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Poland's battery storage market is skipping the pilot phase, with its first projects starting at 200MW, a size it took Germany five years to reach. And because of the way Poland runs its grid, two identical batteries in different locations can earn very different amounts. With over 2GW of batteries expected on the grid by 2028, the market is about to change fast.Ed Porter is joined by Aleksandra Radwańska, Country Lead Poland at Entrix, and Jan Kłoczko at Entrix, to unpack what it takes to optimise batteries in a market scaling this fast.They cover:How two identical batteries in different parts of Poland can earn very different amounts, and why each needs its own scorecard.Why getting a new battery approved to support Poland's grid can take up to two years, while everyone is still learning the rules.How over 2GW of batteries expected by 2028, in a country that peaks at around 25GW, will change the way power is traded in Poland.What battery owners are choosing between: guaranteed-income deals that help secure loans, or betting on the market.Why Poland's single national electricity price is coming under strain as the grid gets more congested.Want to see how battery assets in Poland are performing? Ko, Modo Energy's AI analyst, is built for exactly these questions. CHAPTERS 0:00 Poland's battery storage market: straight to 200MW 1:17 Central dispatch and location-based battery revenues 4:11 Credible battery optimisers vs good pitch decks 6:46 Benchmarking optimiser performance per asset 9:08 Ancillary services prequalification in Poland 12:47 Starting with 100-200MW batteries: no sandbox 13:19 Intraday liquidity and the TSO balancing crackdown 15:27 Wholesale trading patterns and Poland's duck curve 18:44 Over 2GW of batteries by 2028 20:11 Route to market: floors, tolls and merchant 24:01 Flexible and asymmetric grid connections 27:29 Lessons from bringing large batteries online 28:48 Contrarian view: one national price, a constrained grid 30:47 Contrarian view: collaboration over complaint

Poland's battery storage market is skipping the pilot phase, with its first projects starting at 200MW, a size it took Germany five years to reach. And because of the way Poland runs its grid, two identical batteries in different locations can earn very different amounts. With over 2GW of batteries expected on the grid by 2028, the market is about to change fast.Ed Porter is joined by Aleksandra Radwańska, Country Lead Poland at Entrix, and Jan Kłoczko at Entrix, to unpack what it takes to optimise batteries in a market scaling this fast.They cover:How two identical batteries in different parts of Poland can earn very different amounts, and why each needs its own scorecard.Why getting a new battery approved to support Poland's grid can take up to two years, while everyone is still learning the rules.How over 2GW of batteries expected by 2028, in a country that peaks at around 25GW, will change the way power is traded in Poland.What battery owners are choosing between: guaranteed-income deals that help secure loans, or betting on the market.Why Poland's single national electricity price is coming under strain as the grid gets more congested.Want to see how battery assets in Poland are performing? Ko, Modo Energy's AI analyst, is built for exactly these questions. CHAPTERS 0:00 Poland's battery storage market: straight to 200MW 1:17 Central dispatch and location-based battery revenues 4:11 Credible battery optimisers vs good pitch decks 6:46 Benchmarking optimiser performance per asset 9:08 Ancillary services prequalification in Poland 12:47 Starting with 100-200MW batteries: no sandbox 13:19 Intraday liquidity and the TSO balancing crackdown 15:27 Wholesale trading patterns and Poland's duck curve 18:44 Over 2GW of batteries by 2028 20:11 Route to market: floors, tolls and merchant 24:01 Flexible and asymmetric grid connections 27:29 Lessons from bringing large batteries online 28:48 Contrarian view: one national price, a constrained grid 30:47 Contrarian view: collaboration over complaint

As the electrification of heat increases and technologies like heat pump adoption grows, it's tempting to assume the gas network can simply be wound down street by street, in line with falling demand. But it's not as simple as this: network topology, not customer count, decides when decommissioning is actually viable, and the UK gas network is nowhere close to that point today.Sam Wilson, Director of Energy System Operations at Cadent, joins the podcast to explain the engineering reality behind that constraint — and how things like pressure control, storage, and gas injection all factor into it.They cover:Why network topology, not customer count, decides when decommissioning is actually viableHow gas goes from completely odourless at transmission pressure to detectable on your street.What it takes to step pressure down from around 90 bar in the transmission system, through off-takes and above ground installations, to roughly 30 millibars at a domestic appliance.How line packing turns the pipe network itself into short-duration storage, with operators raising or lowering in-pipe pressure to absorb daily demand swings.What's actually limiting how much biomethane and hydrogen can go into the network today, and why hydrogen can be blended in without any changes needed to downstream appliances.Want to know how heat electrification could reshape power demand in GB? Ask Ko - Modo Energy's AI energy analyst - sign up for free hereTranscript available hereYou can watch or listen to new episodes every Tuesday. Transmission is a Modo Energy production. Your host is Ed Porter - Director EMEA & APAC at Modo Energy.Chapters:0:00 Introduction1:09 What people get wrong about the gas network.3:03 From gas field to home boiler: the full journey4:33 UK's four gas distribution networks explained5:15 Transmission pressure: 90 bar and above6:25 Line packing - storing gas inside the pipes7:55 Industrial vs domestic gas pressure needs12:34 Replacing 100-year-old cast iron gas pipes13:56 Biomethane in the gas network17:15 Hydrogen blending: how much the network can take21:22 Getting hydrogen to industrial gas users23:18 Electrification vs the gas network's engineering reality24:26 What happens when homes remove their gas connection25:46 Why decommissioning the gas network isn't linear31:57 Sam Wilson's contrarian take on the energy transitionMusic licensed via Artlist.

As the electrification of heat increases and technologies like heat pump adoption grows, it's tempting to assume the gas network can simply be wound down street by street, in line with falling demand. But it's not as simple as this: network topology, not customer count, decides when decommissioning is actually viable, and the UK gas network is nowhere close to that point today.Sam Wilson, Director of Energy System Operations at Cadent, joins the podcast to explain the engineering reality behind that constraint — and how things like pressure control, storage, and gas injection all factor into it.They cover:Why network topology, not customer count, decides when decommissioning is actually viableHow gas goes from completely odourless at transmission pressure to detectable on your street.What it takes to step pressure down from around 90 bar in the transmission system, through off-takes and above ground installations, to roughly 30 millibars at a domestic appliance.How line packing turns the pipe network itself into short-duration storage, with operators raising or lowering in-pipe pressure to absorb daily demand swings.What's actually limiting how much biomethane and hydrogen can go into the network today, and why hydrogen can be blended in without any changes needed to downstream appliances.Want to know how heat electrification could reshape power demand in GB? Ask Ko - Modo Energy's AI energy analyst - sign up for free hereTranscript available hereYou can watch or listen to new episodes every Tuesday. Transmission is a Modo Energy production. Your host is Ed Porter - Director EMEA & APAC at Modo Energy.Chapters:0:00 Introduction1:09 What people get wrong about the gas network.3:03 From gas field to home boiler: the full journey4:33 UK's four gas distribution networks explained5:15 Transmission pressure: 90 bar and above6:25 Line packing - storing gas inside the pipes7:55 Industrial vs domestic gas pressure needs12:34 Replacing 100-year-old cast iron gas pipes13:56 Biomethane in the gas network17:15 Hydrogen blending: how much the network can take21:22 Getting hydrogen to industrial gas users23:18 Electrification vs the gas network's engineering reality24:26 What happens when homes remove their gas connection25:46 Why decommissioning the gas network isn't linear31:57 Sam Wilson's contrarian take on the energy transitionMusic licensed via Artlist.

The grid is swapping spinning turbines for grid forming inverters, and something is getting lost in the trade. A turbine could always throw 5 times its normal output to clear a fault, for free, using nothing but physics. Inverters can only manage around 1.5 times theirs. So if renewables are going to take over, where does that missing strength come from instead?Ben Braun is Chief Engineer at Fluence, where he's spent his career working on power electronics - from batteries to the grid. In this episode, he breaks down grid forming vs grid following inverters for everyone without an electrical engineering degree.They cover:- Why "grid forming is slower" than grid following - and why that slower response is actually what makes it more stable in a fault.- Why NESO in GB and AEMO in Australia are chasing completely different things from grid forming batteries.- Why grid inertia disappears as spinning turbines retire, and how a sudden burst of power from a battery can fake it.- Why volatile AI training loads are turning data centres into miniature grids of their own, and how batteries are used to stop that volatility ever reaching the wider network.- Why Ben's biggest concern isn't too little fault current on the grid, but too much of it - and why that could force a wave of grid upgrades most people haven't priced inWant to see which grids are paying for inertia and fault current today, or where the next stability tenders are opening? Ko, Modo Energy's AI analyst, is built for exactly these questions. Free sign up: https://modoenergy.com/product/ko?utm_source=podcast&utm_medium=youtube&utm_campaign=ben_braun&utm_content=ko_signup

The grid is swapping spinning turbines for grid forming inverters, and something is getting lost in the trade. A turbine could always throw 5 times its normal output to clear a fault, for free, using nothing but physics. Inverters can only manage around 1.5 times theirs. So if renewables are going to take over, where does that missing strength come from instead?Ben Braun is Chief Engineer at Fluence, where he's spent his career working on power electronics - from batteries to the grid. In this episode, he breaks down grid forming vs grid following inverters for everyone without an electrical engineering degree.They cover:- Why "grid forming is slower" than grid following - and why that slower response is actually what makes it more stable in a fault.- Why NESO in GB and AEMO in Australia are chasing completely different things from grid forming batteries.- Why grid inertia disappears as spinning turbines retire, and how a sudden burst of power from a battery can fake it.- Why volatile AI training loads are turning data centres into miniature grids of their own, and how batteries are used to stop that volatility ever reaching the wider network.- Why Ben's biggest concern isn't too little fault current on the grid, but too much of it - and why that could force a wave of grid upgrades most people haven't priced inWant to see which grids are paying for inertia and fault current today, or where the next stability tenders are opening? Ko, Modo Energy's AI analyst, is built for exactly these questions. Free sign up: https://modoenergy.com/product/ko?utm_source=podcast&utm_medium=youtube&utm_campaign=ben_braun&utm_content=ko_signup

Joe McDonald says close to 30% of a business power bill can go to trading desks, balancing costs and wholesale market fees most customers never see. Behind suppliers can sit five or six more intermediaries, each taking a cut before the energy ever arrives. Is that a market working as designed, or one taking more than it should?Joe is Founder & CEO of Tem Energy, and has spent over a decade inside the middle of the energy market, watching where the money actually goes on its way to the meter. He's now building the AI infrastructure to strip those middlemen out of the chain, with Tem already transacting over £1 billion a year across thousands of UK businesses, backed by a fresh Series B to fund expansion into Texas and Australia.They cover:Why up to 30% of a business energy bill can go to trading desks, balancing costs and wholesale fees layered behind the supplier.How forward market contracts fix energy prices for months or years and why "shape matching" between generators and buyers creates a shadow market worth billions.The P442 grid charging exemption, and why a change this small took two years to push through.Why Joe believes Tem's AI agents could remove around 90% of labor costs in energy transactions, and why he sees that trade-off as necessary.Tem Energy's plan after its Series B - expanding into Texas and Australia before Europe and the case for energy AI becoming the UK's next trillion-dollar industry.Want to dig deeper into where that 30% actually goes, or how forward contracts are priced? Ask Ko, Modo Energy's AI analyst, for free sign up also gets you trial access to Modo Energy's research.You can watch or listen to new episodes every Tuesday. Transmission is a Modo Energy production. Your host is Ed Porter - Director EMEA & APAC at Modo Energy.Chapters:0:00 Introduction1:24 The Real Cost Layers Behind A Business Energy Bill3:17 The Mechanics Of Forward Energy Contracts5:25 Shape Matching Explained6:35 The Shadow Market Behind The Grid11:12 Pricing And Settling Energy Trades With AI26:46 The P442 Grid Charging Exemption36:29 The Slow Pace Of Energy Market Regulation37:37 The Same Problem Across Global Energy Markets38:36 Cutting Utility Operating Costs With AI39:22 Comparing This Model To Octopus And Kraken40:40 Joe McDonald's Contrarian View On Energy Markets41:34 Cutting 90% Of Energy Labor Costs With AI

Joe McDonald says close to 30% of a business power bill can go to trading desks, balancing costs and wholesale market fees most customers never see. Behind suppliers can sit five or six more intermediaries, each taking a cut before the energy ever arrives. Is that a market working as designed, or one taking more than it should?Joe is Founder & CEO of Tem Energy, and has spent over a decade inside the middle of the energy market, watching where the money actually goes on its way to the meter. He's now building the AI infrastructure to strip those middlemen out of the chain, with Tem already transacting over £1 billion a year across thousands of UK businesses, backed by a fresh Series B to fund expansion into Texas and Australia.They cover:Why up to 30% of a business energy bill can go to trading desks, balancing costs and wholesale fees layered behind the supplier.How forward market contracts fix energy prices for months or years and why "shape matching" between generators and buyers creates a shadow market worth billions.The P442 grid charging exemption, and why a change this small took two years to push through.Why Joe believes Tem's AI agents could remove around 90% of labor costs in energy transactions, and why he sees that trade-off as necessary.Tem Energy's plan after its Series B - expanding into Texas and Australia before Europe and the case for energy AI becoming the UK's next trillion-dollar industry.Want to dig deeper into where that 30% actually goes, or how forward contracts are priced? Ask Ko, Modo Energy's AI analyst, for free sign up also gets you trial access to Modo Energy's research.You can watch or listen to new episodes every Tuesday. Transmission is a Modo Energy production. Your host is Ed Porter - Director EMEA & APAC at Modo Energy.Chapters:0:00 Introduction1:24 The Real Cost Layers Behind A Business Energy Bill3:17 The Mechanics Of Forward Energy Contracts5:25 Shape Matching Explained6:35 The Shadow Market Behind The Grid11:12 Pricing And Settling Energy Trades With AI26:46 The P442 Grid Charging Exemption36:29 The Slow Pace Of Energy Market Regulation37:37 The Same Problem Across Global Energy Markets38:36 Cutting Utility Operating Costs With AI39:22 Comparing This Model To Octopus And Kraken40:40 Joe McDonald's Contrarian View On Energy Markets41:34 Cutting 90% Of Energy Labor Costs With AI

