In Episode 53 of Redefining Energy TECH, Host Michael Barnard speaks with Tristan Smith, a prominent expert in maritime decarbonization and professor at the University College London Energy Institute. Tristan shares his insights, beginning with an overview of maritime shipping, which accounts for approximately 1 gigaton of CO₂ equivalent annually, making it responsible for about 2-3% of global emissions. Crucially, the regulatory oversight for these emissions sits largely with the International Maritime Organization (IMO) due to the nature of international shipping occurring beyond national jurisdictions.

Our conversation moves through the historical context of the IMO, tracing its evolution from a safety standards body established post-Titanic disaster to an organization now deeply involved in global climate policy. Historically, the IMO faced significant challenges in progressing climate regulations due to entrenched disagreements between developed and developing countries around responsibilities. The Paris Agreement in 2015, alongside persistent advocacy from smaller nations like the Marshall Islands, notably shifted this dynamic, leading to the adoption of the IMO’s initial climate strategy in 2018.

We delve into recent regulatory developments, including the unprecedented IMO vote initiated by Saudi Arabia, resulting in a decisive 63-to-16 vote (with around 29 abstentions) mandating progressive reductions in greenhouse gas intensity for ships over the next 25 years. The regulation sets clear fines for non-compliance—$380 per ton for exceeding the highest threshold and $100 per ton for mid-level breaches—ultimately requiring ships to achieve a 65% reduction in emissions intensity by 2040.

The discussion highlights the role of Emissions Control Areas (ECAs), established initially to curb SOx and NOx emissions in sensitive regions like the Baltic Sea, North Sea, and North America, effectively serving as early tests for broader international regulations. Additionally, we critically examine LNG’s journey from a touted solution for reducing SOx and NOx emissions to its complicated position as a potential climate liability due to significant methane emissions both onboard and upstream. Norway’s influential promotion of LNG and subsequent studies, such as those by the International Council on Clean Transportation, underline these complexities. 

Finally, Tristan emphasizes the future challenges facing maritime decarbonization, notably the risk of technological lock-in with LNG and the powerful role of the oil and gas industry within the maritime sector. We also explore the shifting political landscape as global fossil fuel transportation—currently 40% of maritime tonnage along with another declining 15% for raw iron ore—faces inevitable structural declines, promising profound implications for industry dynamics and global decarbonization efforts.

In this episode of Redefining Energy Tech, host Michael Barnard concludes his conversation (See Ep51 for part 1/2) with Dr. Joseph Romm about the uncomfortable truths behind hydrogen's persistent hype. Romm—physicist, climate policy expert, and author of The Hype About Hydrogen—lays out a detailed indictment of hydrogen’s role in the energy transition and the vested interests keeping it afloat. As the 20th anniversary edition of his book hits shelves this Earth Day, he’s doubling down on his central message: hydrogen is the wrong answer to the right problem.

We begin by unpacking why oil and gas companies are so enamored with hydrogen. It’s not about climate—it’s about preserving infrastructure and revenue streams. These companies already produce and move hydrogen, mostly for refining heavy, dirty oil. Green hydrogen, despite its green sheen, still fits their business model. But Romm doesn’t buy it. He notes that the economics don’t work. Carbon capture projects like Sleipner and Norway’s Northern Lights are prohibitively expensive and under-deliver. And if we actually tried to build out a CO₂ pipeline network big enough to matter? We’d need something as vast and capital-intensive as the entire global oil distribution system—for just a slice of the emissions problem.

Romm argues hydrogen may have a future in niche industrial applications, but as a general-purpose energy carrier, it's fatally flawed. It leaks, it’s explosive, and it’s staggeringly inefficient. Producing green hydrogen wastes half the renewable electricity, liquefying it wastes another 40%, and every transfer step leaks at least 1%. The total system leakage can reach 10%, and that’s not just waste—it’s warming. While hydrogen isn’t a greenhouse gas itself, it prolongs methane’s atmospheric lifespan. Its 20-year global warming potential? Around 35—an eye-opener for anyone counting climate impact in decades, not centuries.

The safety issues alone should give pause. Hydrogen ignites invisibly, has an explosive range far wider than natural gas, and can’t be odorized for fuel cells. Industrial users need massive safety zones, spark-proof gear, and constant ventilation. That’s not something we want coursing through urban refuelling infrastructure.

