After a decade of flat demand, power markets are being forced to absorb a very different problem: rapid load growth arriving faster than transmission, large-scale generation, and utility interconnection processes can respond. The focus shifts from utility-scale procurement to the distributed edge of the system, where commercial and industrial solar, community solar, batteries, and microgrids may prove to be some of the fastest tools available for adding capacity, managing costs, and improving resilience.

Host Sylvia Leyva Martinez is joined by Tim Montague, host of Clean Power Hour and a longtime C&I solar operator and advisor, to unpack what distinguishes distributed generation from utility-scale solar in practice. Tim explains why the differences are not just about megawatts, but about interconnection, contractor capability, state policy, and execution risk. He also lays out how the phase-down of the ITC and the July 4 Safe Harbor deadline sharpened those differences: sophisticated developers with capital and pipeline visibility bought themselves runway through 2029, while smaller players that missed the deadline now face a much tighter path to commercial operation.

The conversation then turns to the economics and mechanics of the market. Tim argues that state-level frameworks remain decisive for C&I and community solar, pointing to states such as Illinois, New York, New Jersey, Massachusetts, Maryland, Minnesota, Colorado, and New Mexico as the sector’s core proving grounds. From workforce rules and training pipelines to tax-credit capture and commercial lending, he describes a market that is far more fragmented than utility-scale power, but also more flexible. Financing can range from a local business borrowing through its existing commercial bank to larger developers using institutional capital to safe-harbor equipment and scale portfolios, while PPAs remain available but often introduce longer, more complex contracting cycles.

Crucially, the episode looks at why distributed energy is moving from a niche resilience play to a system-level answer for affordability and speed to power. Rising electricity prices, data-center demand, and long utility interconnection queues are improving the case for solar-plus-storage behind the meter and at community scale. Tim makes the case that batteries, community solar, distributed computing, and eventually community-scale microgrids can complement, not replace, utility-scale buildout by delivering capacity where it is needed faster and with more local value. The core question running through the episode is whether the next phase of the energy transition will be defined not only by bigger projects, but by a more distributed grid architecture built for flexibility, resilience, and cost control.

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Lots of agencies say they work with energy companies. twentytwo & brand was built for them. They've partnered with more than 120 companies driving the energy transition – from growth-stage startups to globally recognised industry leaders. Media relations, brand design, video, paid advertising and community engagement – they cover it all under one roof. No onboarding lag, no industry crash course – they speak your language on day one. If you're ready to sharpen your story and supercharge your marketing, find them here. 

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Electricity demand is rising, capital is tightening, and nuclear is back in the conversation as utilities, governments, and large power users look for firm low-carbon supply. But the central question is not whether advanced nuclear can attract interest. It is whether any new design can get far enough ahead on cost, manufacturability, and fuel strategy to break from the economics that have constrained conventional nuclear for decades.

Host Sylvia Leyva Martinez is joined by Thomas Jam Pedersen, co-founder and CEO of Copenhagen Atomics, to examine one of the more unconventional answers now being put forward: thorium molten salt reactors built around low-pressure operation, standardized manufacturing, and a fuel strategy that could use spent nuclear fuel alongside thorium. Their core argument is that most of the nuclear sector is still trying to improve on a legacy light-water model that may remain too expensive, too complex, and too slow to scale against the pace of future energy demand.

A large part of the discussion focuses on what that alternative looks like in practice. Pedersen argues that operating at atmospheric pressure changes the cost and engineering profile of the reactor itself, making smaller units easier to manufacture and potentially easier to deploy repeatedly. He also lays out why Copenhagen Atomics sees spent fuel not only as a waste problem but as a potential input, provided it can be recycled economically and paired with thorium to achieve higher fuel efficiency. The commercial model follows the same logic: standardize the reactor unit, let customers source the rest of the plant locally, and avoid the bespoke, first-of-a-kind economics that have burdened much of the sector.

The episode also looks ahead to the harder constraints that will determine whether that thesis holds. Licensing remains slow and expensive, investor appetite is still shaped by the long history of political and regulatory risk in nuclear, and even successful advanced designs are unlikely to make a meaningful dent in global electricity supply before 2035. The takeaway is that the real test for advanced nuclear is no longer just technical credibility. It is whether a new generation of reactor companies can prove they have found a model that lowers cost, reduces deployment risk, and makes nuclear scalable in a very different energy market.

This episode is brought to you by twentytwo & brand – a marketing and PR agency built specifically for energy leaders.