Battery storage went from an unproven bet to one of Europe's fastest-growing energy assets in a but the exceptional returns early investors saw have already faded as more batteries crowd the market. The real question today isn't whether a battery can make money, it's whether an optimiser can keep making money from it, market after market, year after year.In this conversation, Brecht Dierckx, Director of Physical Asset Trading & Optimisation at Centrica, joins Ed to unpack what actually separates a good battery optimiser from an average one, and why pricing, contracts and risk are becoming as important as trading itself.They cover:- Why the exceptional early returns 2017–2018 battery investors saw are gone for good, and what actually lets some optimisers keep repeating strong performance while others can't- How battery revenue has shifted over time — from grid-support services, to adjusting trades as markets move, to buying and selling across multiple markets at once — and why each edge shrinks as more batteries chase it- Why pricing a battery deal is nothing like pricing a financial instrument, and how modelling different future scenarios (rather than simple averages) reveals the real value of holding a diversified portfolio- What project developers are actually asking optimisers for now — performance guarantees, profit shares, protection from regulatory changes — and why some of those guarantees aren't realistically workable- Which European markets look most promising for battery growth next, and how emerging grid restrictions could shape how much value new assets are able to captureWant to know how flexible connection agreements or grid restrictions are changing your battery's revenue forecast? Ask Ko, Modo Energy's AI analystChapters:0:00 – Battery Storage Returns Are Saturating1:04 – Battery Optimisation Operational Excellence2:22 – Repeatable Battery Storage Returns5:43 – Ancillary Services Revenue Saturation8:14 – Battery Optimiser Performance Benchmarks10:08 – Small Vs Large Battery Trading Teams14:25 – AI In Energy Trading16:29 – Autonomous AI Battery Trading Risks18:40 – Extreme Weather Impact On Energy Trading21:49 – Best European Battery Storage Markets24:13 – Battery Storage Toll Pricing28:59 – Battery Portfolio Diversification Strategy31:36 – Flexible Connection Agreements Explained35:51 – Battery Storage Investment Guarantees38:30 – Battery Storage And Grid Transmission

Battery storage went from an unproven bet to one of Europe's fastest-growing energy assets in a but the exceptional returns early investors saw have already faded as more batteries crowd the market. The real question today isn't whether a battery can make money, it's whether an optimiser can keep making money from it, market after market, year after year.In this conversation, Brecht Dierckx, Director of Physical Asset Trading & Optimisation at Centrica, joins Ed to unpack what actually separates a good battery optimiser from an average one, and why pricing, contracts and risk are becoming as important as trading itself.They cover:- Why the exceptional early returns 2017–2018 battery investors saw are gone for good, and what actually lets some optimisers keep repeating strong performance while others can't- How battery revenue has shifted over time — from grid-support services, to adjusting trades as markets move, to buying and selling across multiple markets at once — and why each edge shrinks as more batteries chase it- Why pricing a battery deal is nothing like pricing a financial instrument, and how modelling different future scenarios (rather than simple averages) reveals the real value of holding a diversified portfolio- What project developers are actually asking optimisers for now — performance guarantees, profit shares, protection from regulatory changes — and why some of those guarantees aren't realistically workable- Which European markets look most promising for battery growth next, and how emerging grid restrictions could shape how much value new assets are able to captureWant to know how flexible connection agreements or grid restrictions are changing your battery's revenue forecast? Ask Ko, Modo Energy's AI analystChapters:0:00 – Battery Storage Returns Are Saturating1:04 – Battery Optimisation Operational Excellence2:22 – Repeatable Battery Storage Returns5:43 – Ancillary Services Revenue Saturation8:14 – Battery Optimiser Performance Benchmarks10:08 – Small Vs Large Battery Trading Teams14:25 – AI In Energy Trading16:29 – Autonomous AI Battery Trading Risks18:40 – Extreme Weather Impact On Energy Trading21:49 – Best European Battery Storage Markets24:13 – Battery Storage Toll Pricing28:59 – Battery Portfolio Diversification Strategy31:36 – Flexible Connection Agreements Explained35:51 – Battery Storage Investment Guarantees38:30 – Battery Storage And Grid Transmission

This summer, Britain recorded its first ever four consecutive months of 35°C+ heat and according to the Climate Change Committee, the UK isn't ready for it, physically or emotionally. As political pressure mounts in the net zero debate over whether Britain should slow its climate transition, the CCC's chief executive makes the case that affordability and climate action are the same fight, not competing priorities. Ed sits down with Emma Pinchbeck, Chief Executive of the Climate Change Committee (CCC), to find out what preparing for a hotter Britain actually looks like, and why extreme heat has quietly overtaken flooding as the institution's top adaptation concern.They cover:Why extreme heat is now one of the CCC's top adaptation recommendations, with up to 92% of UK homes at risk of overheating by 2050.How solar and battery storage naturally track cooling demand, and why that strengthens the case for air conditioning becoming standard in UK homes.Emma's case for accelerating rather than easing off decarbonisation, including data showing EV- and solar-equipped homes can save up to £1,900 a year on energy costs.Why UK electricity is priced roughly 4x higher than gas, well above the 2:1 ratio in countries that have successfully rolled out heat pumps.Why Emma argues cost-of-living and climate policy are "the same question," not competing priorities.Want to know why UK electricity prices are 4x higher than gas, and how that compares to countries where heat pumps have taken off? Ask Ko, Modo Energy's AI Analyst, for the market-by-market breakdown. Try Ko for freeTranscript available here: Chapters: 0:00 Britain's Record-Breaking Heat1:16 The CCC's Real Role vs. Government Policy2:55 The Net Zero Speed Debate: Science and Political Pressure4:38 Electrification and Household Energy Savings9:55 Why UK Electricity Costs Four Times More Than Gas12:57 Extreme Heat and the Case for Home Cooling15:47 Solar, Batteries, and the Summer Cooling Demand Curve17:34 Gas as a Strategic Reserve for Grid Security22:43 The True Cost of Net Zero: £6.9 Trillion in Investment25:20 Financing the Transition: Levies and Smoothing Costs29:05 Why Demand Matters More Than Supply31:03 Industrial Policy: Grangemouth, Port Talbot, and Manufacturing35:27 Emma's Contrarian View: Cost and Climate as One Question38:28 Closing Thoughts and Sign-OffMusic licensed via Artlist.

This summer, Britain recorded its first ever four consecutive months of 35°C+ heat and according to the Climate Change Committee, the UK isn't ready for it, physically or emotionally. As political pressure mounts in the net zero debate over whether Britain should slow its climate transition, the CCC's chief executive makes the case that affordability and climate action are the same fight, not competing priorities. Ed sits down with Emma Pinchbeck, Chief Executive of the Climate Change Committee (CCC), to find out what preparing for a hotter Britain actually looks like, and why extreme heat has quietly overtaken flooding as the institution's top adaptation concern.They cover:Why extreme heat is now one of the CCC's top adaptation recommendations, with up to 92% of UK homes at risk of overheating by 2050.How solar and battery storage naturally track cooling demand, and why that strengthens the case for air conditioning becoming standard in UK homes.Emma's case for accelerating rather than easing off decarbonisation, including data showing EV- and solar-equipped homes can save up to £1,900 a year on energy costs.Why UK electricity is priced roughly 4x higher than gas, well above the 2:1 ratio in countries that have successfully rolled out heat pumps.Why Emma argues cost-of-living and climate policy are "the same question," not competing priorities.Want to know why UK electricity prices are 4x higher than gas, and how that compares to countries where heat pumps have taken off? Ask Ko, Modo Energy's AI Analyst, for the market-by-market breakdown. Try Ko for freeTranscript available here: Chapters: 0:00 Britain's Record-Breaking Heat1:16 The CCC's Real Role vs. Government Policy2:55 The Net Zero Speed Debate: Science and Political Pressure4:38 Electrification and Household Energy Savings9:55 Why UK Electricity Costs Four Times More Than Gas12:57 Extreme Heat and the Case for Home Cooling15:47 Solar, Batteries, and the Summer Cooling Demand Curve17:34 Gas as a Strategic Reserve for Grid Security22:43 The True Cost of Net Zero: £6.9 Trillion in Investment25:20 Financing the Transition: Levies and Smoothing Costs29:05 Why Demand Matters More Than Supply31:03 Industrial Policy: Grangemouth, Port Talbot, and Manufacturing35:27 Emma's Contrarian View: Cost and Climate as One Question38:28 Closing Thoughts and Sign-OffMusic licensed via Artlist.

Poland has cut coal's share of power generation from 95% to roughly 55% in a decade, with renewables generating over 30% of the country's power last year. That mismatch is already producing negative prices and turning battery storage into one of the country's biggest investment opportunities.Ed is joined by Tomasz Sęk, Founder and COO of R.Power Renewables, which holds a 1.7GW / 6.3GWh capacity-market-secured storage portfolio, one of the largest in Poland, to unpack how the country's power market is transforming.They cover:- Why coal's inflexibility, not its shrinking market share, is now Poland's biggest driver of negative prices and battery arbitrage.- How Poland's capacity market is evolving as de-rating factors and CapEx fall together, and what that means for the next wave of battery investment.- Why R.Power blends floor-plus-profit-share deals — including its new Axpo agreement — with full-toll contracts to balance risk and upside- How solar PPAs are evolving into Hybrid PPAs, as corporates like Amazon and Cisco look for more flexible, peak-shifted power- How R.Power plans to bring its 1.7GW / 6.3GWh capacity-market-secured portfolio online within 18–24 months, and what's setting the paceWant to go deeper on the Polish power market? Ask Ko, Modo Energy's AI analyst, for the latest on Polish battery revenues, capacity market results, and grid dynamics: https://modoenergy.com/product/ko?utm_source=podcast&utm_medium=podcast_apps&utm_campaign=tomasz_sek&utm_content=ko_signupChapters: 0:00 Introduction 1:08 Poland's Coal-to-Renewables Shift 1:57 Perception vs Reality of Poland's Energy Mix 4:52 Negative Prices and Coal's Inflexibility 5:58 Gas Peakers vs Battery Storage 7:45 Poland's Vertically Integrated Power Market 8:46 Day-Ahead vs Intraday Trading in Poland 9:54 Choosing a Route-to-Market Partner 12:06 Capacity Market Explained 13:21 R.Power's 1.7GW / 6.3GWh Portfolio 13:57 De-Rating Factors and Falling CapEx 17:00 Dunkelflaute and the Case for Gas 17:21 The Axpo Deal: Floor Plus Profit Share 19:51 Solar PPAs and the Rise of Hybrid PPAs 20:26 Multi-Technology PPAs and Peak Shifting 22:00 What's Slowing Poland's BESS Rollout 23:46 Poland's Grid Queue vs Texas and China 24:51 One Regulatory Fix: Faster Auctions 26:50 Poland's Cost Advantage

Poland has cut coal's share of power generation from 95% to roughly 55% in a decade, with renewables generating over 30% of the country's power last year. That mismatch is already producing negative prices and turning battery storage into one of the country's biggest investment opportunities.Ed is joined by Tomasz Sęk, Founder and COO of R.Power Renewables, which holds a 1.7GW / 6.3GWh capacity-market-secured storage portfolio, one of the largest in Poland, to unpack how the country's power market is transforming.They cover:- Why coal's inflexibility, not its shrinking market share, is now Poland's biggest driver of negative prices and battery arbitrage.- How Poland's capacity market is evolving as de-rating factors and CapEx fall together, and what that means for the next wave of battery investment.- Why R.Power blends floor-plus-profit-share deals — including its new Axpo agreement — with full-toll contracts to balance risk and upside- How solar PPAs are evolving into Hybrid PPAs, as corporates like Amazon and Cisco look for more flexible, peak-shifted power- How R.Power plans to bring its 1.7GW / 6.3GWh capacity-market-secured portfolio online within 18–24 months, and what's setting the paceWant to go deeper on the Polish power market? Ask Ko, Modo Energy's AI analyst, for the latest on Polish battery revenues, capacity market results, and grid dynamics.Transcript available hereChapters: 0:00 Introduction 1:08 Poland's Coal-to-Renewables Shift 1:57 Perception vs Reality of Poland's Energy Mix 4:52 Negative Prices and Coal's Inflexibility 5:58 Gas Peakers vs Battery Storage 7:45 Poland's Vertically Integrated Power Market 8:46 Day-Ahead vs Intraday Trading in Poland 9:54 Choosing a Route-to-Market Partner 12:06 Capacity Market Explained 13:21 R.Power's 1.7GW / 6.3GWh Portfolio 13:57 De-Rating Factors and Falling CapEx 17:00 Dunkelflaute and the Case for Gas 17:21 The Axpo Deal: Floor Plus Profit Share 19:51 Solar PPAs and the Rise of Hybrid PPAs 20:26 Multi-Technology PPAs and Peak Shifting 22:00 What's Slowing Poland's BESS Rollout 23:46 Poland's Grid Queue vs Texas and China 24:51 One Regulatory Fix: Faster Auctions 26:50 Poland's Cost Advantage

Most people assume Great Britain's grid connection queue works on a first come, first served basis. It doesn't - and that misconception is costing developers time and money. Connections reform was meant to bring clarity to the queue, but projects that were declared protected and pushed to the front are still missing their connection dates, and new contract disputes are now stalling projects that should already be moving. It all comes down to what actually gets built — and whether Britain can get anywhere close to Clean Power 2030.Catherine Cleary, Specialist Connections Engineer at Roadnight Taylor and a returning Transmission guest, joins Ed Porter to unpack what's really determining who connects to the grid, and when.They cover:- Why the grid connection queue isn't ordered by application date and how a 20MW battery project can end up waiting behind a nuclear power station for the same network reinforcements.- Why gate two offers under TMO4+ are going out with technical errors, and why fixing something as small as a typo can take months once you're one of hundreds of affected projects.- Why NESO's oversubscription numbers might be the wrong problem to solve, and what bay sharing could do instead.- Why data centres and other demand customers are pushing for independent transmission owner (ITO) status, and what Ofgem's latest signal means for future connections.- Catherine's contrarian take after 15 years in the industry: why Britain might be about to build too much grid, not too little.Want to go deeper on grid connections and battery build-out? Sign up for free to Ko, Modo Energy's AI analyst https://modoenergy.com/product/ko?utm_source=podcast&utm_medium=podcast_apps&utm_campaign=catherine_cleary&utm_content=ko_signupChapters:0:00 Introduction1:13 Two myths about the grid connection queue2:05 Queue order vs. connection order: nuclear vs. battery example3:34 The 4.9MW de minimis threshold loophole4:12 TMO4+ and connections reform: from design exercise to rollout6:41 Gate two offer errors and technical query delays9:05 Clean Power 2030 deliverability under connections reform13:37 Engineering capacity for 30GW of battery storage16:01 Bay sharing and hybrid project connections17:49 CMP470: the oversubscribed technology commitment fee22:04 Co-location, AC/DC coupling and TMO4+ shortcomings for hybrids25:15 Fixing TMO4+ for hybrids: the parent/child concept28:05 Data centre and demand connections vs. generation33:39 Politics, policy and the connections queue36:35 Contract delays: the new longest pole in the tent39:16 The case for independent transmission owners (ITOs)41:50 Contrarian view: are we building too much grid?