Romm also skewers the geopolitical assumptions baked into Europe’s hydrogen plans—especially proposals to convert African renewables into hydrogen for export. He calls it what it is: 21st-century energy colonialism. Far better, he says, for Africa to use that clean energy locally to power homes, industry, and prosperity directly through electrification.

Ultimately, Romm is clear: if the world is serious about climate, it needs to stop chasing the hydrogen mirage. We should electrify as much as we can, as fast as we can. The rest is delay, marketing spin, and stranded asset risk.

His updated book, The Hype About Hydrogen, is available on Amazon this Earth Day—April 22. If you're still clinging to the idea that hydrogen will save the energy transition, this conversation might just change your mind.    

In this episode of Redefining Energy Tech, host Michael Barnard sat down with Dr. Joseph Romm—physicist, energy policy veteran, and author of The Hype About Hydrogen—to pull back the curtain on hydrogen’s persistent mystique. Romm isn’t new to the debate. Back in the early 2000s, he was among the first to publicly challenge the logic of hydrogen as a viable energy carrier. Now, twenty years later, he’s back with a completely rewritten edition of his book, just in time for Earth Day, and the message hasn’t changed: the hydrogen hype is still hype.

What makes Romm’s critique so compelling is his history. He once supported hydrogen research while in the Clinton-era Department of Energy, betting on Sandia Labs’ onboard gasoline reformers. But that hope dissolved under the weight of technical reality. In 2003, as the Bush administration rolled out its $1.3 billion hydrogen initiative, Romm published the first edition of The Hype About Hydrogen, drawing a stark contrast between hydrogen’s theoretical promise and its practical inefficiency. The fundamental math hasn’t budged. Hydrogen production, storage, transport, and conversion wastes up to 80% of the original renewable electricity. Batteries? They waste closer to 20%.

Fast forward to today, and hydrogen is once again being paraded as a climate solution, this time with a new coat of green paint. But Romm’s updated research shows the same miscalculations baked into the models of the IEA, CSIRO, and even PIK—institutions that projected green hydrogen prices based on wildly optimistic learning curves. Hydrogen didn’t follow the same cost trajectory as solar or batteries. In fact, between 2020 and 2024, the cost of electrolyzers increased by 40%—a staggering reversal of expectations that should have set off alarm bells across boardrooms and ministries.

We also tackled the real-world energy transition playing out in China. While Western nations argue over tariffs and watch supply chains buckle, China is installing 350 gigawatts of solar and wind in a single year—ten times its nuclear additions—and prioritizing direct electrification over hydrogen. It’s not just policy rhetoric; it’s industrial reality.

This divergence is becoming painfully clear in the transport sector. European advisors have publicly declared hydrogen “dead for trucks,” pointing instead to the obvious solution: battery-electric vehicles and megawatt-scale charging infrastructure. The market is responding. Companies trying to straddle both hydrogen and battery bets—Van Hool, Quantron, Nikola—are struggling or collapsing. Romm calls this “narrative disarticulation”—an elegant way of saying that serious people are quietly walking away from the hydrogen dream.

His final warning is unequivocal: investing in hydrogen based on outdated assumptions is a recipe for stranded assets and political distraction. Industry’s call to support “dirty hydrogen now, clean later” isn’t just a bait-and-switch—it’s a carbon trap dressed up in green branding. If we’re serious about climate, it’s time to let go of the hydrogen mirage and double down on what we know works: clean, efficient electrification.

Want to rethink your assumptions on hydrogen? This is the episode to listen to.

Simon Todd is back with Michael Barnard for part 2/2, and this time he’s drilling deeper—both literally and figuratively. In this second round, the Managing Director of Causeway Energies walks us through the hard tech and hard truths of geothermal energy, especially as it applies to the UK and Ireland. What emerges is a grounded, brutally realistic look at where geothermal works, where it doesn’t, and how to separate serious solutions from science fiction.

We kick off with the cross-pollination of oil and gas tech into geothermal—rotary PDC bits, custom drilling muds, and all the bruised geology that comes with punching into granite. The oil patch may be sunsetting, but its tools are still getting a second act. Todd highlights how firms like Fervo are making surgical improvements to geothermal drilling by leveraging fracking's dirty tricks for clean heat, aiming to stimulate natural fractures in hot granite. It's technically elegant, but there’s a catch: the economics are still brutal. EGS systems might sound great on paper, but $150–$250 per megawatt-hour isn’t going to win against wind or solar anytime soon. Todd doesn’t sugarcoat it. The question isn’t if Fervo’s system works—it’s whether it can keep working at nameplate for 25 years straight.