Lots of agencies say they work with energy companies. twentytwo & brand was built for them. They've partnered with more than 120 companies driving the energy transition – from growth-stage startups to globally recognised industry leaders. Media relations, brand design, video, paid advertising and community engagement – they cover it all under one roof. No onboarding lag, no industry crash course – they speak your language on day one. If you're ready to sharpen your story and supercharge your marketing, find them here. 

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Solar demand remains strong, storage is scaling fast, and inverter technology is becoming more central to how modern power systems actually function. But the conversation around inverters is no longer just about efficiency, bankability, or price. As these devices take on more intelligence — managing batteries, supporting grid stability, and communicating more directly with the wider system — they are also being treated as a new point of strategic vulnerability. In both Europe and the US, policymakers are starting to respond accordingly.

Host Sylvia Leyva Martinez is joined by Joe Shangraw, research analyst at Wood Mackenzie covering solar inverter markets, to examine what that shift means in practice. Their core argument is that inverter policy is moving beyond trade protection and into a more complicated mix of cybersecurity, industrial strategy, and grid risk. They unpack why Europe’s March decision to block public EU funding for projects using Chinese-made inverters matters beyond its immediate scope, and why the region’s dependence on Chinese vendors — especially in utility-scale string inverters and integrated battery-plus-inverter systems — makes any attempt to diversify more complex than simply switching suppliers.

 A large part of the discussion focuses on the FCC’s July decision to add foreign power inverters to its Covered List, where the real issue is not just whether the headlines overstated the impact, but how narrowly or broadly the rule will ultimately be applied. Shangraw explains that the current language appears closely tied to communications hardware, especially wireless-enabled devices, which creates a more nuanced picture than an outright market shutdown. That distinction matters because it affects not only which new products fall in scope, but how developers, manufacturers, and asset owners start thinking about software updates, grid-code compliance, and long-term procurement risk. The challenge is no longer just cost competitiveness. It is whether an inverter can remain usable, updateable, and policy-safe over the life of the asset.

The episode also looks ahead to the next set of decisions facing the industry: whether Europe expands restrictions beyond publicly funded projects, how quickly US and allied manufacturers can localise enough of the supply chain to qualify under tougher domestic-content rules, and where practical bottlenecks are most likely to emerge. The takeaway is that inverter policy is becoming a test case for a much bigger energy-transition problem: how to reduce genuine security risks without creating new deployment constraints. For developers, manufacturers, and policymakers alike, the inverter market is no longer just a technology contest. It is becoming a test of how the energy transition handles security, industrial policy, and system reliability all at once.

The report and note and Sylvia refers can be found here: 

Solar Solar Inverter Market Share Report 2026

Ban on inverters from high-risk countries, led by China, to affect 14% of EU solar demand through 2030

This episode is brought to you by twentytwo & brand – a marketing and PR agency built specifically for energy leaders.

Lots of agencies say they work with energy companies. twentytwo & brand was built for them. They've partnered with more than 120 companies driving the energy transition – from growth-stage startups to globally recognised industry leaders. Media relations, brand design, video, paid advertising and community engagement – they cover it all under one roof. No onboarding lag, no industry crash course – they speak your language on day one. If you're ready to sharpen your story and supercharge your marketing, find them here. 

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Copper is moving from background commodity to frontline constraint. Demand is rising fast, high-grade deposits are getting harder to find, and the lead times for bringing new supply online remain brutally long. That matters not just for renewables and electrification, but for the basic energy resilience of modern life: the wires that keep lights on, water running, refrigeration working, and data centres scaling all depend on a metal the industry already knows is becoming harder to source.

Host Sylvia Leyva Martinez is joined by Liz Dennett, founder and CEO of Endolith, whose career spans Wood Mackenzie, AWS, and NASA-linked astrobiology research, to explore a biological approach to one of mining’s toughest problems. Endolith uses microbial communities, what Dennett calls “the world’s oldest miners," to help recover more copper from low-grade ore in existing heap leach operations. The company’s core thesis is that copper supply can be made more elastic not by rebuilding mine sites from scratch, but by layering biology, sensing, and robust data architecture into brownfield operations that are already running.

 Liz explains how that works on site: low-grade ore is stacked into large heaps, irrigated with sulfuric acid, and treated with microbes that accelerate the chemical pathways needed to liberate more copper into solution. The appeal is not futuristic moonshot capex, but a modular, plug-and-play system designed to fit into existing mine infrastructure with minimal downtime. The discussion looks at why that matters economically. Endolith is targeting ore bodies and waste streams that are currently too messy, too low grade, or too contaminated to recover efficiently through conventional routes, including arsenic-rich material that can be especially problematic for smelting. In lab settings, the company has seen significantly higher recovery, and even modest incremental gains in the field could translate into a meaningful unlock when the underlying mine and processing system are already built.