Most people assume Great Britain's grid connection queue works on a first come, first served basis. It doesn't - and that misconception is costing developers time and money. Connections reform was meant to bring clarity to the queue, but projects that were declared protected and pushed to the front are still missing their connection dates, and new contract disputes are now stalling projects that should already be moving. It all comes down to what actually gets built — and whether Britain can get anywhere close to Clean Power 2030.Catherine Cleary, Specialist Connections Engineer at Roadnight Taylor and a returning Transmission guest, joins Ed Porter to unpack what's really determining who connects to the grid, and when.They cover:- Why the grid connection queue isn't ordered by application date and how a 20MW battery project can end up waiting behind a nuclear power station for the same network reinforcements.- Why gate two offers under TMO4+ are going out with technical errors, and why fixing something as small as a typo can take months once you're one of hundreds of affected projects.- Why NESO's oversubscription numbers might be the wrong problem to solve, and what bay sharing could do instead.- Why data centres and other demand customers are pushing for independent transmission owner (ITO) status, and what Ofgem's latest signal means for future connections.- Catherine's contrarian take after 15 years in the industry: why Britain might be about to build too much grid, not too little.Want to go deeper on grid connections and battery build-out? Sign up for free to Ko, Modo Energy's AI analyst https://modoenergy.com/product/ko?utm_source=podcast&utm_medium=podcast_apps&utm_campaign=catherine_cleary&utm_content=ko_signupChapters:0:00 Introduction1:13 Two myths about the grid connection queue2:05 Queue order vs. connection order: nuclear vs. battery example3:34 The 4.9MW de minimis threshold loophole4:12 TMO4+ and connections reform: from design exercise to rollout6:41 Gate two offer errors and technical query delays9:05 Clean Power 2030 deliverability under connections reform13:37 Engineering capacity for 30GW of battery storage16:01 Bay sharing and hybrid project connections17:49 CMP470: the oversubscribed technology commitment fee22:04 Co-location, AC/DC coupling and TMO4+ shortcomings for hybrids25:15 Fixing TMO4+ for hybrids: the parent/child concept28:05 Data centre and demand connections vs. generation33:39 Politics, policy and the connections queue36:35 Contract delays: the new longest pole in the tent39:16 The case for independent transmission owners (ITOs)41:50 Contrarian view: are we building too much grid?

Battery storage costs have fallen by two-thirds since 2022 and the cell chemistry currently dominates the grid barely existed at scale five years ago, and the same disruption could be about to happen again. Meanwhile, the supplier market is fragmenting rather than consolidating and the biggest names today aren't guaranteed to stay on top.Marek Kubik has watched these shifts happen from inside the industry since the early days. He joins Ed to explain why the balance of power in battery storage keeps changing, and what's coming next.They coverWhy battery storage costs have fallen two-thirds since 2022 - and why that could be about to reverse.The real reason CATL's battery market share has dropped from 32% to 20%.Why sodium-ion batteries could repeat LFP's rapid takeover of grid-scale storage.How battery container design is changing again, from bigger cells to taller stacks.The battery duration limit everyone assumed was fixed - until 16-18 hour systems broke it.Want to dig deeper into battery cell chemistry and pricing trends? Ask Ko, Modo Energy's AI analystChapters00:00 Introduction01:50 Saudi Arabia battery storage market update02:16 UAE 24/7 renewable energy project03:18 Solar plus battery storage economics explained05:10 Battery storage prices: are we near the floor?06:38 Lithium carbonate prices and battery raw material costs08:22 Battery storage cost per kilowatt-hour explained11:07 China battery prices and the race to $50/kWh13:36 Sodium-ion batteries vs LFP: the next chemistry shift21:18 CATL market share and battery supply chain competition26:14 Battery procurement trends and container design innovation29:39 Battery storage service, warranties and spare parts30:54 Lessons from a decade in battery storage32:09 Long duration energy storage and the Ofgem LDES scheme34:48 How much renewable energy storage is enough?38:18 Flow batteries, iron-air and CO2 energy storage39:32 Sodium-ion's future in grid-scale battery storage

Battery storage costs have fallen by two-thirds since 2022 and the cell chemistry currently dominates the grid barely existed at scale five years ago, and the same disruption could be about to happen again. Meanwhile, the supplier market is fragmenting rather than consolidating and the biggest names today aren't guaranteed to stay on top.Marek Kubik has watched these shifts happen from inside the industry since the early days. He joins Ed to explain why the balance of power in battery storage keeps changing, and what's coming next.They coverWhy battery storage costs have fallen two-thirds since 2022 - and why that could be about to reverse.The real reason CATL's battery market share has dropped from 32% to 20%.Why sodium-ion batteries could repeat LFP's rapid takeover of grid-scale storage.How battery container design is changing again, from bigger cells to taller stacks.The battery duration limit everyone assumed was fixed - until 16-18 hour systems broke it.Want to dig deeper into battery cell chemistry and pricing trends? Ask Ko, Modo Energy's AI analyst:Read the companion article: [companion article link — TBC]Chapters00:00 Introduction01:50 Saudi Arabia battery storage market update02:16 UAE 24/7 renewable energy project03:18 Solar plus battery storage economics explained05:10 Battery storage prices: are we near the floor?06:38 Lithium carbonate prices and battery raw material costs08:22 Battery storage cost per kilowatt-hour explained11:07 China battery prices and the race to $50/kWh13:36 Sodium-ion batteries vs LFP: the next chemistry shift21:18 CATL market share and battery supply chain competition26:14 Battery procurement trends and container design innovation29:39 Battery storage service, warranties and spare parts30:54 Lessons from a decade in battery storage32:09 Long duration energy storage and the Ofgem LDES scheme34:48 How much renewable energy storage is enough?38:18 Flow batteries, iron-air and CO2 energy storage39:32 Sodium-ion's future in grid-scale battery storage

GB Energy's £1 million solar investment freed up savings a Hull hospital had left on the table for years. It's an example of what can happen when a state-backed investor takes risks the market won't. GB Energy calls itself an activist investor, built to put public money behind the frontiers where private capital moves too slowly: deepwater wind, long duration storage, public sector solar. The interesting question now is how far this model can scale, and how well it keeps sharing that risk with private capital as it grows.Dan McGrail, CEO of Great British Energy, joins Ed Porter to explain how Britain's state-owned energy company decides where to invest, and why it's taking on the risks private money won't take first.They cover: - Why the "activist investor" model can justify riskier bets than pure-return investors would take - and where that logic stops making sense- How to identify an investment "frontier": the areas of high ambition where private capital isn't moving fast enough to hit national targets- What a queue of 50GW+ in unsolicited co-investment enquiries reveals about investor appetite for state-backed risk-sharing- Why community-owned local energy can outperform national schemes on economic impact - one Orkney turbine now funds housing, buses and insulation- Why chasing niche global market share, not local content quotas, may be the smarter industrial strategy for competing with ChinaGot a question about the build-out of batteries, solar or wind in GB or Europe? That's what Ko is for - sign up to try for free.Transcript available hereYou can watch or listen to new episodes every Tuesday. Transmission is a Modo Energy production. Your host is Ed Porter - Director EMEA & APAC at Modo Energy.Chapters00:00 £1m Solar Saving At A Hull Hospital00:43 Guest Introduction: Dan McGrail, CEO Of GB Energy01:11 GB Energy's Company Model And DESNZ Ownership02:42 Investment Committee Discipline Vs Government Thinking03:23 The "Frontiers" Strategy Explained07:44 Floating Wind And The Deepwater Frontier09:03 ScotWind, Rising Costs And Investor Confidence12:33 Three Strategic Pillars: Offshore, Onshore, Local19:56 Public Entrepreneurship Vs Maximising Profit21:17 The Siemens Story: Why Private Capital Wants In22:35 50GW Of Unsolicited Investment Enquiries26:00 Electrically Qualified Workers And The Skills Gap30:45 Shapinsay's Community-Owned Wind Turbine34:34 Solar On Hospitals And Schools37:16 Balancing Solar With Battery Storage39:56 GB Energy's £8.3 Billion Budget: Progress So Far41:14 Contrarian View: Industrial Legacy Over Cheap Energy

GB Energy's £1 million solar investment freed up savings a Hull hospital had left on the table for years. It's an example of what can happen when a state-backed investor takes risks the market won't. GB Energy calls itself an activist investor, built to put public money behind the frontiers where private capital moves too slowly: deepwater wind, long duration storage, public sector solar. The interesting question now is how far this model can scale, and how well it keeps sharing that risk with private capital as it grows.Dan McGrail, CEO of Great British Energy, joins Ed Porter to explain how Britain's state-owned energy company decides where to invest, and why it's taking on the risks private money won't take first.They cover: - Why the "activist investor" model can justify riskier bets than pure-return investors would take - and where that logic stops making sense- How to identify an investment "frontier": the areas of high ambition where private capital isn't moving fast enough to hit national targets- What a queue of 50GW+ in unsolicited co-investment enquiries reveals about investor appetite for state-backed risk-sharing- Why community-owned local energy can outperform national schemes on economic impact - one Orkney turbine now funds housing, buses and insulation- Why chasing niche global market share, not local content quotas, may be the smarter industrial strategy for competing with ChinaGot a question about the build-out of batteries, solar or wind in GB or Europe? That's what Ko is for - sign up to try for free.Transcript available hereYou can watch or listen to new episodes every Tuesday. Transmission is a Modo Energy production. Your host is Ed Porter - Director EMEA & APAC at Modo Energy.Chapters00:00 £1m Solar Saving At A Hull Hospital00:43 Guest Introduction: Dan McGrail, CEO Of GB Energy01:11 GB Energy's Company Model And DESNZ Ownership02:42 Investment Committee Discipline Vs Government Thinking03:23 The "Frontiers" Strategy Explained07:44 Floating Wind And The Deepwater Frontier09:03 ScotWind, Rising Costs And Investor Confidence12:33 Three Strategic Pillars: Offshore, Onshore, Local19:56 Public Entrepreneurship Vs Maximising Profit21:17 The Siemens Story: Why Private Capital Wants In22:35 50GW Of Unsolicited Investment Enquiries26:00 Electrically Qualified Workers And The Skills Gap30:45 Shapinsay's Community-Owned Wind Turbine34:34 Solar On Hospitals And Schools37:16 Balancing Solar With Battery Storage39:56 GB Energy's £8.3 Billion Budget: Progress So Far41:14 Contrarian View: Industrial Legacy Over Cheap Energy

Germany looks like Europe's most attractive battery storage market on paper: deep power price volatility, a fast-growing renewables build-out, and nearly three gigawatts of batteries already live. In reality, developers are navigating uncertain grid connection queues, gruelling commissioning phases, and a tolling market still working out how much risk is fair to price in.Christina Hepp, Director Strategy, and Leandra Boes, Director Asset Management, both at Green Flexibility, join Ed Porter to unpack what building and operating batteries in Germany actually looks like once the PowerPoint slide meets the grid.They cover:- What a Flexible Connection Agreement actually is and why this kind of trade-off is fast becoming the norm in Germany.- Why grid operators and battery companies have historically struggled to "speak the same language", and how a shared framework like REGIOlink helps translate one side's needs into the other's terms.- What actually happens in the final weeks before a large-scale battery switches on for real: the software integration, testing and last-minute troubleshooting that never makes it into a press release.- Why choosing to sell power on the open market versus locking in a steadier, pre-agreed deal is a much bigger and riskier decision than it sounds - and why Green Flexibility is betting on the option most peers shy away from.- Just how enormous Germany's battery storage pipeline has become: enough grid connection requests queued up that regulators have had to start filtering out the projects that aren't actually going to happen.Want the data behind this conversation? Ask Ko, Modo Energy's AI analyst:https://modoenergy.com/sign-up?utm_source=podcast&utm_medium=podcast_apps&utm_campaign=green-flexibility&utm_content=ko_signupChapters:00:00 Introduction01:20 Common Misconceptions About Building Batteries in Germany02:24 FID Prep and Commissioning: What Doesn't Make the Press Release03:25 Flexible Connection Agreements (FCAs): The Ski Cannon Example07:54 Germany's FCA Market Standardization10:36 Battery Commissioning in Germany: Lessons From the Toughest Phase14:29 Merchant vs Tolling: Germany's Battery Revenue Models19:30 REGIOlink: Integrating Batteries Into Distribution Grids23:11 Battery Data Sharing With Grid Operators26:27 Germany's Project Development Shakeout29:32 Co-Located Battery Projects: Pros and Cons31:47 Germany's Zonal Pricing Debate for Batteries34:32 Contrarian Views: Merchant Strategy and the German Power Market as "Barbie"

