The transition to net zero is fundamentally a capital-allocation challenge underpinned by accelerating engineering realities
As Europe struggles to create a coherent strategy for transitioning towards a zero-carbon emission energy strategy, institutional investors need to abandon any attempts at ideological rigidity to take advantage of the opportunities but also beware of the pitfalls that lie ahead. That was a key conclusion in a wide-ranging discussion I had recently with Adair Turner, chair of the Energy Transitions Commission (ETC), which operates at the nexus of private sector capital, state policy and technological feasibility.
The ETC conducts comprehensive mappings across the heavy-emitting sectors of the global economy: power generation, building infrastructure, heavy industry and transport. The baseline objective remains clear: to transition developed economies to net zero by 2050 and developing nations by 2060. But even achieving these targets demands an acknowledgement of the changing reality that while climate frameworks historically anchored around a 1.5°C warming ceiling, contemporary empirical modelling suggests that a stabilisation “well below two degrees centigrade” represents the primary credible trajectory.
A fundamental premise of energy strategy is the concept of “base load”. For nearly a century, the architectural design of electricity grids relied on centralised, always-on nuclear or fossil-fuel assets running continuously to meet minimum demand thresholds.
Turner argues that fulfilling base load objectives is no longer required and that a paradigm shift occurred in 2015, noting that the then head of the UK National Grid explicitly stated that “we live in a world beyond base load”.
Modern electrical networks can operate securely with 70-80% intermittent renewables (wind and solar) without relying on traditional continuous base load assets, says Turner.
This stability is maintained via two primary mechanisms for short-term and for long-term energy storage.
First, battery technology has undergone an unprecedented deflationary curve. Storage battery costs have plummeted by roughly 60% within a three-year window, turning solar-plus-battery configurations into highly competitive options.
In tropical countries such as India, the balancing problem is fundamentally diurnal rather than seasonal – the primary challenge is keeping air conditioning and industrial systems running after sunset.
Turner emphasises that the physical capacity to scale battery storage is practically “limitless”, with the core constraint being economic duration rather than manufacturing feasibility. Batteries are very cost-effective for short-duration storage (ranging from two to 16 hours) to shift daytime solar abundance into evening demand peaks.
In terms of the second primary mechanism, in order to bridge longer-term seasonal wind droughts or prolonged weather anomalies, grids rely on highly flexible assets rather than rigid base load generation. A fleet of gas turbines, repurposed to burn hydrogen or clean gas, can provide backstop security, Turner argues.
These peaking plants operate on low-capacity factors, remaining offline for the vast majority of the year but spinning up rapidly during supply deficits. This structure ensures that no generation asset runs continuously; rather, a dynamic mix of localised renewables, short-term battery arbitrage, and flexible peaking capacity can secure the grid around the clock, Turner explains.
“We live in a world beyond base load”
Where should nuclear fit into energy strategy? The answer is highly dependent on the costs associated with building nuclear plants. The ETC maintains an open-minded but financially disciplined stance on nuclear power.
Turner asserts that, from an operational standpoint, maintaining existing nuclear generation assets for as long as safely possible is an absolute necessity. Conversely, decisions such as Germany’s abrupt nuclear shutdown represent counterproductive climate policies that delayed coal phase-outs by approximately a decade.
The economics of building new nuclear reactors, however, has to battle against severe headwinds. Turner argues that new nuclear builds are significantly more expensive than renewables, even when the costs of storage and grid flexibility are fully internalised.
For example, the contract for Hinckley Point C in the UK stands as a remarkably high-cost electricity supply agreement, particularly when compared directly with the deflationary curves of solar and wind on a per-kilowatt-hour basis. Given the rapidly increasing global electricity generation, the global nuclear sector would need to triple its total capacity over the next 30-40 years to maintain its current 9% share.
But the ETC analysis, Turner says, does find that keeping nuclear at around 15% of total generation can offer a distinct system-wide diversification benefit, subtly lowering the total system cost by reducing the absolute volume of seasonal storage and overgeneration capacity required.
The transition path to net zero does, of course, face the challenges of geopolitical instability most obviously with the war in Ukraine and the stand-off in the Strait of Hormuz. While there were fears that these would drive a structural resurgence in coal generation, empirical observations across European energy systems reveal that coal’s role has been strictly defensive and transitory.
During the winter of 2022–23, European governments ordered coal assets to be maintained in a state of operational readiness as an insurance policy. “Yet, due to structural demand destruction, elevated natural gas prices and favourable winter weather, almost none of them actually burned that coal,” says Turner. For example, the Drax facility in Yorkshire maintained massive standby coal reserves that ultimately went entirely unused, and Europe’s trajectory to phase out coal by the mid-2030s remains firmly intact.
Whilst the US may find it difficult to deviate from a rigid ideological anti-China stance, Europe has the luxury of being able to adapt to the reality of Beijing’s industrial hegemony across the clean technology value chain. China has secured dominant positions in the manufacturing of solar photovoltaic (PV) panels, lithium-ion battery cells, and electric vehicles, points out Turner.
He argues that faced with this asymmetry, European industrial policy must avoid monolithic protectionism and instead adopt a strategy of “intelligent sectoral differentiation”, governed by three core principles.
First, Europe must accurately distinguish between industries where domestic production is salvageable and those where it is economically unviable. In the solar PV panel sector, Europe possesses virtually zero manufacturing capacity, no distinct technological advantage, and minimal employment at risk.
It therefore makes sense for Europe to import highly deflated Chinese panels to rapidly decarbonise its power sector. Conversely, automotive manufacturing and battery cell production represent critical economic pillars with substantial employment at risk. “Here, regionalising battery gigafactories in close proximity to vehicle assembly lines is highly logical and economically defensible,” says Turner.
Second, when trade defences are deployed, they must be rigorously calibrated against verified, company-specific state subsidies in strict compliance with World Trade Organisation guidelines.
Third, Europe should actively welcome direct inward investment from leading Chinese clean technology firms. Establishing Chinese-owned manufacturing facilities within European borders drives localised employment, integrates advanced supply chain expertise and forces regional incumbents to innovate, echoing how Japanese and Indian capital previously revitalised the British automotive industry.
For institutional investors, it is worth bearing in mind, says Turner, that a critical insight of modern techno-economic analysis is that approximately 40% of the total capital investment required to build a zero-carbon power system must be deployed directly into grid infrastructure rather than generation assets.
The integration of high-penetration intermittent renewables demands massive capital expenditure in distribution networks, subsea interconnectors and advanced digital grid-management systems. The recent grid instability event in Spain serves as a classic cautionary tale.
The transition to net zero is fundamentally a capital-allocation challenge underpinned by accelerating engineering realities. Turner argues that an obsolete reliance on base load generation is rapidly giving way to an agile network architecture defined by ultra-low-cost intermittent renewables, highly distributed storage assets and sophisticated grid-management systems. Whether his views are correct remains to be seen – but they cannot be ignored.
Joseph Mariathasan is a contributing editor to IPE, a partner of Peak Sustainability Ventures and a director of GIST Impact