He then turns to the UK and Ireland's own geothermal potential. Unlike the flashy volcanic zones of the western U.S. or Iceland, we’re working with Hot Sedimentary Aquifers and radiogenic granites. The geology is less forgiving, but far from useless. Causeway’s bet is on moderate-depth wells—500 to 1,500 meters—which fall into what Todd calls the "Goldilocks zone": hot enough to matter, shallow enough to stay affordable.

And this is where Todd really breaks from the crowd. Forget chasing deep geothermal megaprojects with 5 km drill strings and power plant dreams. Causeway Energies has pivoted to something far more practical: industrial heat. About half of emissions are tied to heating, most of it well below 100°C. Modern high-temperature heat pumps—some hitting 150°C—make pairing geothermal with industrial facilities like breweries and hospitals an obvious win. The kicker? These systems offer round-trip efficiencies that embarrass hydrogen and electrify sectors gas can’t reach.

One technology worth highlighting here is the Standing Column Well—basically a turbocharged hybrid of open and closed-loop systems that’s 3 to 5 times more thermally potent than your average ground loop. It thrives in fractured aquifers that aren’t fit for drinking water, dodging some of the regulatory red tape. And with a century’s worth of oil and gas borehole data lying around, Causeway has a treasure map to the best locations.

Simon Todd isn't pitching geothermal as a silver bullet. He’s carving out a niche: targeted, replicable, cost-effective solutions for decarbonizing industrial heat. It’s not glamorous. It’s not headline-grabbing. But it works. And in the climate transition, that might just be the most disruptive idea of all.

Follow the podcast to hear more from the people actually building the energy future, not just imagining it      

In this eye-opening episode (part 1/2), Host Michael Barnard invites Simon Todd, Managing Director of Causeway Energies and a man whose geological expertise spans from the chalk beds of Northern Ireland to the drilling decks of BP. Simon joins the podcast to drag geothermal energy out of its misunderstood niche and into the spotlight it deserves.

Simon, who spent 25 years at BP before pivoting hard into the future, lays out a vision for geothermal that’s far more than volcanic spas and Icelandic outliers. He starts by grounding us (literally) in the Earth’s temperature dynamics: from a molten 6,000°C core to the relatively tame gradients of continental crust. We learn that geothermal isn’t just a matter of poking around tectonic hotspots. With modern drilling and clever thermal engineering, you can tap heat just about anywhere—even in the soggy, non-volcanic soils of the UK and Ireland.

He gets into the mechanics too, explaining how ground source heat pumps use the shallow earth—those top 10–15 meters that swing with the seasons—to store and retrieve heat. He unpacks the performance metric du jour, the Coefficient of Performance (COP), and shows how deeper wells (500 to 700 meters) vastly outperform air-source systems. The returns? In some projects, a sub-3-year payback. That’s not a climate virtue signal—that’s a boardroom greenlight.

But Simon doesn't stop at closed-loop systems. He dives into the real geothermal opportunity hiding beneath our feet: open-loop aquifer systems. These draw warm water from permeable rock formations—‘rock sponges,’ as he puts it—offering faster heat transfer than passive conduction. And yet, while ATES systems thrive across the Netherlands and Belgium, they’re barely used in the UK or Ireland. Why? Bureaucratic inertia, unfamiliarity, and maybe just a lack of storytelling.

With directional drilling tech now able to reach aquifers from a single pad, and real-time data steering drill heads with pinpoint accuracy, Simon argues we have the tools and the data. What’s missing is awareness—and maybe a bit of ambition.

This episode is a geothermal masterclass from someone who’s lived both the legacy fossil past and the clean energy future. If you're still thinking geothermal is just for hot springs and sci-fi, Simon Todd is here to prove otherwise—with numbers, with tech, and with real-world results.

Follow the show for more episodes like this one, where energy myths get debunked, and the future gets explained.

In this second part of the conversation, Mark O'Malley returns to discuss with co-host Michael Barnard grid reliability and the evolving challenges of integrating renewable energy.