Germany looks like Europe's most attractive battery storage market on paper: deep power price volatility, a fast-growing renewables build-out, and nearly three gigawatts of batteries already live. In reality, developers are navigating uncertain grid connection queues, gruelling commissioning phases, and a tolling market still working out how much risk is fair to price in.Christina Hepp, Director Strategy, and Leandra Boes, Director Asset Management, both at Green Flexibility, join Ed Porter to unpack what building and operating batteries in Germany actually looks like once the PowerPoint slide meets the grid.They cover:- What a Flexible Connection Agreement actually is and why this kind of trade-off is fast becoming the norm in Germany.- Why grid operators and battery companies have historically struggled to "speak the same language", and how a shared framework like REGIOlink helps translate one side's needs into the other's terms.- What actually happens in the final weeks before a large-scale battery switches on for real: the software integration, testing and last-minute troubleshooting that never makes it into a press release.- Why choosing to sell power on the open market versus locking in a steadier, pre-agreed deal is a much bigger and riskier decision than it sounds - and why Green Flexibility is betting on the option most peers shy away from.- Just how enormous Germany's battery storage pipeline has become: enough grid connection requests queued up that regulators have had to start filtering out the projects that aren't actually going to happen.Want the data behind this conversation? Ask Ko, Modo Energy's AI analyst:https://modoenergy.com/sign-up?utm_source=podcast&utm_medium=podcast_apps&utm_campaign=green-flexibility&utm_content=ko_signupChapters:00:00 Introduction01:20 Common Misconceptions About Building Batteries in Germany02:24 FID Prep and Commissioning: What Doesn't Make the Press Release03:25 Flexible Connection Agreements (FCAs): The Ski Cannon Example07:54 Germany's FCA Market Standardization10:36 Battery Commissioning in Germany: Lessons From the Toughest Phase14:29 Merchant vs Tolling: Germany's Battery Revenue Models19:30 REGIOlink: Integrating Batteries Into Distribution Grids23:11 Battery Data Sharing With Grid Operators26:27 Germany's Project Development Shakeout29:32 Co-Located Battery Projects: Pros and Cons31:47 Germany's Zonal Pricing Debate for Batteries34:32 Contrarian Views: Merchant Strategy and the German Power Market as "Barbie"

Many people picture a power purchase agreement as a 15-year mega-deal between a tech giant and a solar farm. In reality, 99% of UK PPAs look nothing like that. Power purchase agreements now sit behind a growing chunk of how the UK's electricity supply is sourced, and getting the price wrong could mean getting locked in well above the market rate for years.Ed sits down with Rob Ogden, Founder and CEO of Renewable Exchange - one of the UK's largest PPA marketplaces - to unpack how PPAs are actually priced, why REGO certificate prices have swung from over £20 to just a few pence, and what happens to Europe's ageing wind fleet as 20-year subsidies run out and thousands of turbines are pushed onto the merchant market.They cover:Why the "blue-chip" corporate PPA is the exception in a UK market dominated by short-term utility contracts, and how subsidy schemes from NFFO to CfD shaped that split.How negative and volatile power prices are forcing generators and off-takers to rethink how PPAs are priced and structured.The lessons from Covid and the Ukraine energy crisis on why locking into a 15-year PPA carries real pricing risk.Why matching thousands of small renewable generators with energy suppliers is such a hard problem to solve, and what it takes to build pricing infrastructure that can handle PPA demand spiking overnight.Why REGO prices have swung from over £20 to just a few pence, and the case for moving to 24/7 REGO matching.Want to see what future power prices look like right now? Head to Modo Energy and ask Ko, Modo Energy's AI analyst — sign-up's free and takes seconds.Transcript available here.Chapters00:00 Introduction: Is Your "100% Green" Tariff Really Green?01:15 What People Get Wrong About Power Purchase Agreements03:45 UK Power Purchase Agreement Market Structure04:57 UK Renewable Subsidy History: NFFO, RO, FiT and CfD07:16 PPA Regret: Negative Pricing and Value Erosion09:49 Long-Term PPA Risk Through Covid and the Ukraine Crisis14:32 Hybrid PPA and Flexibility Contract Structures17:46 Renewable Exchange Origin Story: The Aberdeenshire Wind Farmers19:53 Platform Scaling Pains: Rebuilding Three Times22:41 Renewable Exchange's Impact on Consumer Energy Costs24:30 Co-Located Solar and Battery Revenue Streams26:58 REGO Explained: Renewable Energy Guarantee of Origin32:16 The Case for 24/7 REGO Matching36:27 Expanding to Germany: Legacy Wind Assets and Repowering41:13 Contrarian Take: Ending Renewable Energy Subsidies

Many people picture a power purchase agreement as a 15-year mega-deal between a tech giant and a solar farm. In reality, 99% of UK PPAs look nothing like that. Power purchase agreements now sit behind a growing chunk of how the UK's electricity supply is sourced, and getting the price wrong could mean getting locked in well above the market rate for years.Ed sits down with Rob Ogden, Founder and CEO of Renewable Exchange - one of the UK's largest PPA marketplaces - to unpack how PPAs are actually priced, why REGO certificate prices have swung from over £20 to just a few pence, and what happens to Europe's ageing wind fleet as 20-year subsidies run out and thousands of turbines are pushed onto the merchant market.They cover:Why the "blue-chip" corporate PPA is the exception in a UK market dominated by short-term utility contracts, and how subsidy schemes from NFFO to CfD shaped that split.How negative and volatile power prices are forcing generators and off-takers to rethink how PPAs are priced and structured.The lessons from Covid and the Ukraine energy crisis on why locking into a 15-year PPA carries real pricing risk.Why matching thousands of small renewable generators with energy suppliers is such a hard problem to solve, and what it takes to build pricing infrastructure that can handle PPA demand spiking overnight.Why REGO prices have swung from over £20 to just a few pence, and the case for moving to 24/7 REGO matching.Want to see what future power prices look like right now? Head to Modo Energy and ask Ko, Modo Energy's AI analyst — sign-up's free and takes seconds.Chapters00:00 Introduction: Is Your "100% Green" Tariff Really Green?01:15 What People Get Wrong About Power Purchase Agreements03:45 UK Power Purchase Agreement Market Structure04:57 UK Renewable Subsidy History: NFFO, RO, FiT and CfD07:16 PPA Regret: Negative Pricing and Value Erosion09:49 Long-Term PPA Risk Through Covid and the Ukraine Crisis14:32 Hybrid PPA and Flexibility Contract Structures17:46 Renewable Exchange Origin Story: The Aberdeenshire Wind Farmers19:53 Platform Scaling Pains: Rebuilding Three Times22:41 Renewable Exchange's Impact on Consumer Energy Costs24:30 Co-Located Solar and Battery Revenue Streams26:58 REGO Explained: Renewable Energy Guarantee of Origin32:16 The Case for 24/7 REGO Matching36:27 Expanding to Germany: Legacy Wind Assets and Repowering41:13 Contrarian Take: Ending Renewable Energy Subsidies

How dangerous are battery storage fires, really? Despite the headlines, grid-scale battery fire failure rates have fallen 99% since 2018 - from around 4 incidents per gigawatt hour to under 0.1. Even as global deployment scaled into the tens of gigawatt hours. Most people still picture a whole site going up in flames. The engineering tells a very different story. Dan Sherlock-Burke, Director of Asset Management at Gore Street Capital, joins Ed Porter for a technical look at how battery fire safety actually works - from the Moss Landing fire that shaped public perception, to the data that can flag a failing module weeks before it fails. He explains what really happens minute-by-minute when a cell enters thermal runaway, why most BESS fires trace back to operations rather than faulty cells, and why fire suppression isn't always the safeguard it appears to be.They cover:- Battery fire propagation: why "let it burn" is increasingly viable, and how modern container design has made fires spreading across a site vanishingly rare- BESS fire statistics: how EPRI's failure incident database shows a fall from around 4 incidents per gigawatt hour in 2018 to under 0.1 today, a 99% reduction- What causes battery fires: why only ~11% start with a faulty cell, while ~65% trace back to operations and integration- LFP vs NMC battery chemistry: lower combustion temperatures, no self-supplied oxygen, and why lithium iron phosphate still isn't "inherently safe"- Battery fire suppression: the contrarian case for why the wrong system can turn a fire into an explosionAsk Ko, Modo Energy's AI analyst, about battery storage safety and fire risk: Get started now.Read the companion article here.You can watch or listen to new episodes every Tuesday. Transmission is a Modo Energy production. Your host is Ed Porter - Director EMEA & APAC at Modo Energy.0:00 - What everyone gets wrong about battery fires2:42 - Battery fire propagation and site design4:04 - Moss Landing fire: what actually happened7:04 - LFP vs NMC battery chemistry explained9:04 - Why lithium iron phosphate isn't "inherently safe"13:08 - Using data to catch thermal runaway early15:53 - EPRI's battery failure incident database16:27 - How battery fire rates fell 99% since 201818:58 - What causes battery fires: the 11% vs 65% split23:26 - Why most battery fires go unreported28:01 - Inside thermal runaway, minute by minute34:44 - Fire suppression and the explosion risk39:09 - The Liverpool battery fire41:11 - Rethinking battery fire suppression

How dangerous are battery storage fires, really? Despite the headlines, grid-scale battery fire failure rates have fallen 99% since 2018 - from around 4 incidents per gigawatt hour to under 0.1. Even as global deployment scaled into the tens of gigawatt hours. Most people still picture a whole site going up in flames. The engineering tells a very different story. Dan Sherlock-Burke, Director of Asset Management at Gore Street Capital, joins Ed Porter for a technical look at how battery fire safety actually works - from the Moss Landing fire that shaped public perception, to the data that can flag a failing module weeks before it fails. He explains what really happens minute-by-minute when a cell enters thermal runaway, why most BESS fires trace back to operations rather than faulty cells, and why fire suppression isn't always the safeguard it appears to be.They cover:- Battery fire propagation: why "let it burn" is increasingly viable, and how modern container design has made fires spreading across a site vanishingly rare- BESS fire statistics: how EPRI's failure incident database shows a fall from around 4 incidents per gigawatt hour in 2018 to under 0.1 today, a 99% reduction- What causes battery fires: why only ~11% start with a faulty cell, while ~65% trace back to operations and integration- LFP vs NMC battery chemistry: lower combustion temperatures, no self-supplied oxygen, and why lithium iron phosphate still isn't "inherently safe"- Battery fire suppression: the contrarian case for why the wrong system can turn a fire into an explosionAsk Ko, Modo Energy's AI analyst, about battery storage safety and fire risk. Get started now.You can watch or listen to new episodes every Tuesday. Transmission is a Modo Energy production. Your host is Ed Porter - Director EMEA & APAC at Modo Energy.0:00 - What everyone gets wrong about battery fires2:42 - Battery fire propagation and site design4:04 - Moss Landing fire: what actually happened7:04 - LFP vs NMC battery chemistry explained9:04 - Why lithium iron phosphate isn't "inherently safe"13:08 - Using data to catch thermal runaway early15:53 - EPRI's battery failure incident database16:27 - How battery fire rates fell 99% since 201818:58 - What causes battery fires: the 11% vs 65% split23:26 - Why most battery fires go unreported28:01 - Inside thermal runaway, minute by minute34:44 - Fire suppression and the explosion risk39:09 - The Liverpool battery fire41:11 - Rethinking battery fire suppression

The atmosphere is unpredictable, and weather forecasts are far more reliable on some days than others. For anyone trading power or gas across Europe, knowing the difference is everything. It's what separates a confident call from an expensive guess. In this conversation, Ed is joined by Matt Dobson - Head of European Energy Forecasting and Emma Patmore, Energy Meteorologist from MetDesk. They walk us through when they can trust what they're seeing and when they can't, and how they turn an uncertain forecast into something traders can actually act on. Along the way they cover wind droughts (or Dunkelflaute), a possible record El Niño, river levels that shut down power stations, and the rise of AI weather modelsThey cover- How weather forecast accuracy isn't fixed: Why a day-ahead wind forecast lands within 10–15% around 80% of the time, but a shifted low-pressure track can swing output 30–40%.- Dunkelflaute explained: How a blocking high-pressure system causes a wind drought, and why the longest recent German event ran nine days in early November 2024.- El Niño and energy markets: Why a milder autumn means lower heating demand and gives traders reason to sell Q4 gas.- AI weather models vs traditional models: why AI is pulling ahead at the 10–20 day horizon while traditional models stay sharper on fine-scale detail.- Heatwaves and nuclear power: How 40°C heat in France and low river levels force nuclear curtailment and Rhine freight limits, echoing 2022.Want to see how weather is moving European power and gas prices right now? Ask Ko, Modo Energy's AI analyst: Free sign up: https://modoenergy.com/sign-up?utm_source=podcast&utm_medium=podcast_apps&utm_campaign=metdesk&utm_content=ko_signupRead the companion article here.You can watch or listen to new episodes every Tuesday. Transmission is a Modo Energy production. Your host is Ed Porter - Director EMEA & APAC at Modo Energy.Chapters0:00 - How weather forecasting drives energy markets1:01 - What everyone gets wrong about weather forecasting1:26 - Why forecast accuracy changes with the time horizon4:03 - Saharan dust and solar power generation6:02 - How weather varies over short distances7:11 - Dunkelflaute explained: wind drought conditions8:20 - German wind power and the nine-day wind drought11:08 - Teleconnections: El Nino, ENSO and the MJO12:54 - Record El Nino forecast and what it means17:30 - Trading El Nino: gas, hydro and Alpine snow17:56 - Why traders go short Q4 gas18:58 - ECMWF data and ensemble forecasting19:35 - How weather ensembles work: 151 members21:39 - AI weather models vs traditional forecasting23:25 - Are weather forecasts getting more accurate?26:17 - Climate change and weather forecasting27:50 - French heatwaves and nuclear power curtailment31:10 - Low Rhine levels and freight restrictions33:11 - The polar vortex and sudden stratospheric warming36:15 - The Beast from the East explained

