prices or financing costs alone. EPC cost escalations show no sign of abating, with higher raw material prices - further amplified by tariffs - coupled with rising labour and financing costs having a pronounced impact on US LNG project implementation, to the point where developers are struggling to keep EPC contracts valid as they move toward FID.

Labour is the most structurally entrenched component of that inflation. Approximately 439,000 additional construction workers were needed in the United States in 2025, with nearly 500,000 required in 2026 to meet projected demand - and approximately 94% of contractors report difficulty filling open positions. That shortage does not resolve through higher wages alone; it generates schedule risk, selective bidding by contractors, and a sustained upward pressure on labour rates that embeds itself into every project budget.

The IHS Pipeline and LNG construction cost index increased 36% between 2020 and 2025 - a structural re-rating of the cost of building energy infrastructure, not a temporary spike. On the equipment side, Baker Hughes - which holds approximately 90% market share in LNG turbomachinery - reported record IET orders of $4.9 billion and a record backlog of $33.1 billion in Q1 2026, with a book-to-bill of 1.5x, meaning new orders are arriving materially faster than existing ones are being delivered. The implications for delivery sequencing - and therefore project schedules - are direct. Developers are responding by accepting higher liquefaction fees: US liquefaction tolls are now being negotiated at up to 15% above prior cycle levels, with buyers in Europe and Asia willing to absorb the premium to secure supply certainty. That premium is, in significant part, a cost-of-construction premium being passed through the value chain.

The first manifestation of EPC scarcity is not project cancellation. It is cost inflation.

Project cancellation is the terminal outcome - what happens when cost inflation reaches a level that breaks project economics entirely, or when execution resources are so committed that a developer cannot secure an EPC contract on acceptable terms.

That point has not been reached for most current projects. But the indications are visible: unit costs rising, labour rates escalating, equipment queues extending, and contract values being revised upward between FEED and FID with increasing regularity.

For developers and their financing partners, the question is no longer simply whether a project is technically and commercially viable at sanction. It is whether the EPC cost envelope assumed at sanction will hold through execution - and in the current environment, the answer to that question is becoming harder to provide with confidence.

SECTION 4: THE HUMAN CAPITAL CONSTRAINT

Behind the project awards and balance sheet recoveries lies a more fundamental and harder-to-resolve constraint: the engineering and construction workforce itself.

The IEA's World Energy Employment 2025 report, the agency's most comprehensive global workforce analysis, documents the problem with unusual clarity. The energy workforce is ageing faster than the economy-wide average, and too few qualified workers are entering the sector to replace retirees and meet rising demand.

In advanced economies, 2.4 energy workers are approaching retirement for every new worker under 25 entering the sector, compared with a ratio of approximately 1:1 in emerging market and developing economies. In specific critical disciplines, the ratios are worse: in nuclear and grid-related professions, entry-to-retirement ratios of 1:1.7 and 1:1.4 respectively have been recorded.

The IEA's projections are sobering - between today and 2035, two out of every three new hires in the energy sector may be needed simply to replace retiring workers, before any growth in project activity is factored in.

The Global Energy Talent Index (GETI) 2026, published by Airswift, reinforces the picture from the demand side. Professionals aged over 45 now comprise 48% of the energy workforce, while the share aged 25 to 34 has declined to 19%. Only one-third of hiring managers are actively recruiting graduates to build a younger pipeline. Willingness to relocate for work, a critical variable in an industry where projects are geographically dispersed, has fallen from 89% in 2022 to 75% in 2026.

For EPC contractors, this demographic pressure interacts with a second structural problem: the complexity of the projects being delivered is increasing at the same time that experienced capacity is contracting. A modern LNG facility incorporates advanced automation, digital operations infrastructure, integrated carbon capture systems, and increasingly demanding environmental standards. Carbon capture projects require specialised process engineering expertise that barely existed commercially a decade ago. These are not skills that can be acquired through accelerated training programmes.

The IOGP (International Association of Oil and Gas Producers) has stated that the developing talent and skills gap, partly a result of significant layoffs during the 2015–2020 downturn, represents a greater impediment to the industry's forward delivery than any capital, equipment, or supply shortage. That assessment carries even greater weight today.

SECTION 5: THE SPECIALISATION PREMIUM

One of the most consequential structural shifts in the current EPC cycle is the growing premium commanded by contractors with deep, demonstrable expertise in specific technology domains, and the corresponding erosion of value for generalist execution capability.

Developers of large-scale LNG facilities, complex offshore developments, or first-of-kind carbon capture projects cannot afford to conduct engineering experiments at billion-dollar scale. They require contractors who have delivered comparable facilities before, who own not just a workforce, but proven process knowledge, established supplier relationships, proprietary technology licences, and institutional project memory.

Consider the pattern visible in Technip Energies' contract awards across 2025 and 2026: a major LNG award in the United States (Commonwealth LNG), a major LNG award in Qatar (North Field West), preliminary FLNG work in Mozambique (Coral Norte), CCS engineering in Thailand (PTTEP Arthit), the world's largest low-carbon ammonia facility in the United States (Blue Point Number One ATR), and FEED work for INPEX's Abadi LNG project in Indonesia. This is clearly an issue of a company whose specialisation in LNG process technology and decarbonisation engineering is generating repeated preferential access across geographies and project types simultaneously.