The conversation also asks why biomining may be having its moment now, after decades of false starts. Liz argues that the breakthrough is not microbes alone, but the combination of microbial science, cloud-scale data systems, and faster experimentation that lets teams build and iterate far more effectively than even a few years ago. From there, the conversation broadens into the strategic question underneath Endolith’s business: how to increase copper supply in a world where demand is being pushed simultaneously by grid build-out, industrial electrification, and the explosive growth of AI infrastructure. The episode closes on the trade-offs that follow from that reality, from financing hard-tech mining solutions to building companies in sectors where the need is obvious, the customers are conservative, and proof matters more than hype.

This Horizons episode Liz refers to can be found here: 

https://www.woodmac.com/podcasts/horizons/red-metal-green-demand/

This episode is brought to you by twentytwo & brand – a marketing and PR agency built specifically for energy leaders.

Lots of agencies say they work with energy companies. twentytwo & brand was built for them. They've partnered with more than 120 companies driving the energy transition – from growth-stage startups to globally recognised industry leaders. Media relations, brand design, video, paid advertising and community engagement – they cover it all under one roof. No onboarding lag, no industry crash course – they speak your language on day one. If you're ready to sharpen your story and supercharge your marketing, find them here. 

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Wind remains fundamentally healthy: electricity demand is rising, decarbonised power is still needed, and both Europe and the US continue to pull new projects forward, albeit for different reasons. But the industry’s center of gravity is shifting. The conversation is no longer just about building faster or installing more megawatts. As turbines get larger, OEM competition broadens, and project economics tighten, the consequences of failure are becoming much harder to ignore.

Host Sylvia Leyva Martinez is joined by Alexis Grenon, CEO of Onyx Insight, and Olly Litterick of Tokio Marine GX to examine what that shift means in practice. Their core argument is that the wind sector is moving from a development-at-speed mindset toward operational efficiency, where every dollar of ROI matters and risk has to be quantified far more precisely. They unpack why insurers still struggle with newer turbine classes despite two decades of renewables underwriting: the machines are scaling faster than the loss history, the supply chain maturity is lagging  to price them confidently, and in wind, bigger hardware often means not more failures, but far costlier ones when they do occur.

A large part of the discussion focuses on blades, where exposure and difficult inspection regimes make early detection especially valuable. Grenon argues that the industry has relied too heavily on periodic inspection and not enough on continuous monitoring, contrasting the lack of standardised turbine monitoring with the smoke detector logic used elsewhere in insurance. The promise of better instrumentation, integrated SCADA and condition data, and physics-informed AI is not simply smarter dashboards. It is the ability to detect structural issues earlier, prevent minor damage from escalating into six-figure or seven-figure failures, and make better-informed decisions about maintenance, underwriting, and asset life.

The episode also looks ahead to the next set of decisions facing wind owners: how to handle aging fleets, when to extend life versus repower, and how much independent real-time data can change the balance of power between owners, OEMs, and insurers. The takeaway is that better data and earlier visibility can help the industry move from reactive maintenance and blunt underwriting toward a more preventative, risk-based model, one that should improve insurability, reduce downtime, and make the next phase of wind deployment more durable.

This episode is brought to you by twentytwo & brand -- a marketing and PR agency built specifically for energy leaders.

Lots of agencies say they work with energy companies, twentytwo & brand was built for them. They've partnered with more than 120 companies driving the energy transition — from growth-stage startups to globally recognized industry leaders. Media relations, brand design, video, paid advertising, and community engagement — they cover it all under one roof. No onboarding lag, no industry crash course -- they speak your language on day one.

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As AI systems scale, the infrastructure challenge is no longer just about chips, models, and software performance. It is increasingly about the physical systems that allow computation to happen at all: power delivery, cooling, water access, and the speed at which new capacity can be brought online. Power conversion is becoming a much more important design question. As racks move from conventional power densities toward megawatt-scale configurations, every inefficiency in the electrical pathway becomes more consequential. For stakeholders across the energy sector, that makes AI infrastructure more than just a datacenter story. It is also a story about grid constraints, industrial load growth, thermal management, and how developers can design facilities that are efficient enough, flexible enough, and resilient enough to operate at the scale AI now demands.