The atmosphere is unpredictable, and weather forecasts are far more reliable on some days than others. For anyone trading power or gas across Europe, knowing the difference is everything. It's what separates a confident call from an expensive guess. In this conversation, Ed is joined by Matt Dobson - Head of European Energy Forecasting and Emma Patmore, Energy Meteorologist from MetDesk. They walk us through when they can trust what they're seeing and when they can't, and how they turn an uncertain forecast into something traders can actually act on. Along the way they cover wind droughts (or Dunkelflaute), a possible record El Niño, river levels that shut down power stations, and the rise of AI weather modelsThey cover- How weather forecast accuracy isn't fixed: Why a day-ahead wind forecast lands within 10–15% around 80% of the time, but a shifted low-pressure track can swing output 30–40%.- Dunkelflaute explained: How a blocking high-pressure system causes a wind drought, and why the longest recent German event ran nine days in early November 2024.- El Niño and energy markets: Why a milder autumn means lower heating demand and gives traders reason to sell Q4 gas.- AI weather models vs traditional models: why AI is pulling ahead at the 10–20 day horizon while traditional models stay sharper on fine-scale detail.- Heatwaves and nuclear power: How 40°C heat in France and low river levels force nuclear curtailment and Rhine freight limits, echoing 2022.Want to see how weather is moving European power and gas prices right now? Ask Ko, Modo Energy's AI analyst: Free sign up: https://modoenergy.com/sign-up?utm_source=podcast&utm_medium=podcast_apps&utm_campaign=metdesk&utm_content=ko_signupRead the companion article hereYou can watch or listen to new episodes every Tuesday. Transmission is a Modo Energy production. Your host is Ed Porter - Director EMEA & APAC at Modo Energy.Chapters0:00 - How weather forecasting drives energy markets1:01 - What everyone gets wrong about weather forecasting1:26 - Why forecast accuracy changes with the time horizon4:03 - Saharan dust and solar power generation6:02 - How weather varies over short distances7:11 - Dunkelflaute explained: wind drought conditions8:20 - German wind power and the nine-day wind drought11:08 - Teleconnections: El Nino, ENSO and the MJO12:54 - Record El Nino forecast and what it means17:30 - Trading El Nino: gas, hydro and Alpine snow17:56 - Why traders go short Q4 gas18:58 - ECMWF data and ensemble forecasting19:35 - How weather ensembles work: 151 members21:39 - AI weather models vs traditional forecasting23:25 - Are weather forecasts getting more accurate?26:17 - Climate change and weather forecasting27:50 - French heatwaves and nuclear power curtailment31:10 - Low Rhine levels and freight restrictions33:11 - The polar vortex and sudden stratospheric warming36:15 - The Beast from the East explained

Two thirds of industrial energy demand is heat, not electricity, and most of it still runs on gas. Thermal storage converts cheap electricity into heat, stores it in concrete, and dispatches it when the factory needs it, undercutting the gas bill even though gas is cheaper per unit on average. Alex Robertson, CEO of ENERGYNEST, joins Ed Porter to explain how a thermal battery works, why it competes with lithium-ion on cost, and why grid connections - not the technology - are the real constraint on industrial decarbonisation.They cover:- Why thermal storage functions like a battery on the energy markets but stores heat one-way in optimised concrete.- The medium-temperature "frying, drying and applying" range (roughly 150 to 300C) that sits above heat pumps and below cement and steel.- How decoupling thermal demand from the electricity price typically can cut the gas bill by around 50%.- Why a 20-foot-container module stores about two megawatt hours, stacks three high, and loses only around 2% of capacity per day.- Why a flexible, interruptible asset is exactly what congested grids need - and why Germany still lacks the flexible connection framework the Netherlands is rolling out.Ask Ko, Modo Energy's AI analyst, any question from this conversation: https://modoenergy.com/sign-up?utm_source=podcast&utm_medium=podcast_apps&utm_campaign=Alex Robertson&utm_content=ko_signupRead the companion article: https://modoenergy.com/transmission-podcast/80ce6824-59a1-495b-9e94-0a38bdb9572e?utm_source=podcast&utm_medium=podcast_apps&utm_campaign=Alex Robertson&utm_content=article_pageModo Energy's solar and battery forecasts are live at modo.energy.You can watch or listen to new episodes every Tuesday. Transmission is a Modo Energy production. Your host is Ed Porter - Director EMEA & APAC at Modo Energy.Chapters 0:00 - Introduction0:11 - Industrial heat demand and the gas problem1:13 - One thing everyone gets wrong about thermal storage3:14 - How the concrete thermal battery works4:08 - Medium temperature heat and the customer profile6:56 - Why gas boilers still dominate German industry7:52 - Using storage to beat the gas price10:09 - Concrete versus lithium-ion: cost and supply chain13:10 - Degradation and the 25-year thermal capacity16:02 - Scaling up: module size and storage capacity16:40 - Daily cycling and storage duration economics19:50 - Seasonal variation and running gas in winter23:33 - Cost, savings and the five-year payback24:36 - The ideal customer and the grid connection test25:46 - Data centres, demand queues and grid congestion28:02 - Flexible connection agreements and the system design gap30:10 - Grid utilisation versus grid buildout33:34 - Heat as a service and unlocking investment36:04 - A contrarian view on industrial decarbonisationMusic licensed via Artlist.

Two thirds of industrial energy demand is heat, not electricity, and most of it still runs on gas. Thermal storage converts cheap electricity into heat, stores it in concrete, and dispatches it when the factory needs it, undercutting the gas bill even though gas is cheaper per unit on average. Alex Robertson, CEO of ENERGYNEST, joins Ed Porter to explain how a thermal battery works, why it competes with lithium-ion on cost, and why grid connections - not the technology - are the real constraint on industrial decarbonisation.They cover:- Why thermal storage functions like a battery on the energy markets but stores heat one-way in optimised concrete.- The medium-temperature "frying, drying and applying" range (roughly 150 to 300C) that sits above heat pumps and below cement and steel.- How decoupling thermal demand from the electricity price typically can cut the gas bill by around 50%.- Why a 20-foot-container module stores about two megawatt hours, stacks three high, and loses only around 2% of capacity per day.- Why a flexible, interruptible asset is exactly what congested grids need - and why Germany still lacks the flexible connection framework the Netherlands is rolling out.Ask Ko, Modo Energy's AI analyst, any question from this conversation: https://modoenergy.com/sign-up?utm_source=podcast&utm_medium=podcast_apps&utm_campaign=Alex Robertson&utm_content=ko_signupRead the companion article: https://modoenergy.com/transmission-podcast/80ce6824-59a1-495b-9e94-0a38bdb9572e?utm_source=podcast&utm_medium=podcast_apps&utm_campaign=Alex Robertson&utm_content=article_pageModo Energy's solar and battery forecasts are live at modo.energy.You can watch or listen to new episodes every Tuesday. Transmission is a Modo Energy production. Your host is Ed Porter - Director EMEA & APAC at Modo Energy.Chapters 0:00 - Introduction0:11 - Industrial heat demand and the gas problem1:13 - One thing everyone gets wrong about thermal storage3:14 - How the concrete thermal battery works4:08 - Medium temperature heat and the customer profile6:56 - Why gas boilers still dominate German industry7:52 - Using storage to beat the gas price10:09 - Concrete versus lithium-ion: cost and supply chain13:10 - Degradation and the 25-year thermal capacity16:02 - Scaling up: module size and storage capacity16:40 - Daily cycling and storage duration economics19:50 - Seasonal variation and running gas in winter23:33 - Cost, savings and the five-year payback24:36 - The ideal customer and the grid connection test25:46 - Data centres, demand queues and grid congestion28:02 - Flexible connection agreements and the system design gap30:10 - Grid utilisation versus grid buildout33:34 - Heat as a service and unlocking investment36:04 - A contrarian view on industrial decarbonisationMusic licensed via Artlist.

Germany's battery storage market is booming - but a saturation crunch is coming, and most investors aren't ready for it. The question is which revenue streams hold up, and which collapse the way they did in GB, Texas, and Australia.Ed sits down with Till Stehr, German Research Analyst, and Cosima from the Advisory Services Team at Modo Energy, to map the real structural drivers, and risks, behind German BESS returns.They cover: Why German battery saturation is closer than the market thinks - FCR is already saturated, with aFRR close behind.• Why German battery revenues near €200,000/MW/year for a two-hour system are more about timing than structure.• What makes Germany's intraday market the most liquid in Europe and the €1,000+/MWh spikes batteries feed on.• How flexible connection agreements are quietly reshaping returns, from ramp rates to export caps.• What German grid fees look like after the 2029 exemption and why dynamic fees are locational pricing through the back door.Got a question about the German BESS market? Ask Ko, Modo Energy's AI analyst: https://modoenergy.com/sign-up?utm_source=podcast&utm_medium=youtube&utm_campaign=till_cosima&utm_content=ko_signupChapters:00:00 – An Introduction tGermany's Battery Storage Market 00:50 – What Investors Get Wrong About Germany02:33 – Why Ancillary Services Saturate Fast03:47 – German Battery Revenues: €200k per MW05:24 – Structural Value: Solar and Intraday Trading06:30 – Redispatch Costs and Locational Pricing08:04 – FCR and aFRR Explained09:37 – Battery Saturation and the Overbuilt Ratio14:08 – Europe's Most Liquid Intraday Market18:50 – Battery Interconnection: Friend or Foe?21:52 – Negative Power Prices in Germany25:36 – Flexible Connection Agreements Explained32:19 – Battery Inertia and Grid-Forming Inverters35:53 – German Grid Fees: What's Announced40:37 – Contrarian Views: DSOs and Locational Pricing

Germany's battery storage market is booming - but a saturation crunch is coming, and most investors aren't ready for it. The question is which revenue streams hold up, and which collapse the way they did in GB, Texas, and Australia.Ed sits down with Till Stehr, German Research Analyst, and Cosima from the Advisory Services Team at Modo Energy, to map the real structural drivers, and risks, behind German BESS returns.They cover: Why German battery saturation is closer than the market thinks - FCR is already saturated, with aFRR close behind.• Why German battery revenues near €200,000/MW/year for a two-hour system are more about timing than structure.• What makes Germany's intraday market the most liquid in Europe and the €1,000+/MWh spikes batteries feed on.• How flexible connection agreements are quietly reshaping returns, from ramp rates to export caps.• What German grid fees look like after the 2029 exemption and why dynamic fees are locational pricing through the back door.Got a question about the German BESS market? Ask Ko, Modo Energy's AI analyst: https://modoenergy.com/sign-up?utm_source=podcast&utm_medium=youtube&utm_campaign=till_cosima&utm_content=ko_signupChapters:00:00 – An Introduction tGermany's Battery Storage Market 00:50 – What Investors Get Wrong About Germany02:33 – Why Ancillary Services Saturate Fast03:47 – German Battery Revenues: €200k per MW05:24 – Structural Value: Solar and Intraday Trading06:30 – Redispatch Costs and Locational Pricing08:04 – FCR and aFRR Explained09:37 – Battery Saturation and the Overbuilt Ratio14:08 – Europe's Most Liquid Intraday Market18:50 – Battery Interconnection: Friend or Foe?21:52 – Negative Power Prices in Germany25:36 – Flexible Connection Agreements Explained32:19 – Battery Inertia and Grid-Forming Inverters35:53 – German Grid Fees: What's Announced40:37 – Contrarian Views: DSOs and Locational Pricing

Most battery revenue projections stop at the day-ahead auction. But the optimisers running multi-gigawatt BESS portfolios argue that's where the money is being left on the table - re-trading a battery through intraday, balancing, and ancillary services can add 50% or more to revenue, and battery offtake structures like floors, tolls, and swaps only make sense once you understand how that value actually gets captured.In this episode of Transmission, Ed Porter sits down with Brian Lonn, Head of UK Flexibility at Statkraft, to break down how a multi-gigawatt battery optimisation desk actually trades batteries and the offtake structures it offers on top.They cover:How battery re-trading works in practice.How Statkraft scaled its GB flex portfolio from 22MW of intraday-active battery volume to ~4.5GW under contract and why this scale is the precondition for offering offtake at all.Why the battery optimisation market could consolidate and what that means for smaller optimisers and asset owners.How battery floors, tolls, and day-ahead swaps differ in tenor and purpose, with a working £/MW ballpark for each on a 2-hour battery.Brian's contrarian view on Clean Power 2030: why the real question for the GB power system is megawatt-hours, not megawatts.Want sharper answers on battery storage markets? Ko is Modo Energy's AI analyst, built on our underlying data and research. Ask Ko anything: https://modoenergy.com/sign-up?utm_source=podcast&utm_medium=youtube&utm_campaign=brian_lonn&utm_content=ko_signupRead the companion article: [COMPANION ARTICLE URL — TBC]You can watch or listen to new episodes every Tuesday. Transmission is a Modo Energy production. Your host is Ed Porter - Director EMEA & APAC at Modo Energy.00:00 Introduction01:06 What everyone gets wrong about battery asset optimisation05:14 Statkraft's GB flex portfolio — scaling to 4.5GW07:24 Inside a battery trading desk — the operational reality10:02 Re-trading explained — and the £100 to £150 worked example16:49 How algorithmic intraday battery trading has evolved19:50 Re-trading uplift — 50%+ over day-ahead-only battery revenue22:14 The balancing mechanism and NESO's role in battery dispatch29:58 Battery offtake structures — floors, tolls, and day-ahead swaps37:35 Co-location — solar and battery storage in the GB market45:36 How to break into battery asset optimisation and energy trading49:04 Brian's contrarian view — megawatts vs megawatt-hours50:03 Why battery augmentation matters for Clean Power 2030Music licensed via Artlist.