The conversation examines successful examples from Germany, Denmark, and Ireland, highlighting Ireland's unique position as a synchronous island. Texas also emerges as a case study, demonstrating how increased wind and solar capacity has contributed to improved grid stability. While these examples show progress, the discussion underscores the importance of balancing reliability standards with cost-effectiveness and exploring solutions such as flexible supply chains and industrial demand response to manage renewable intermittency.

The episode delves into the state of research on power system transformation. While planning methodologies for renewables are well understood, gaps remain in implementation and data availability. Inverter-based resources (IBRs) are making strides, but their seamless integration into the grid remains a work in progress. High Voltage Direct Current (HVDC) technology has proven effective, but its interaction with AC systems requires further study. The need for improved models is evident, as utilities and grid operators require greater confidence before deploying new technologies. However, commercial realities often hinder investment in specialized power system analysis tools, further complicating the transition.

A key topic is the Global Power System Transformation Consortium (GPST), which is working toward becoming a legal entity capable of managing resources and funding. The initiative aims to support system operators worldwide in implementing cutting-edge research and solutions, requiring significant financial backing. Estimates suggest that $2 billion will be needed for global implementation, with an additional $500 million required for research and demonstrations. Despite these financial hurdles, progress is being made, as developers and original equipment manufacturers (OEMs) recognize the economic benefits of supporting GPST.

Beyond funding, the industry faces another pressing challenge—an acute shortage of highly skilled power system professionals. While the demand for expertise is growing exponentially, talent production is increasing at a much slower pace. Bridging this gap will require targeted strategies to develop a new generation of engineers and researchers, ensuring that the power sector can keep up with the accelerating energy transition.

Action items from this episode include reaching out to Mark O'Malley to explore GPST funding opportunities and developing strategies to scale up the production of skilled professionals in the power sector.

The transformation of global power systems is accelerating as wind and solar become dominant energy sources. In the latest episode of Redefining Energy Tech, Mark O'Malley, Leverhulme Professor of Power Systems at Imperial College London, offers a deep dive into the challenges and opportunities of this transition in an in-depth conversation with host Michael Barnard.

O'Malley brings decades of expertise in energy system integration, drawing from his work at McGill University, NREL, and the Energy Systems Integration Group. The conversation highlights a pivotal 2018-2019 workshop on achieving high renewable penetration, setting the stage for discussions on the shift from traditional synchronous generators to inverter-based resources.

The move to an inverter-driven grid presents new technical hurdles, particularly in balancing supply and demand while maintaining stability. O'Malley outlines six critical research areas shaping the future of power systems: inverter technologies, distributed energy resources, planning and adequacy, control room modernization, stability detection tools, and system services.

One of the most pressing challenges is optimizing the balance between grid-following and grid-forming inverters. While grid-following inverters currently dominate, grid-forming inverters hold the potential to establish voltage and frequency independently. The complexity of integrating diverse inverter designs across different manufacturers adds another layer of difficulty.

Beyond technical challenges, the discussion extends to global power system dynamics, with a focus on China’s contrasting regional power structures. The integration of AC and DC transmission, particularly in connecting renewable-rich regions to demand centers, underscores the necessity for international collaboration in solving system-wide challenges.

Key action items emerging from the discussion include updating the research agenda for power system transformation and refining the balance between inverter types in various grid configurations. As power systems evolve, the industry must prioritize research, coordination, and investment to ensure stability and reliability in a renewable-driven future.

Listen to the full conversation on Redefining Energy Tech for an in-depth exploration of these critical issues shaping the next era of energy systems.

In Episode 46 of *Redefining Energy - Tech*, host Michael Barnard concludes his talk with David Fishman. David examines China's dynamic energy landscape, emphasizing the rapid development of wind, solar, and energy storage technologies.

The episode begins with a comprehensive analysis of wind energy, highlighting significant growth in onshore wind despite grid curtailment challenges in western regions. Offshore wind, while slower to develop, is gaining traction with ambitious plans for 15-30 GW per coastal province. Meanwhile, distributed wind energy is emerging as a key focus under innovative policies like the "10,000 Villages Harness the Wind" initiative.

The conversation moves to solar energy, where Fishman explores the dual success of utility-scale megabase projects in deserts and the booming distributed solar sector. Public-private collaborations, such as the Whole County Rooftop Solar Promotion Program, have driven rooftop solar installations to tens of gigawatts in China's eastern provinces, accounting for half of the solar market.