Host Sylvia Leyva Martinez is joined by Nick Wright, Vertical Solutions Manager at Siemens. Their conversation explores why the growth of the AI factory is pushing operators to rethink traditional electrical architecture, especially the number of conversion steps required to move power from the grid to the chip. Nick explains why conventional AC-heavy setups are under pressure as compute loads become denser, more dynamic, and more power-intensive, and why more direct AC-to-DC pathways are drawing increased attention. The episode also examines what that shift means in practice: less energy lost in conversion, less excess heat to manage, different implications for cooling design, and a growing role for higher-voltage DC systems, digital twins, monitoring technologies, and new protection equipment. Along the way, the discussion widens beyond the building itself to consider how AI facilities may evolve into more grid-aware assets, capable of interacting more intelligently with the broader energy system rather than functioning simply as passive loads.

For developers, IPPs, utilities, financiers, and infrastructure planners, the episode offers a clear signal that power architecture is becoming a strategic decision much earlier in the project lifecycle. One of the key takeaways is that this is not a simple story of DC replacing AC. The more relevant point is that as racks scale, reducing unnecessary conversion steps can improve efficiency and system performance in ways that matter economically at very large scale. But the conversation also makes clear that conversion efficiency is only one part of a much broader infrastructure equation. Access to reliable power, water availability, cooling strategy, workforce readiness, supply chain bottlenecks, equipment lead times, and safety considerations all shape whether a new AI facility can be delivered on time and scaled over the long term. The players most likely to succeed will be the ones that stop treating power as a late-stage procurement issue and instead plan holistically across energy, compute, operations, and grid interaction from the beginning.

This episode is brought to you by twentytwo & brand -- a marketing and PR agency built specifically for energy leaders.

Lots of agencies say they work with energy companies, twentytwo & brand was built for them. They've partnered with more than 120 companies driving the energy transition — from growth-stage startups to globally recognized industry leaders. Media relations, brand design, video, paid advertising, and community engagement — they cover it all under one roof. No onboarding lag, no industry crash course -- they speak your language on day one.

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A year ago the data centre conversation was about scale. Increasingly it is about what happens when the announcements meet the physical grid. New capacity is being announced at roughly 435 megawatts a month, enough to power a city of 400,000 people, but two-thirds of that committed load tends to disappear the moment utilities ask for a financial commitment behind it. AI training facilities create load profiles that drop 30% in five minutes, or 190 megawatts in three. The grid's mechanical inertia is retiring just as hyperscaler ambition accelerates, and regulation is lagging on both sides of the meter.

In this episode, interim host Bridget van Dorsten returns the microphone to host Sylvia Leyva Martinez. The two recap six months of the show through clips from Chris Seiple (Wood Mackenzie), Tom Falcone (Large Public Power Council), Akhil Batheja (Bloom Energy), Kay Aikin (Dynamic Grid), Kristina Carlquist and Christian Payerl (ABB), Shannon Miller (Mainspring Energy) and Nick Chaset (Octopus US), and map out the questions that will shape Sylvia's return.

The central tension of the past six months: announcements are racing ahead, but utilities, regulators and the physical grid cannot move at hyperscaler speed. A data centre can be built in two years. New generation takes five to ten. That mismatch is why developers have stopped waiting on the grid: 35% of US data centre project capacity announced in 2025 was planned with around-the-meter generation, and 92% of bridge prime power deals are now struck before the end tenant is signed, inverting the usual logic of infrastructure development. But collocated power is still, in Bridget's framing, a science project. The load behaviour demands a coordinated portfolio: supercapacitors and UPS catching millisecond swings, synchronous condensers supplying inertia, fuel cells and linear generators offering modular, fuel-flexible bridging power as a hedge against demand risk. Nick Chaset's intervention cuts the other way: the UK already hosts the world's largest residential virtual power plant, and the cheapest megawatt is the one you don't build. The episode closes on duelling forward views, Tom Falcone's cooperative optimism against Kay Aikin's affordability death spiral, with the question of who ultimately holds the bag if the announcements don't materialise still unresolved.

Sylvia sets out what she wants to explore next: the regulatory contradiction where utilities support bring-your-own-generation but cannot guarantee protection from curtailment; renewables supply constraints and the transformer and labour bottlenecks that affect every fuel source equally; the return of energy security as a framing now that "energy transition" has fallen out of political favour in the US; and the community opposition data centre developers are only beginning to grapple with.