Most battery revenue projections stop at the day-ahead auction. But the optimisers running multi-gigawatt BESS portfolios argue that's where the money is being left on the table - re-trading a battery through intraday, balancing, and ancillary services can add 50% or more to revenue, and battery offtake structures like floors, tolls, and swaps only make sense once you understand how that value actually gets captured.In this episode of Transmission, Ed Porter sits down with Brian Lonn, Head of UK Flexibility at Statkraft, to break down how a multi-gigawatt battery optimisation desk actually trades batteries and the offtake structures it offers on top.They cover:How battery re-trading works in practice.How Statkraft scaled its GB flex portfolio from 22MW of intraday-active battery volume to ~4.5GW under contract and why this scale is the precondition for offering offtake at all.Why the battery optimisation market could consolidate and what that means for smaller optimisers and asset owners.How battery floors, tolls, and day-ahead swaps differ in tenor and purpose, with a working £/MW ballpark for each on a 2-hour battery.Brian's contrarian view on Clean Power 2030: why the real question for the GB power system is megawatt-hours, not megawatts.Want sharper answers on battery storage markets? Ko is Modo Energy's AI analyst, built on our underlying data and research. Ask Ko anything: https://modoenergy.com/sign-up?utm_source=podcast&utm_medium=youtube&utm_campaign=brian_lonn&utm_content=ko_signupRead the companion article: [COMPANION ARTICLE URL — TBC]You can watch or listen to new episodes every Tuesday. Transmission is a Modo Energy production. Your host is Ed Porter - Director EMEA & APAC at Modo Energy.00:00 Introduction01:06 What everyone gets wrong about battery asset optimisation05:14 Statkraft's GB flex portfolio — scaling to 4.5GW07:24 Inside a battery trading desk — the operational reality10:02 Re-trading explained — and the £100 to £150 worked example16:49 How algorithmic intraday battery trading has evolved19:50 Re-trading uplift — 50%+ over day-ahead-only battery revenue22:14 The balancing mechanism and NESO's role in battery dispatch29:58 Battery offtake structures — floors, tolls, and day-ahead swaps37:35 Co-location — solar and battery storage in the GB market45:36 How to break into battery asset optimisation and energy trading49:04 Brian's contrarian view — megawatts vs megawatt-hours50:03 Why battery augmentation matters for Clean Power 2030Music licensed via Artlist.

The scope of the National Energy System Operator - or NESO - has expanded from running the electricity system to planning Britain's whole energy system across electricity, gas and hydrogen, all while delivering connections reform and steering toward Clean Power 2030. That transformation is reshaping everything from how Britain plans its grid 20 years out to how it keeps the lights on tonight. Ed Porter is joined by Kayte O'Neill, Chief Operating Officer at the National Energy System Operator (NESO), for a wide-ranging conversation on the biggest changes in the GB power market: grid connections reform, the battery storage queue, zero-carbon grid operation, and the next wave of electricity market design.They cover:Connections reform and the UK grid queue — how NESO has cut the 800GW queue down to a deliverable pipeline and what Gate 2 means for developers over the next 12 months.The battery storage connections queue and how NESO is thinking about attrition, bay sharing and co-location.Zero-carbon operation of the GB grid and why gas plants still run on windy, sunny days (stability services, inertia, grid-forming inverters)NESO's expanded whole-system role - strategic planning across electricity, gas and hydrogen, and the Strategic Spatial Energy Plan (SSEP)Reformed National Pricing, data centre demand connections, AI in the control room, and the £40bn/year investment unlock at stake.Ask Ko, Modo Energy's AI energy analyst, your questions on UK grid operations and BESS markets: Sign up hereTranscript available hereHosted by Ed Porter, Director EMEA & APAC at Modo Energy.Chapters:00:00 - Intro: what people get wrong about NESO04:15 - NESO's new role in gas security of supply05:49 - The summer outlook and GB's low-demand operability problem07:48 - Why gas still runs on the GB grid on windy, sunny days09:49 - Stability services and the path to zero-carbon grid operation11:03 - The 97.7% zero-carbon record on 1 April 202512:40 - Stability pathfinders, inertia markets and grid-forming inverters17:04 - The winter challenge: gigawatts vs terawatt-hours21:33 - Connections reform: from 800GW to a deliverable grid23:54 - What connections reform means for developers next26:01 - The skilled-labour bottleneck behind grid build-out30:32 - Battery queue attrition and the BESS oversupply problem33:51 - The Strategic Spatial Energy Plan (SSEP)38:59 - Co-location and bay sharing: the unfinished reform44:35 - Reformed National Pricing and GB electricity market reform49:13 - Data, digital and AI in the NESO control room51:44 - The 2026 Operability Strategy Report and Markets Roadmap52:24 - A contrarian case for connections reformMusic licensed via Artlist.

The scope of the National Energy System Operator - or NESO - has expanded from running the electricity system to planning Britain's whole energy system across electricity, gas and hydrogen, all while delivering connections reform and steering toward Clean Power 2030. That transformation is reshaping everything from how Britain plans its grid 20 years out to how it keeps the lights on tonight. Ed Porter is joined by Kayte O'Neill, Chief Operating Officer at the National Energy System Operator (NESO), for a wide-ranging conversation on the biggest changes in the GB power market: grid connections reform, the battery storage queue, zero-carbon grid operation, and the next wave of electricity market design.They cover:Connections reform and the UK grid queue — how NESO has cut the 800GW queue down to a deliverable pipeline and what Gate 2 means for developers over the next 12 months.The battery storage connections queue and how NESO is thinking about attrition, bay sharing and co-location.Zero-carbon operation of the GB grid and why gas plants still run on windy, sunny days (stability services, inertia, grid-forming inverters)NESO's expanded whole-system role - strategic planning across electricity, gas and hydrogen, and the Strategic Spatial Energy Plan (SSEP)Reformed National Pricing, data centre demand connections, AI in the control room, and the £40bn/year investment unlock at stake.Ask Ko, Modo Energy's AI energy analyst, your questions on UK grid operations and BESS markets: Sign up hereTranscript available hereHosted by Ed Porter, Director EMEA & APAC at Modo Energy.Chapters:00:00 - Intro: what people get wrong about NESO04:15 - NESO's new role in gas security of supply05:49 - The summer outlook and GB's low-demand operability problem07:48 - Why gas still runs on the GB grid on windy, sunny days09:49 - Stability services and the path to zero-carbon grid operation11:03 - The 97.7% zero-carbon record on 1 April 202512:40 - Stability pathfinders, inertia markets and grid-forming inverters17:04 - The winter challenge: gigawatts vs terawatt-hours21:33 - Connections reform: from 800GW to a deliverable grid23:54 - What connections reform means for developers next26:01 - The skilled-labour bottleneck behind grid build-out30:32 - Battery queue attrition and the BESS oversupply problem33:51 - The Strategic Spatial Energy Plan (SSEP)38:59 - Co-location and bay sharing: the unfinished reform44:35 - Reformed National Pricing and GB electricity market reform49:13 - Data, digital and AI in the NESO control room51:44 - The 2026 Operability Strategy Report and Markets Roadmap52:24 - A contrarian case for connections reformMusic licensed via Artlist.

Three years ago, the best price for a ready-to-build solar project in Spain was €200,000 per megawatt — today it is €50,000. Batteries have moved the opposite way, with ready-to-build prices climbing to around €100,000 per megawatt and a 30GW pipeline now stacking up behind them.Ed Porter sits down with Carmen Izquierdo Serrano, founder of nTeaser, the renewable energy marketplace where many of Spain's BESS, solar, and co-located deals are transacting, to unpack what those numbers actually mean for investors entering the Spanish power market and how the post-blackout urgency, and bottlenecks in financing and labour will shape who wins the next phase of Spain's energy transitionThey cover:Why Spanish solar ready-to-build prices have collapsed from €200,000 to €50,000 per megawatt while battery prices have climbed to ~€100,000 per megawatt in the space of three yearsHow the 30GW Spain BESS pipeline stacks up against the ~3.5GW expected to be operating by 2030, and why Carmen thinks that operating-asset forecast is conservativeWhere the real bottleneck is for delivery - not developers or permits, but bank financing and the skilled labour needed to construct the projectsWhy Italy's BESS market has slowed after the first MACSE auction while Spain has accelerated, and what that means for capital allocation across Southern Europe.How buyer expectations on arbitrage revenues are likely to be cannibalised as more batteries enter the market, and which revenue streams banks will actually finance againstWant to go deeper on Spanish BESS revenues? Ko, Modo Energy's AI analyst, can walk you through asset-specific forecasts: https://modoenergy.com/sign-up?utm_source=podcast&utm_medium=youtube&utm_campaign=carmen_izquierdo&utm_content=ko_signupChapters:0:00 - Spain solar prices crashed from €200K to €50K per MW1:10 - Why the Spain BESS market is misunderstood2:35 - Spain's 30GW battery storage pipeline explained3:25 - Inside nTeaser: Spain's renewable energy M&A platform5:00 - Is the 3.5GW Spain battery forecast for 2030 too low?7:50 - Spain BESS bottlenecks: bank financing and labour10:00 - Who is buying Spanish battery projects in 202612:50 - Spain vs Italy BESS: the MACSE auction setback15:00 - Data centres and behind-the-meter co-location in Spain18:00 - When Spain battery projects become bankable19:30 - Spain capacity market timing and revenue impact20:30 - BESS arbitrage cannibalisation and revenue stacking21:45 - Poland, Romania, and BESS expansion across Europe23:30 - How nTeaser is changing European renewables M&ATransmission is a Modo Energy podcast hosted by Ed Porter, Director EMEA & APAC at Modo Energy.

Three years ago, the best price for a ready-to-build solar project in Spain was €200,000 per megawatt — today it is €50,000. Batteries have moved the opposite way, with ready-to-build prices climbing to around €100,000 per megawatt and a 30GW pipeline now stacking up behind them.Ed Porter sits down with Carmen Izquierdo Serrano, founder of nTeaser, the renewable energy marketplace where many of Spain's BESS, solar, and co-located deals are transacting, to unpack what those numbers actually mean for investors entering the Spanish power market and how the post-blackout urgency, and bottlenecks in financing and labour will shape who wins the next phase of Spain's energy transitionThey cover:Why Spanish solar ready-to-build prices have collapsed from €200,000 to €50,000 per megawatt while battery prices have climbed to ~€100,000 per megawatt in the space of three yearsHow the 30GW Spain BESS pipeline stacks up against the ~3.5GW expected to be operating by 2030, and why Carmen thinks that operating-asset forecast is conservativeWhere the real bottleneck is for delivery - not developers or permits, but bank financing and the skilled labour needed to construct the projectsWhy Italy's BESS market has slowed after the first MACSE auction while Spain has accelerated, and what that means for capital allocation across Southern Europe.How buyer expectations on arbitrage revenues are likely to be cannibalised as more batteries enter the market, and which revenue streams banks will actually finance againstWant to go deeper on Spanish BESS revenues? Ko, Modo Energy's AI analyst, can walk you through asset-specific forecasts: https://modoenergy.com/sign-up?utm_source=podcast&utm_medium=youtube&utm_campaign=carmen_izquierdo&utm_content=ko_signupChapters:0:00 - Spain solar prices crashed from €200K to €50K per MW1:10 - Why the Spain BESS market is misunderstood2:35 - Spain's 30GW battery storage pipeline explained3:25 - Inside nTeaser: Spain's renewable energy M&A platform5:00 - Is the 3.5GW Spain battery forecast for 2030 too low?7:50 - Spain BESS bottlenecks: bank financing and labour10:00 - Who is buying Spanish battery projects in 202612:50 - Spain vs Italy BESS: the MACSE auction setback15:00 - Data centres and behind-the-meter co-location in Spain18:00 - When Spain battery projects become bankable19:30 - Spain capacity market timing and revenue impact20:30 - BESS arbitrage cannibalisation and revenue stacking21:45 - Poland, Romania, and BESS expansion across Europe23:30 - How nTeaser is changing European renewables M&ATransmission is a Modo Energy podcast hosted by Ed Porter, Director EMEA & APAC at Modo Energy.

Chris Stark is leading the UK's Clean Power 2030 mission. As Head of Mission Control at DESNZ, no one sees the constraint costs, grid bottlenecks and reform of National Pricing trade-offs more clearly. The UK is building a clean power system at a pace not seen since the 1960s, connecting record volumes of wind and solar while transmission, storage and gas all reshape around them. Constraint costs have hit £1.7 billion, gas is being squeezed off the system, and the government has just rewritten the rules of the wholesale market.Chris joins Ed Porter to break down what Mission Control is actually delivering, where flexibility and storage fit into the 2030 plan, and what Reformed National Pricing means for investors, generators and consumers.They cover:Why building UK transmission lines takes 8-10 years — and why bringing two projects forward by a year is worth £4bn to consumers.Why the UK chose to build the grid and the generation simultaneously, and the risks that creates.Why the strategic spatial energy plan is the biggest energy decision coming in the next 12 months and how it sets up a "build it once" network for the future.The reform of National Pricing decision, what the wholesale CfD means in practice and how electricity is being de-linked from gas.Why flexibility is the "forgotten third child" of the energy transition and how dunkelflaute, long-duration storage and household batteries fit into the 2030s system.Chris's contrarian take on carbon pricing - why he thinks the Treasury's decision to remove the Carbon Price Support from gas signals carbon pricing is "coming down the list of things that matters.”Want to model how Clean Power 2030, REMA and the wholesale CFD reshape GB power prices? Ko, Modo Energy's AI analyst, is built for exactly these questions. Free sign up: https://modoenergy.com/sign-up?utm_source=podcast&utm_medium=youtube&utm_campaign=chris_stark&utm_content=ko_signup────────────────────────────⏱ CHAPTERS00:00 - Introduction01:09 - What everyone gets wrong about Mission Control03:00 - Constraint costs as a UK grid health metric04:30 - Why the £7 billion constraint cost forecast may not land09:18 - The biggest UK transmission build since the 1960s10:36 - Sea Link, Norwich to Tilbury and the £4 billion question15:29 - Building a UK grid ready to double electricity demand by 205017:59 - From centralised transmission to flexible, dynamic networks21:16 - Reform of National Pricing: why the UK said no to zonal28:48 - Wholesale CfDs and decoupling UK power from gas prices37:13 - Flexibility, batteries and the forgotten third pillar42:16 - Markets versus state intervention in UK energy47:28 - Long duration energy storage and the battery technology race49:35 - Managing the UK gas fleet down to 5% by 203053:21 - Chris's contrarian view: the end of carbon pricing?55:42 - Closing thoughtsYou can watch or listen to new episodes every Tuesday. Transmission is a Modo Energy production. Your host is Ed Porter - Director EMEA & APAC at Modo Energy.