For Saipem, the equivalent positioning is in offshore execution. Its deepwater construction fleet, subsea engineering capability, and track record in complex offshore environments represent barriers to entry that have taken decades to accumulate.

Larsen & Toubro Energy Hydrocarbon's award of the $4–5 billion combined NFPS Package 4A/4B contract from QatarEnergy demonstrates the same dynamic from an emerging-market perspective. L&T's sustained investment in technical capability and international project experience has positioned it as a credible Tier-1 contractor for the world's most capital-intensive projects.

SECTION 6: GEOPOLITICAL INSTABILITY AS A STRUCTURAL DEMAND DRIVER

The conflict in the Middle East and its consequences for the Strait of Hormuz have generated sustained volatility in oil and LNG markets in 2026. The IEA's World Energy Investment 2026 report specifically notes that nations are now prioritising domestic spending to insulate themselves from what it describes as 'the world's second major energy shock in five years,' and that the conflict's effects are shaping future investment priorities across the sector.

The instinct is to treat geopolitical disruption as a risk to the EPC industry, a potential disruptor of supply chains, workforce availability, and project timelines. That framing misses the more consequential medium-term dynamic.

Every major energy supply shock of the past decade has produced a physical infrastructure response. The IEA notes in its 2026 investment report that energy companies and governments are investing in 'building alternative routes to market, strengthening supply chains, allowing for greater redundancy and lower utilisation rates for back-up infrastructure' - all as a direct response to supply security concerns. Every storage facility, alternative pipeline, import terminal, and back-up generation unit requires engineering design, material procurement, and physical construction.

SECTION 7: STRATEGIC IMPLICATIONS

The emerging execution constraint carries material implications across the energy value chain that warrant direct attention from project developers, capital allocators, and policymakers.

For Project Developers and Operators

The traditional procurement dynamic - competitive tender, late-stage EPC engagement, price compression through bidder competition - is becoming less viable in an environment where leading contractors are working from multi-year backlogs and have the leverage to be selective. Developers who secure preferred access to proven execution capability - through early contractor involvement, framework agreements, or long-term partnerships - are gaining a structural advantage over those who rely on spot procurement.

For Financial Investors

EPC contractors present a differentiated risk-return profile within the broader energy capital cycle. Unlike commodity producers, whose revenues are exposed to price volatility, EPC contractors generate revenue from the act of building - revenues that are contracted, backlog-supported, and largely insulated from short-term commodity price movements. The consolidation now underway - most visibly in the Saipem-Subsea7 merger - reflects an industry rationalising around scale, specialisation, and execution depth.

For Governments and Policymakers

The execution constraint has direct implications for the deliverability of energy security commitments. A project sanctioned today may face delays not because of financing, permitting, or market demand, but because the engineering and construction resources required to execute it are already committed elsewhere. The IEA's World Energy Employment 2025 report frames this as a strategic priority: 'Building a pipeline of skilled workers is a strategic priority for energy security.' Workforce policy, engineering education, and technical training infrastructure may need to be considered as components of energy strategy - not ancillary concerns.

CONCLUSION: THE NEW SCARCE RESOURCE

For most of the past century, strategic power in the energy industry resided with those who controlled the resource. Operators, national oil companies, and reserve holders set the pace of development. EPC contractors were service providers - essential, but ultimately interchangeable at the margin.

In a world where global energy investment is approaching $3.4 trillion annually, where three simultaneous investment supercycles are drawing on the same finite pool of execution resources, where the IEA tracks 300 bcm/year of new LNG capacity coming to market before 2030, and where its own employment analysis projects that two-thirds of new energy hires through 2035 will be needed simply to replace retiring workers - the ability to execute is becoming as strategically consequential as the ability to own.

A developer may command world-class reserves, committed capital, and regulatory clearance. Without access to a proven EPC contractor with available engineering bandwidth - and the compressor slots, fabrication yard capacity, and specialised workforce to match - the project does not advance on schedule, if it advances at all.

For those building, financing, or governing the global energy system, the execution imperative is a central consideration.

Primary Sources

-  IEA - World Energy Investment 2026 (May 2026)

-  IEA - World Energy Investment 2025

-  IEA - Gas 2025: Medium-Term Gas and LNG Market Report

-  IEA - Global LNG Capacity Tracker (updated May 2026)

-  IEA - World Energy Employment 2025 (December 2025)

-  Technip Energies - FY 2025 Financial Results, press release (February 26, 2026)

-  Technip Energies - 9M 2025 Financial Results (October 2025)

-  Saipem - FY 2025 Preliminary Results, press release (February 24, 2026)

-  Saipem - H1 2025 Interim Consolidated Financial Report

-  QatarEnergy - North Field West EPC Contract Award announcement (February 25, 2026)

-  IOGP - Workforce Energy analysis

-  Global Energy Talent Index (GETI) 2026 - Airswift