Here is the latest Horizon's piece that Bridget referenced:

https://www.woodmac.com/horizons/can-us-data-centre-development-outpace-grid-development/

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The energy transition conversation focuses on what connects to the grid. Far less attention goes to whether anyone is coordinating what those assets do once connected. AI training runs swing hundreds of megawatts in seconds as GPUs checkpoint and restart a profile that looks like a generator tripping offline. At distribution level, millions of inverter-based resources create localised variability that overwhelms individual circuits even when aggregate models look healthy. The planning tools in use today were designed for neither problem.

Host Bridget van Dorsten is joined by Kay Aikin, CEO and Founder of Dynamic Grid, energy engineer, grid architecture advisor to the DOE-supported GridWise Architecture Council, and contributor to the UN Environmental Program's building decarbonisation work. Kay unpacks what an AI training facility actually does to the grid with full GPU load for hours or days, then a drop to ten percent in seconds during checkpointing. She talks about how at the scale now planned, the Stargate project in Texas alone could represent ten percent of ERCOT disappearing in four seconds. The behaviour is stochastic and cannot be modelled with traditional statistical tools. At distribution level, virtual power plants responding to wholesale signals without circuit-level visibility can create competing oscillations, the kind of emergent dynamics that contributed to the Spanish grid failure.

The proposed fix is an AI controller at the substation, sending price-based signals and flexible operating envelopes to large assets and VPP operators, giving them twenty-four-hour forecasts and real-time circuit visibility. Total cost: under a hundred thousand dollars installed. The reason it isn't everywhere is cost-of-service regulation. Utilities earn returns on deployed capital, so a million-dollar transformer replacement is more profitable than software that eliminates the need for it.

Without new approaches, rebuilding the US distribution grid could cost up to ten trillion dollars by 2040. Kay is developing grid utilisation metrics with regulators in Maine, Virginia, and Maryland to incentivise extracting more from existing infrastructure. The episode closes on the need for distribution system operators and the affordability death spiral that looms if the structural incentives don't shift.

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As coal and gas plants retire, the energy transition conversation focuses on replacing their generation capacity. What gets far less attention is the loss of the physical properties those machines provided for free: inertia that stabilises frequency, fault current that supports voltage during disturbances, and reactive power that regulates voltage across the network. These services come from the physics of enormous spinning rotors synchronised to the grid, responding instantaneously, without sensors, software or control loops. As inverter-based resources replace them, that mechanical immune system disappears, and a new, extreme stress test is arriving at the same time in the form of AI data centres whose loads can swing by hundreds of megawatts in a fraction of a second.

Host Bridget van Dorsten is joined by Kristina Carlquist, General Manager of Synchronous Condensers at ABB, and Christian Payerl, Sales Manager of Synchronous Condensers at ABB, to unpack why a technology that has existed for as long as the grid itself is now experiencing a revival.

Christian explains the three ancillary services the grid is losing, inertia, short-circuit current and reactive power, and why inverter-based generation does not replace them. Grid-forming batteries can be programmed to simulate inertia, but each charge-discharge cycle degrades lifetime, overload capacity is limited to microseconds, and the models needed for accurate grid simulation are often tied up in manufacturer IP. Synchronous condensers respond on physics alone, in both directions, with no degradation and no modelling uncertainty. The recent blackout in Spain illustrates what happens when that gap is left unfilled.

Kristina walks through the commercial traction. ABB's partnership with VoltaGrid on isolated data center microgrids has grown from an unexpected inbound enquiry in late 2024 to dozens of synchronous condensers delivered. On the grid-connected side, the Faroe Islands have deployed four units with a fifth on the way as part of their push toward 100% renewables, already achieving multi-day periods of fully renewable operation. ABB is also working with Korea's Jeju Island on its first flywheel-equipped deployment. The demand pattern is widening: islands integrating renewables, TSOs managing weak grid regions, mines electrifying operations, and now data centre developers who had never considered grid stability equipment before.

The episode closes on regulation and standards. Christian, who participates in international standards work through CIGRE, notes that there is still no international standard for flywheel safety and that the treatment of inertia as a paid service varies dramatically by country. While inertia is compensated as a paid service in the UK, in Sweden it is treated as free – rotating machines providing it receive no income stream for doing so. As data center load grows faster than regulation can respond, both guests argue that the answer is not one technology but a combination, provided the industry, utilities and policymakers can align on what the grid actually needs to remain stable.

This episode is sponsored by GridBeyond.