Chris Stark is Head of UK's Mission for Clean Power, As Head of Mission Control at DESNZ, no one sees the constraint costs, grid bottlenecks and reform of National Pricing trade-offs more clearly. The UK is building a clean power system at a pace not seen since the 1960s, connecting record volumes of wind and solar while transmission, storage and gas all reshape around them. Constraint costs have hit £1.7 billion, gas is being squeezed off the system, and the government has just rewritten the rules of the wholesale market.Chris joins Ed Porter to break down what Mission Control is actually delivering, where flexibility and storage fit into the 2030 plan, and what Reformed National Pricing means for investors, generators and consumers.They cover:Why building UK transmission lines takes 8-10 years — and why bringing two projects forward by a year is worth £4bn to consumers.Why the UK chose to build the grid and the generation simultaneously, and the risks that creates.Why the strategic spatial energy plan is the biggest energy decision coming in the next 12 months and how it sets up a "build it once" network for the future.The reform of National Pricing decision, what the wholesale CfD means in practice and how electricity is being de-linked from gas.Why flexibility is the "forgotten third child" of the energy transition and how dunkelflaute, long-duration storage and household batteries fit into the 2030s system.Chris's contrarian take on carbon pricing - why he thinks the Treasury's decision to remove the Carbon Price Support from gas signals carbon pricing is "coming down the list of things that matters.”Want to model how Clean Power 2030, REMA and the wholesale CFD reshape GB power prices? Ko, Modo Energy's AI analyst, is built for exactly these questions. Free sign up: https://modoenergy.com/sign-up?utm_source=podcast&utm_medium=youtube&utm_campaign=chris_stark&utm_content=ko_signup────────────────────────────⏱ CHAPTERS00:00 - Introduction01:09 - What everyone gets wrong about Mission Control03:00 - Constraint costs as a UK grid health metric04:30 - Why the £7 billion constraint cost forecast may not land09:18 - The biggest UK transmission build since the 1960s10:36 - Sea Link, Norwich to Tilbury and the £4 billion question15:29 - Building a UK grid ready to double electricity demand by 205017:59 - From centralised transmission to flexible, dynamic networks21:16 - Reform of National Pricing: why the UK said no to zonal28:48 - Wholesale CfDs and decoupling UK power from gas prices37:13 - Flexibility, batteries and the forgotten third pillar42:16 - Markets versus state intervention in UK energy47:28 - Long duration energy storage and the battery technology race49:35 - Managing the UK gas fleet down to 5% by 203053:21 - Chris's contrarian view: the end of carbon pricing?55:42 - Closing thoughtsYou can watch or listen to new episodes every Tuesday. Transmission is a Modo Energy production. Your host is Ed Porter - Director EMEA & APAC at Modo Energy.

Germany sits at the centre of Europe's energy transition: over 800 distribution networks, deep intraday markets, and a flexibility gap roughly 40 times its battery fleet. But the real question isn't whether the market is big - it's whether it saturates as battery capacity grows, or scales for years yet.Philipp Man is co-founder and CEO of Terralayr. He joins Ed Porter to unpack the operational reality of building Germany battery storage at scale, the regulatory tension around grid fees, and the contrarian view that Germany's flexibility market is structurally larger than most forecasts suggest.They cover:- Why operating Germany battery storage is harder than capital alone can solve.- Why Germany's TSOs are positive on BESS, why DSOs are nervous and what regulators need to fix.- What the Bundesnetzagentur grid-fee review means for the BESS exemption running to August 2029.- How splitting merchant capacity across multiple optimisers outperforms single-optimiser tolls.- Why flexibility revenues are convex, dominated by tail events, and structurally larger than forecasts predict.Want to track Germany's battery storage pipeline, grid-fee changes, or flexibility market data? Ko, Modo Energy's AI analyst, is built for exactly these questions. Free sign up: https://modoenergy.com/sign-up?utm_source=podcast&utm_medium=podcast_apps&utm_campaign=philipp_man&utm_content=ko_signupTranscript available here: ⏱ CHAPTERS00:00 Introduction01:01 What everyone gets wrong about Germany battery storage04:50 Inside Terralayr's 8 GW pipeline07:00 German grid fees and the 2029 BESS exemption11:00 Why DSOs are nervous about battery storage14:30 Nodal pricing, FCAs and the one-price-zone problem18:30 How layer's virtual battery auction works24:30 Will Germany's BESS market saturate35:30 Markets outside Germany — UK, Spain, Nordics37:00 Advice for new entrants and the coming consolidation40:30 Contrarian view: flexibility revenues are convex`You can watch or listen to new episodes every Tuesday. Transmission is a Modo Energy production. Your host is Ed Porter - Director EMEA & APAC at Modo Energy.Music licensed via Artlist.

Germany sits at the centre of Europe's energy transition: over 800 distribution networks, deep intraday markets, and a flexibility gap roughly 40 times its battery fleet. But the real question isn't whether the market is big - it's whether it saturates as battery capacity grows, or scales for years yet.Philipp Man is co-founder and CEO of Terralayr. He joins Ed Porter to unpack the operational reality of building Germany battery storage at scale, the regulatory tension around grid fees, and the contrarian view that Germany's flexibility market is structurally larger than most forecasts suggest.They cover:- Why operating Germany battery storage is harder than capital alone can solve.- Why Germany's TSOs are positive on BESS, why DSOs are nervous and what regulators need to fix.- What the Bundesnetzagentur grid-fee review means for the BESS exemption running to August 2029.- How splitting merchant capacity across multiple optimisers outperforms single-optimiser tolls.- Why flexibility revenues are convex, dominated by tail events, and structurally larger than forecasts predict.Want to track Germany's battery storage pipeline, grid-fee changes, or flexibility market data? Ko, Modo Energy's AI analyst, is built for exactly these questions. Free sign up: https://modoenergy.com/sign-up?utm_source=podcast&utm_medium=podcast_apps&utm_campaign=philipp_man&utm_content=ko_signupTranscript available here: ⏱ CHAPTERS00:00 Introduction01:01 What everyone gets wrong about Germany battery storage04:50 Inside Terralayr's 8 GW pipeline07:00 German grid fees and the 2029 BESS exemption11:00 Why DSOs are nervous about battery storage14:30 Nodal pricing, FCAs and the one-price-zone problem18:30 How layer's virtual battery auction works24:30 Will Germany's BESS market saturate35:30 Markets outside Germany — UK, Spain, Nordics37:00 Advice for new entrants and the coming consolidation40:30 Contrarian view: flexibility revenues are convex`You can watch or listen to new episodes every Tuesday. Transmission is a Modo Energy production. Your host is Ed Porter - Director EMEA & APAC at Modo Energy.Music licensed via Artlist.

Developing battery storage in emerging markets isn't a technology problem - it's a regulatory, offtake, and capital problem. The frameworks, offtake structures, and capital mandates weren't built for storage and that gap is exactly where the risk sits.Hassen Bali, co-founder and director at Ion Ventures, joins Ed Porter to discuss what it actually takes to develop battery storage projects across markets at very different stages of maturity, from the UK to Southeast Asia.They cover:- Why battery storage development demands a different approach to solar or wind and why you have to decide your commercial endpoint before you break ground, not after.- How project conversion rates in the UK BESS market have dropped from 30–40% in the early days to roughly 10–15% today, and how that affects pipeline management and investor communications.- Why early-stage BESS markets like Malaysia and the Philippines are still reliant on bilateral offtake and what that means for project bankability.- Why FCA-regulated investors face hard legal barriers to project finance in sub-investment-grade countries and what that means for who can actually back early-stage BESS projects.- Hassen's contrarian view: that reform of merit order and legacy thermal contracts is the most direct lever for accelerating energy transition globally even if it means unwinding agreements that investors consider bulletproof.Want to model BESS revenue across different market structures? Ko, Modo Energy's AI analyst, is built for exactly these questions. Free sign up here.Transcript available here: Chapters:0:00 Introduction0:53 What People Get Wrong About Developing Battery Storage Projects2:41 BESS Project Development Pipeline: How to Manage Investors and Conversion Rates5:58 Why Ion Ventures Expanded Into Southeast Asia7:34 BESS Market Readiness in Malaysia, Philippines, Indonesia and Brunei8:32 Replacing Coal and Diesel: What Southeast Asian Grids Look Like Today11:35 BESS Project Success Rates in Emerging Markets vs the UK12:39 Why Bilateral Offtake Models Dominate Early-Stage BESS Markets15:17 Why Long-Term Contracts Can Actually Help Battery Storage Bankability16:05 Why Country Risk and OECD Classification Block Capital From Emerging BESS Markets21:02 Can Emerging Markets Leapfrog to Grid 2.0? The Telco Analogy Explained22:59 How to Build a Battery Storage Roadmap for a Nascent Grid: Lessons from Bangladesh30:06 How to Avoid Grid Congestion When Scaling Renewables in Emerging Markets32:17 Contrarian View: Should Merit Order Reform Unwind Legacy Thermal Contracts?You can watch or listen to new episodes every Tuesday. Transmission is a Modo Energy production. Your host is Ed Porter - Director EMEA & APAC at Modo Energy.

Developing battery storage in emerging markets isn't a technology problem - it's a regulatory, offtake, and capital problem. The frameworks, offtake structures, and capital mandates weren't built for storage and that gap is exactly where the risk sits.Hassen Bali, co-founder and director at Ion Ventures, joins Ed Porter to discuss what it actually takes to develop battery storage projects across markets at very different stages of maturity, from the UK to Southeast Asia.They cover:- Why battery storage development demands a different approach to solar or wind and why you have to decide your commercial endpoint before you break ground, not after.- How project conversion rates in the UK BESS market have dropped from 30–40% in the early days to roughly 10–15% today, and how that affects pipeline management and investor communications.- Why early-stage BESS markets like Malaysia and the Philippines are still reliant on bilateral offtake and what that means for project bankability.- Why FCA-regulated investors face hard legal barriers to project finance in sub-investment-grade countries and what that means for who can actually back early-stage BESS projects.- Hassen's contrarian view: that reform of merit order and legacy thermal contracts is the most direct lever for accelerating energy transition globally even if it means unwinding agreements that investors consider bulletproof.Want to model BESS revenue across different market structures? Ko, Modo Energy's AI analyst, is built for exactly these questions. Want to model BESS revenue across different market structures? Ko, Modo Energy's AI analyst, is built for exactly these questions. Free sign up here.Transcript available here: Chapters:0:00 Introduction0:53 What People Get Wrong About Developing Battery Storage Projects2:41 BESS Project Development Pipeline: How to Manage Investors and Conversion Rates5:58 Why Ion Ventures Expanded Into Southeast Asia7:34 BESS Market Readiness in Malaysia, Philippines, Indonesia and Brunei8:32 Replacing Coal and Diesel: What Southeast Asian Grids Look Like Today11:35 BESS Project Success Rates in Emerging Markets vs the UK12:39 Why Bilateral Offtake Models Dominate Early-Stage BESS Markets15:17 Why Long-Term Contracts Can Actually Help Battery Storage Bankability16:05 Why Country Risk and OECD Classification Block Capital From Emerging BESS Markets21:02 Can Emerging Markets Leapfrog to Grid 2.0? The Telco Analogy Explained22:59 How to Build a Battery Storage Roadmap for a Nascent Grid: Lessons from Bangladesh30:06 How to Avoid Grid Congestion When Scaling Renewables in Emerging Markets32:17 Contrarian View: Should Merit Order Reform Unwind Legacy Thermal Contracts?You can watch or listen to new episodes every Tuesday. Transmission is a Modo Energy production. Your host is Ed Porter - Director EMEA & APAC at Modo Energy.

Spain has approximately 42GW of utility-scale solar and 50GW when rooftop is included, yet less than 100MW of grid-connected battery storage. In February, solar capture rates hit €1.30 per megawatt hour, a fraction of the €30–35/MWh needed for a solar project to break even. So why hasn't battery storage followed the solar boom and could it be the key to rescuing solar revenues?Pablo Martinez Serrano, Iberia Industry Lead at Modo Energy, joins Ed Porter to break down why Spain's energy market defies easy assumptions, and what the Iberian blackout changed.They cover:- Why Spain's hydro fleet masked the need for batteries for years, and why that's no longer enough as solar saturation bites.- Why solar developers are earning less and less for every unit of power they generate and what that means for the projects still in the pipeline.- The co-location thesis: why existing solar asset owners are turning to BESS to fix their generation profile and unlock ancillary service revenue- What actually caused the Iberian blackout: voltage instability, cascading disconnections, and why the TSO had already flagged the risk- Spain's new voltage control market: how it works, why priority of dispatch may be more valuable than the reactive service payment itselfWant to model battery revenue stacks in Spain or track Iberian power market dynamics? Ko, Modo Energy's AI analyst, is built for exactly these questions. Free sign up: https://help.modo.energy/en/articles/13335470-ko-your-ai-analyst?utm_source=podcast&utm_medium=podcast_apps&utm_id=pablo_martinez⏱ CHAPTERS00:00:00 Introduction00:00:50 What everyone gets wrong about Spain00:01:54 Spain's generation mix: solar, wind, hydro, gas and nuclear00:04:43 Seasonal demand dynamics and why spring is the problem00:06:03 Solar capture price collapse: €42 to below €30/MWh00:08:19 PPA contracts, negative prices and the solar momentum problem00:11:52 The co-location pivot: why developers are turning to storage00:13:58 Why Spain has less than 100MW of batteries vs GB's 6GW00:15:33 Where the money is coming from: two types of investor00:17:11 The Iberian blackout: what went wrong and why00:20:04 How Spain is rebuilding grid stability after the blackout00:21:04 Spain's new voltage control market and what it pays00:24:43 Grid forming inverters and the future of ancillary services00:26:38 Contrarian take: Spain hasn't actually decoupled from gas00:29:15 The three phases of displacing thermal generators00:30:39 Closing remarksYou can watch or listen to new episodes every Tuesday. Transmission is a Modo Energy production. Your host is Ed Porter - Director EMEA & APAC at Modo Energy.