Fishman then delves into energy storage, contrasting the long-standing dominance of pumped hydropower with the meteoric rise of lithium-ion battery installations, which now outpace hydro in capacity. Battery storage serves critical roles in energy arbitrage, grid stability, and regulatory compliance, driven by mandates for renewables projects to integrate storage solutions. Independent operators are also investing heavily in battery facilities near renewable energy sites.

The episode concludes with a discussion of technological advancements, including the decreasing costs of lithium iron phosphate (LFP) battery storage, averaging $66 per kWh in recent auctions. Fishman reflects on potential resource constraints and philosophical questions surrounding China's motivations for clean tech innovation, challenging listeners to consider whether noble intentions are essential if the results drive meaningful progress.

This episode provides a nuanced exploration of the strategies and challenges defining China’s energy future.

In Episode 45 of the *Redefining Energy TECH* series, host Michael Barnard invites David Fishman, a senior manager at Lantau Group. David delves into the intricacies of China's energy landscape, highlighting the country's efforts to balance growth and decarbonization. Despite coal's continued dominance, constituting 55-60% of the energy mix, Fishman discusses measures aimed at limiting its growth. While projections suggest a slight increase in coal consumption due to weaker hydropower performance, China is making strides to shut down smaller, less efficient coal plants. Efforts to grow electricity consumption without proportionally increasing coal usage remain a priority, with current coal plant utilization rates around 48-49%.

Natural gas plays a minor role in China’s power generation, primarily confined to coastal regions where LNG imports supplement energy needs. LNG is an emerging trend in transportation, with 8% of heavy long-distance trucks now powered by LNG, offering an alternative to diesel. The rise of electric vehicles is also noteworthy, as Tesla sales in China grew by 8.8%, bucking the trend of global sales declines.

China’s nuclear sector, once envisioned as a central pillar of its energy strategy, has faced delays but is now regaining momentum. The development of domestic nuclear technology, particularly the Hualong 1 reactor, has enabled the approval of ten new reactors annually since 2022. Although nuclear energy’s role has shifted from a backbone solution to a niche yet critical component, Fishman underscores its potential importance in achieving the final stages of grid decarbonization.

The episode also explores China’s robust progress in renewable energy. Wind and solar power, which began scaling up in the late 2000s, are now adding an impressive 300 gigawatts annually, consistently exceeding targets. While nuclear remains behind on its ambitious goals, renewables continue to lead the charge in transforming China’s energy system. Fishman reflects on the unique scalability of China’s nuclear program, noting the challenges other countries may face in replicating its rapid progress. With renewables, nuclear, and a shifting transportation landscape, China’s energy future presents both challenges and opportunities for decarbonization.

In this second part, Gavin Mudd, director of the Critical Minerals Intelligence Center at the British Geological Survey, shares insights into the pivotal role of minerals in the energy transition. While Australia boasts abundant resources, Mudd highlights significant gaps in expertise and labor to extract these materials efficiently. He underscores the urgency of restructuring the iron ore sector to enable green steel production, pointing out that Australia exports four times more energy through coal and natural gas than it consumes domestically. Although lithium mining has surged from $50 million to billions in exports over a decade, Mudd notes it is unlikely to rival coal and LNG in economic impact.

The discussion also tackles the challenges of recycling critical minerals, especially lithium batteries. Unlike lead-acid batteries, which benefit from established regulations and high recycling rates, lithium batteries pose difficulties due to evolving chemistries. Mudd calls for improved regulations, better product design, and increased consumer education to address these recycling hurdles. He also raises concerns about dwindling supplies of antimony and its dissipative use, highlighting the broader need for sustainable management of critical minerals.

A crucial distinction between mineral resources and reserves forms another part of the conversation. While resources represent known quantities of materials, reserves refer to what is currently profitable to extract—a difference often misunderstood. Mudd emphasizes the importance of robust data collection and analysis, noting that many critical minerals lack reserve estimates due to their byproduct status.

Despite these challenges, Mudd remains optimistic. He dispels fears of resource shortages, highlighting increasing global availability of critical minerals and the potential of recycling to reduce environmental impact. By advocating for innovative approaches like reprocessing mine tailings and improving supply chain data, he envisions a future where technological ingenuity overcomes current barriers to sustainability.

This episode calls for bold action, from restructuring Australia’s iron ore sector to enhancing data strategies for byproduct minerals, offering a roadmap for advancing the energy transition sustainably and effectively.