Energy asset owners face a critical challenge: how to optimize performance and drive new revenue in competitive, fast-moving markets. GridBeyond solves this through AI-powered forecasting, energy trading and optimization. 

GridBeyond's platform delivers: 

• Precision forecasting to anticipate market opportunities 
• Intelligent market access across multiple revenue streams 
• Real-time control that responds instantly to market conditions 
• Optimization that combines AI insights with expert oversight 

Whether you're managing batteries, gas peakers, hybrid sites, or complex multi-asset portfolios, GridBeyond helps you turn assets into high-performance revenue machines. The proven platform has helped businesses across the energy sector maximize returns and accelerate their energy transition. 

Want to learn more? Visit go.gridbeyond.com/recharged  https://go.gridbeyond.com/recharged  

See Privacy Policy at https://art19.com/privacy and California Privacy Notice at https://art19.com/privacy#do-not-sell-my-info.

Utilities are under pressure to deliver generation that is dispatchable, affordable, and clean enough to satisfy increasingly stringent environmental rules, notoriously hard to do in one asset. As renewables grow, the gas turbines and engines that have historically filled the gap come with a NOx problem, a CO2 problem, or both. Hydrogen offers a path through, but the supply isn't there yet. So what do you build today?

Host Bridget van Dorsten is joined by Shannon Miller, CEO of Mainspring Energy, and Will Hazelip of National Grid Ventures, to dig into a technology most listeners haven't heard of and the first commercial hydrogen-powered deployment of it. Mainspring's 250-kilowatt linear generator is being installed at National Grid's 1,500 MW North Port facility on Long Island, in partnership with NYSERDA, the Long Island Power Authority, and Stony Brook University.

Shannon explains how Mainspring redesigned the generator using the power electronics that drive solar inverters, batteries and EVs, replacing mechanical systems with software, eliminating the flame, and operating at temperatures low enough to take NOx out of the equation. An adaptive pressure cycle, software-controlled in real time, runs the same hardware on hydrogen, compressed natural gas, biogas, propane or blends, with no hardware change. The 250 kW form factor matters too: efficiency holds across the full load range, fleet redundancy replaces single-asset reliability risk, and deployment is a concrete pad plus electrical and fuel hookups rather than a multi-year build.

Will frames the project against the regulatory backdrop. Long Island sits in a non-attainment zone for NOx, and New York's path to a carbon-free grid requires what the state calls a dispatchable emissions-free resource. The unit will run for 12 months on green hydrogen and on compressed natural gas, with Stony Brook measuring emissions and efficiency, NYSERDA watching for regulatory design, and National Grid building operational experience for the rest of its ageing fleet.

The economic case rests on the alternative. New-build hydrogen-capable gas turbines run $3,500–$4,000/kW on capex (per Wood Mackenzie), with delivered power costs reaching $300–$900/MWh once hydrogen is layered in. Shannon's point is that committing to a single-fuel turbine only pays off if the fuel actually arrives at the scale and price you assumed. With hydrogen supply uncertain, that's a stranded-asset risk linear generators avoid by running on whatever fuel is available today. Will adds the carbon-market angle saying that as carbon pricing develops, real-time fuel switching becomes an optimisation lever, not just a hedge.

Then there’s the supply reality. Total US hydrogen production today isn't enough to fuel a single 500 MW power plant, and with 45V tax credit requirements tightening and federal climate policy in flux, the gap between hydrogen ambition and supply isn't closing fast. Will's suggests starting with the fuels that exist today and scale into hydrogen as supply grows.

The episode closes on demand. Mainspring's factory produces 325 MW a year today and can roughly double in 12–15 months, with pull from industrial customers, data centres and AI infrastructure, and utilities at once, driven by the same problem: nobody can get power fast enough.

This episode is sponsored by GridBeyond.

Energy asset owners face a critical challenge: how to optimize performance and drive new revenue in competitive, fast-moving markets. GridBeyond solves this through AI-powered forecasting, energy trading and optimization. 

GridBeyond's platform delivers: 

• Precision forecasting to anticipate market opportunities 
• Intelligent market access across multiple revenue streams 
• Real-time control that responds instantly to market conditions 
• Optimization that combines AI insights with expert oversight 

Whether you're managing batteries, gas peakers, hybrid sites, or complex multi-asset portfolios, GridBeyond helps you turn assets into high-performance revenue machines. The proven platform has helped businesses across the energy sector maximize returns and accelerate their energy transition. 

Want to learn more? Visit go.gridbeyond.com/recharged  https://go.gridbeyond.com/recharged  

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