Spain has approximately 42GW of utility-scale solar and 50GW when rooftop is included, yet less than 100MW of grid-connected battery storage. In February, solar capture rates hit €1.30 per megawatt hour, a fraction of the €30–35/MWh needed for a solar project to break even. So why hasn't battery storage followed the solar boom and could it be the key to rescuing solar revenues?Pablo Martinez Serrano, Iberia Industry Lead at Modo Energy, joins Ed Porter to break down why Spain's energy market defies easy assumptions, and what the Iberian blackout changed.They cover:- Why Spain's hydro fleet masked the need for batteries for years, and why that's no longer enough as solar saturation bites.- Why solar developers are earning less and less for every unit of power they generate and what that means for the projects still in the pipeline.- The co-location thesis: why existing solar asset owners are turning to BESS to fix their generation profile and unlock ancillary service revenue- What actually caused the Iberian blackout: voltage instability, cascading disconnections, and why the TSO had already flagged the risk- Spain's new voltage control market: how it works, why priority of dispatch may be more valuable than the reactive service payment itselfWant to model battery revenue stacks in Spain or track Iberian power market dynamics? Ko, Modo Energy's AI analyst, is built for exactly these questions. Free sign up: https://help.modo.energy/en/articles/13335470-ko-your-ai-analyst?utm_source=podcast&utm_medium=podcast_apps&utm_id=pablo_martinez⏱ CHAPTERS00:00:00 Introduction00:00:50 What everyone gets wrong about Spain00:01:54 Spain's generation mix: solar, wind, hydro, gas and nuclear00:04:43 Seasonal demand dynamics and why spring is the problem00:06:03 Solar capture price collapse: €42 to below €30/MWh00:08:19 PPA contracts, negative prices and the solar momentum problem00:11:52 The co-location pivot: why developers are turning to storage00:13:58 Why Spain has less than 100MW of batteries vs GB's 6GW00:15:33 Where the money is coming from: two types of investor00:17:11 The Iberian blackout: what went wrong and why00:20:04 How Spain is rebuilding grid stability after the blackout00:21:04 Spain's new voltage control market and what it pays00:24:43 Grid forming inverters and the future of ancillary services00:26:38 Contrarian take: Spain hasn't actually decoupled from gas00:29:15 The three phases of displacing thermal generators00:30:39 Closing remarksYou can watch or listen to new episodes every Tuesday. Transmission is a Modo Energy production. Your host is Ed Porter - Director EMEA & APAC at Modo Energy.

Smart EV charging isn't just about saving money on your electricity bill, it's quietly becoming one of the most scalable sources of grid flexibility in Great Britain. Ohme has run the numbers: incentivising 22,000 customers to plug in more often drove a 32–37% increase in plug-in frequency, unlocking dispatchable flexibility across 60 National Grid events.In this episode, Ed is joined by Joshua Willetts and Dan Norton from Ohme. Josh is part of Ohme's customer operations team and starts the conversation with a live demo of the Ohme Home Pro, and then Dan Ohme's Commercial Director takes us through a deep dive of the economics, regulation, and long-term potential of smart home charging.They cover:- How the Ohme Home Pro works, tethered setup, app pairing, tariff integration, and smart scheduling on Octopus Go and equivalent time-of-use tariffs.- Why plugging in little and often (rather than running to empty and topping up) is the behavioural shift that unlocks real-world EV flexibility.- The CrowdFlex trial results: how a 1–3 GBP/week incentive delivered a 32–37% rise in plug-in frequency and fed directly into National Grid dispatch events- What smart charging regulation, including the Energy Smart Appliance (ESA) framework and load control licensing means for charger manufacturers and aggregators- How V2G and vehicle-to-home could evolve once older EV fleets start cycling into second-hand markets, and what cultural shifts are needed firstWant to model EV flexibility potential in your market? Ko, Modo Energy's AI analyst, is built for exactly these questions. Free sign up: https://help.modo.energy/en/articles/13335470-ko-your-ai-analyst?utm_source=podcast_apps&utm_medium=video&utm_id=ohmeTranscript available here: https://modoenergy.com/transmission-podcast/d2135750-c32a-49dd-a218-e3f69cfc48d7────────────────────────────────────────────────────────⏱ CHAPTERS0:00 Intro — Ed Porter, Welcome to Transmission1:04 Meet Joshua & the Ohme Home Pro1:52 App Setup, QR Code Pairing & Smart Scheduling4:44 Why a Box? What's Inside an EV Smart Charger5:22 Live Demo: Charging a Light Bulb via the Ohme App7:53 Charge Speed, Battery Times & Little-and-Often Strategy11:37 Introducing Dan: EV Adoption Stats & the UK Home Charge Market13:33 Barriers to Home EV Charging Installation18:44 Home Charging vs. Public Charging: The Economics20:06 CrowdFlex Explained: Smart Charging as Grid Flexibility23:11 CrowdFlex Results.26:32 Smart Charging Regulation: ESA, Load Control & Revenue Certainty28:43 How Big Could EV Flexibility Get? GB Grid Scale30:34 Vehicle to Grid (V2G) & Vehicle to Home: What's Coming34:40 What Would You Change? Flexibility Contracts as Steel in the Ground────────────────────────────────────────────────────────You can watch or listen to new episodes every Tuesday. Transmission is a Modo Energy production. Your host is Ed Porter — Director EMEA & APAC at Modo Energy.

Smart EV charging isn't just about saving money on your electricity bill, it's quietly becoming one of the most scalable sources of grid flexibility in Great Britain. Ohme has run the numbers: incentivising 22,000 customers to plug in more often drove a 32–37% increase in plug-in frequency, unlocking dispatchable flexibility across 60 National Grid events.In this episode, Ed is joined by Joshua Willetts and Dan Norton from Ohme. Josh is part of Ohme's customer operations team and starts the conversation with a live demo of the Ohme Home Pro, and then Dan Ohme's Commercial Director takes us through a deep dive of the economics, regulation, and long-term potential of smart home charging.They cover:- How the Ohme Home Pro works, tethered setup, app pairing, tariff integration, and smart scheduling on Octopus Go and equivalent time-of-use tariffs.- Why plugging in little and often (rather than running to empty and topping up) is the behavioural shift that unlocks real-world EV flexibility.- The CrowdFlex trial results: how a 1–3 GBP/week incentive delivered a 32–37% rise in plug-in frequency and fed directly into National Grid dispatch events- What smart charging regulation, including the Energy Smart Appliance (ESA) framework and load control licensing means for charger manufacturers and aggregators- How V2G and vehicle-to-home could evolve once older EV fleets start cycling into second-hand markets, and what cultural shifts are needed firstWant to model EV flexibility potential in your market? Ko, Modo Energy's AI analyst, is built for exactly these questions. Free sign up: https://help.modo.energy/en/articles/13335470-ko-your-ai-analyst?utm_source=podcast_apps&utm_medium=video&utm_id=ohmeTranscript available here: https://modoenergy.com/transmission-podcast/d2135750-c32a-49dd-a218-e3f69cfc48d7────────────────────────────────────────────────────────⏱ CHAPTERS0:00 Intro — Ed Porter, Welcome to Transmission1:04 Meet Joshua & the Ohme Home Pro1:52 App Setup, QR Code Pairing & Smart Scheduling4:44 Why a Box? What's Inside an EV Smart Charger5:22 Live Demo: Charging a Light Bulb via the Ohme App7:53 Charge Speed, Battery Times & Little-and-Often Strategy11:37 Introducing Dan: EV Adoption Stats & the UK Home Charge Market13:33 Barriers to Home EV Charging Installation18:44 Home Charging vs. Public Charging: The Economics20:06 CrowdFlex Explained: Smart Charging as Grid Flexibility23:11 CrowdFlex Results.26:32 Smart Charging Regulation: ESA, Load Control & Revenue Certainty28:43 How Big Could EV Flexibility Get? GB Grid Scale30:34 Vehicle to Grid (V2G) & Vehicle to Home: What's Coming34:40 What Would You Change? Flexibility Contracts as Steel in the Ground────────────────────────────────────────────────────────You can watch or listen to new episodes every Tuesday. Transmission is a Modo Energy production. Your host is Ed Porter — Director EMEA & APAC at Modo Energy.

Battery storage looks simple - a steel box that charges when prices are low and discharges when they're high. But financing a BESS project in Europe means underwriting a trading position: convex revenues, volatile returns, and a growing menu of contractual choices that each shift the risk profile in a different direction.Lisa McDermott, Managing Director and Head of Energy Transition Project Financing at ABN AMRO, has been structuring BESS deals across Europe since 2023*. In this episode, she opens up the credit committee. What gets a project over the line, and what quietly stops it.Covered:- Why battery storage finance is fundamentally different from solar or wind and why contracting it away doesn't change the underlying risk when the contract ends.- From physical tolls to day-ahead swaps, Lisa breaks down which offtake structures are gaining traction in Europe and why the day-ahead swap is the hardest to bank.- Too much merchant exposure, insufficient sponsor equity, weak technical track record and why pushing too many levers at once is the fastest way to stop a deal.- How battery warranties have evolved from 8 to 20 years and why coverage beyond the debt tenor is a bankability requirement, not a nice-to-have.- Germany's grid fee reform has created financing uncertainty at COD, while the Netherlands' congestion model is, counter-intuitively, better for bankability.Want to model battery revenue stacks or stress-test tolling structures for a specific market? Ko, Modo Energy's AI analyst, is built for exactly these questions. Free sign up: https://help.modo.energy/en/articles/13335470-ko-your-ai-analyst?utm_source=podcast_apps&utm_medium=podcast&utm_id=lisa_mcdermottTranscript available here: https://modoenergy.com/transmission-podcast/e2b12f17-f7b4-49d3-9d85-e4cc822695f6────────────────────────────⏱ CHAPTERS0:00 Introduction - Is financing battery storage the same as financing solar?2:32 Why a battery is financing a trader, not an infrastructure asset5:14 Financing across technology types - TRL 8 vs TRL 910:43 What stops a BESS deal in credit committee15:53 Comfort zone: from fully merchant to fully contracted18:43 The growing offtake menu, physical tolls, virtual tolls, and floors24:43 Day-ahead swaps explained and why they introduce basis risk31:59 Gearing: the sliding scale from 30% merchant to 85% fully tolled34:37 European market comparison: Netherlands, France, Italy, Germany40:23 Final question ────────────────────────────You can watch or listen to new episodes every Tuesday. Transmission is a Modo Energy production. Your host is Ed Porter — Director EMEA & APAC at Modo Energy.*Correction: The intro incorrectly states that Lisa McDermott has been financing batteries since 2020. She has been doing so since 2023. We apologise for the error.

Battery storage looks simple - a steel box that charges when prices are low and discharges when they're high. But financing a BESS project in Europe means underwriting a trading position: convex revenues, volatile returns, and a growing menu of contractual choices that each shift the risk profile in a different direction.Lisa McDermott, Managing Director and Head of Energy Transition Project Financing at ABN AMRO, has been structuring BESS deals across Europe since 2023*. In this episode, she opens up the credit committee. What gets a project over the line, and what quietly stops it.Covered:- Why battery storage finance is fundamentally different from solar or wind and why contracting it away doesn't change the underlying risk when the contract ends.- From physical tolls to day-ahead swaps, Lisa breaks down which offtake structures are gaining traction in Europe and why the day-ahead swap is the hardest to bank.- Too much merchant exposure, insufficient sponsor equity, weak technical track record and why pushing too many levers at once is the fastest way to stop a deal.- How battery warranties have evolved from 8 to 20 years and why coverage beyond the debt tenor is a bankability requirement, not a nice-to-have.- Germany's grid fee reform has created financing uncertainty at COD, while the Netherlands' congestion model is, counter-intuitively, better for bankability.Want to model battery revenue stacks or stress-test tolling structures for a specific market? Ko, Modo Energy's AI analyst, is built for exactly these questions. Free sign up: https://help.modo.energy/en/articles/13335470-ko-your-ai-analyst?utm_source=podcast_apps&utm_medium=podcast&utm_id=lisa_mcdermottTranscript available here: https://modoenergy.com/transmission-podcast/e2b12f17-f7b4-49d3-9d85-e4cc822695f6────────────────────────────⏱ CHAPTERS0:00 Introduction - Is financing battery storage the same as financing solar?2:32 Why a battery is financing a trader, not an infrastructure asset5:14 Financing across technology types - TRL 8 vs TRL 910:43 What stops a BESS deal in credit committee15:53 Comfort zone: from fully merchant to fully contracted18:43 The growing offtake menu, physical tolls, virtual tolls, and floors24:43 Day-ahead swaps explained and why they introduce basis risk31:59 Gearing: the sliding scale from 30% merchant to 85% fully tolled34:37 European market comparison: Netherlands, France, Italy, Germany40:23 Final question ────────────────────────────You can watch or listen to new episodes every Tuesday. Transmission is a Modo Energy production. Your host is Ed Porter — Director EMEA & APAC at Modo Energy.*Correction: The intro incorrectly states that Lisa McDermott has been financing batteries since 2020. She has been doing so since 2023. We apologise for the error.