From installation race to system race: 2026 renewable energy outlook and the competitive proposition for UK industry

After renewable energy surpassed coal for the first time in early 2025 to become the world's largest source of electricity, the focus of industry competition is no longer the speed of new installed capacity, but whether the system can absorb this electricity, whether capital can obtain predictable returns, and whether domestic industrial chains can secure a position in this round of restructuring.

In Financier Worldwide's January 2026 energy and utilities roundtable, the judgments offered from legal and transactional perspectives by Milbank's Seyda Duman, Quinn Emanuel Urquhart & Sullivan UK LLP's Adam McWilliams, and Slaughter and May's Oly Moir happen to constitute an observational framework that UK industrial policy researchers can use.

I. The Climate Narrative Recedes, the Security Narrative Rises

McWilliams offered a judgment with considerable policy implications: the global renewable energy landscape is shifting from "climate first" to "security-driven economics." Beyond long-term 2050 targets, China, Europe, and the United States are increasingly placing supply chain resilience and industrial competitiveness on an equal footing.

The backdrop is highly concentrated manufacturing and processing capacity—China accounts for more than 80% of global solar manufacturing, about 75% of battery manufacturing, and 95% to 97% of rare earth processing. McWilliams noted that this structural dependence is increasingly something other economies' policies seek to "untangle." For the UK, this means the energy transition is no longer an issue for environmental departments but a core agenda for industrial departments: solar modules, battery cells, and critical minerals processing capacity constitute an industrial capability issue on par with aerospace and defense.

One judgment that recurred throughout the same discussion is that reframing decarbonization as "energy security" is politically more durable than a purely climate-based argument. McWilliams argued that the EU Green Deal's positioning of wind power as both a climate solution and a strategic industry is precisely an embodiment of this logic—European wind power currently supports about 300,000 jobs and is expected to become Europe's largest power source by 2027.

II. The Demand Side Changes First: AI and Electrification Rewrite the Load Curve

Moir noted that global electricity demand is now growing faster than overall energy demand, driven by AI applications, electric transport, and cooling systems, while new capacity is almost entirely supplied by renewable energy.

McWilliams added a more striking order-of-magnitude reference: according to industry forecasts, data center electricity consumption could exceed Japan's total electricity consumption by 2030; at the same time, grid bottlenecks have already delayed about 20% of new projects.For the UK's industrial system, the combined implication of these two pieces of information is that the feasibility of manufacturing electrification is increasingly tied to electricity prices and grid-connection queue times, rather than to total installed renewable energy capacity. When data centers, advanced manufacturing projects, and hydrogen facilities compete for interconnection capacity on the same grid queue, the spatial layout issue of industrial strategy becomes an issue of grid dispatch and investment sequencing.

III. The Real Bottleneck: Grid, Storage, and Flexibility

Moir lists grid constraints as a key bottleneck for renewable energy deployment: interconnection queues far exceed available capacity, requiring large-scale transmission upgrades. The third structural trend is flexibility—as the share of intermittent power sources rises, the system needs assets that can stabilize the grid: short- and long-duration storage (batteries, hydrogen, pumped hydro), nuclear power (including small modular reactors), dispatchable low-carbon power, and gas plants equipped with carbon capture and storage.

The fourth is the pricing of policy tools. Countries such as the UK use Contracts for Difference (CfD), capacity markets, and the "Regulated Asset Base" (RAB) model to lower the cost of capital and stabilize consumer prices. Moir specifically notes that long-duration energy storage (LDES) is gaining policy support: the UK uses a "cap-and-floor" mechanism, while Italy uses MACSE auctions to reduce debt risk and enhance project bankability.

Storage's own cost curve is also resetting industry expectations. McWilliams points out that in a single week in 2024, global battery demand exceeded the total annual demand from a decade earlier and reached 1TWh for the first time; China controls more than 75% of battery cell manufacturing, forming a cost advantage through vertical integration and scale. Lithium-ion batteries remain cheaper overall despite raw material volatility. In terms of technology pathways, the EU leads in liquid air energy storage, pumped hydro provides 46GW of installed capacity in the EU, while sodium-ion, flow, and solid-state batteries are used to diversify risk. At the policy level, the US Inflation Reduction Act, the EU Battery Regulation, and the UK Energy Act provide some certainty regarding recycling requirements and manufacturing incentives.

Duman adds from the operational side: storage operators have begun using AI to analyze weather patterns, historical data, and market prices, with forecast accuracy about 25% higher than traditional methods, so they can more accurately charge during low electricity price periods and discharge during peaks, amplifying arbitrage opportunities.

The key takeaway here is that storage is moving from a niche role in ancillary services to a core component of system infrastructure. For the UK, bankable storage assets, revenue mechanisms for long-duration storage, and grid equipment manufacturing capacity form an industrial belt that both serves energy security and has export potential.

IV. Policy Credibility Is the Cost of CapitalMoir's judgment is quite direct: investors want certainty, stable policy, and transparency, and political risks such as elections often deter investment. Uncertainty surrounding the Inflation Reduction Act has already shaken investor confidence in the United States and delayed capital inflows. By contrast, Europe and the UK have built credibility through CfDs, capacity markets, and RAB models for CO2 transport and storage and new nuclear—mechanisms designed precisely to reduce financing costs through predictable cash flows. The UK's Clean Power 2030 and targeted support for long-duration energy storage are seen as reinforcing long-term commitments.

The U.S. data McWilliams presented illustrate the scale of the policy: the IRA is expected to mobilize more than $1 trillion in investment by 2032, new solar PV installations are about 40% to 50% higher than expected before the IRA was enacted, and roughly three-quarters of clean energy investment flows into counties with below-median incomes. This pattern reverses long-standing regional investment imbalances, and its timing coincides with the COP30 “Baku to Belém Roadmap” setting a target of $1.3 trillion in annual climate finance by 2035.

But Duman raised a necessary caveat: investors have become more cautious about policy frameworks, because policies may be withdrawn due to changes in government or shifts in political winds, and may also cause malinvestment within industries.

This point has real tension in the UK today. The same discussion clearly noted that the UK government has published a consultation document on adjusting or suspending the inflation escalator index in renewable energy credits; and the U.S. federal government's opposition to offshore wind projects likewise constitutes a pressure signal. The UK's most important institutional asset over the long term is precisely what Moir emphasized: “stability, simplicity, and credible delivery.” Any fine-tuning of mechanisms driven by short-term bill pressure must be premised on not harming long-term capital costs; otherwise, the subsidies saved may be offset by higher financing costs.

V. Green Hydrogen: From Technological Optimism to Coordination Dilemma

Moir's assessment of green hydrogen is relatively restrained: green hydrogen has entered an early deployment phase, and its near-term role is concentrated in hard-to-electrify sectors—industrial heating, refining, chemicals, and sustainable aviation fuel—but only if costs fall. More importantly, the green hydrogen boom of a few years ago has cooled; many projects have been postponed or canceled, including some that received generous government subsidies, and some players have exited the market outright.

Beyond economics, two key challenges are the lack of an offtake market and the lack of large-scale transport and storage infrastructure. In other words, the market lacks a group of large, creditworthy buyers willing to sign long-term contracts and assume material potential liabilities.For industrial cluster-based decarbonization pathways, this means that the core obstacle for green hydrogen is not electrolyzer technology, but demand-side bankability design: long-term offtake agreements, investment recovery mechanisms for shared infrastructure, and contractual structures that allocate risk at the project level are the variables that determine whether green hydrogen can move from demonstration to scale.

VI. Three Judgments

First, energy policy and industrial policy have merged into a single policy domain. When PV, batteries, and rare earth processing are highly concentrated, decarbonization is a supply chain issue; and a supply chain issue is an industrial policy issue.

Second, the metric for competitiveness is shifting from “cost of generation” to “system cost + cost of capital.” Whoever can more quickly resolve grid connection queues, establish revenue mechanisms for long-duration energy storage earlier, and more effectively lower financing costs will be able to convert the physical advantages of renewable energy into industrial electricity price advantages.

Third, policy predictability itself is an industrial asset. The value of CfDs, capacity markets, RAB, and cap-and-floor mechanisms lies not in the scale of subsidies, but in the fact that they turn political commitments into priceable cash flows.

One sentence from McWilliams can serve as the most concise hint for the UK’s next five years: countries that can deepen domestic supply chains, secure critical minerals, and effectively manage social transition will gain outsized investment and deployment growth in the late 2020s.

Variables Worth Watching Continuously

• Whether grid connection reform and transmission investment can substantially shorten queue times in 2026–2027;
• The design details of the UK’s long-duration energy storage “cap-and-floor” mechanism and the financing performance of the first batch of projects;
• The policy direction of the Renewable Energy Credit inflation adjustment index and its impact on CfD financing costs;
• Whether long-term green hydrogen offtake contracts and shared transport and storage infrastructure can form a replicable business model;
• The capacity allocation between AI-driven electricity demand and industrial electrification on the same grid.