Part III: Drawing Up the Ledger

In the first two parts, we saw how Germany rebuilt its energy system and the burdens it placed on industry and households. Now we turn to the future: what short- and long-term prospects is Germany facing, and what can Hungary learn from it? At the end, I draw up the economic ledger.

1. Short-Term Outlook (2026–2030)

The German government's central pledge is for renewables to account for 80% of gross electricity consumption by 2030. Broken down by technology, that means the following:

These targets are ambitious; hitting them is another matter. Onshore wind permitting remains sluggish: in 2025, only 4.5 GW of new capacity came online (per Fraunhofer ISE), falling short of even the interim cumulative target of 76.5 GW for that year. Local opposition and red tape mean expansion keeps slipping behind schedule. Offshore wind is slowing too — only 0.5 GW of new capacity in 2025 — with nearly 21 GW still to find to hit the 30 GW target, and laying subsea cables takes years.

Solar tells a brighter story: capacity reached ~107 GW (AC) in 2025 after more than 17 GW of new solar came online during the year — a record. Grid connections are another chokepoint: in 2025, grid operators had to curtail a record ~1.75 TWh of renewable output (wind and solar combined) as the network clogged up — almost 25% more than the year before, and the trend is accelerating.

The Hydrogen Network: Industry's Green Future?

The Wasserstoff-Kernnetz (hydrogen core network) is one of Germany's largest infrastructure projects, approved by the Bundesnetzagentur in October 2024. The network:

• will run to 9,040 kilometres, built mostly (around 60%) by repurposing existing natural gas pipelines, with the rest new-build;
• must be completed by 2032;
• state bank KfW has provided a €24 billion credit line for the financing.

The hydrogen strategy carries real risks too. Green hydrogen currently costs three to five times as much as natural gas, and the technology has not yet reached mass scalability. On top of that, full-chain efficiency is poor: electrolysis (water to hydrogen) is roughly 70% efficient, storage and transport account for another 10–15% in losses, and converting it back to electricity in a gas plant wastes another 50%. By the end of the chain, only 25–30% of the original electricity can actually be used. In other words, "green hydrogen" is in practice an expensive and wasteful form of energy storage — the German model is trying to fill the nuclear void with it, but it is a loss on both physical and economic grounds.

The storage myth. A common view is that batteries will solve the Dunkelflaute problem. True, battery energy storage systems (BESS) are brilliant at smoothing daily fluctuations: they charge off surplus solar during the day and discharge after dark. But they are useless for storing power across seasons, or even for multi-week winter stretches. Covering a typical German household's monthly winter draw — and then scaling that across the country — would take a battery park the size of a city, at a cost of several billion euros and with vast amounts of raw material (lithium, cobalt) to find. The hard truth is that during a foggy, windless January week in Germany, 180+ GW of renewable capacity (wind and solar) can produce next to nothing — and there are not enough batteries on earth to ride out that stretch. Germany's answer to that problem is gas and hydrogen — in other words, preserving fossil-fuel dependence behind a green veneer. If the hydrogen grid is ready by 2032 but there is no cheap green hydrogen to fill it, the pipes will sit empty — while consumers and taxpayers foot the bill.

The Power Plant Strategy and Capacity Market: The Return of Gas

The most important — and most controversial — development is the German power plant strategy (Kraftwerksstrategie). In January 2026, the German government and the European Commission agreed to tender 12 GW of new dispatchable capacity in 2026. The breakdown:

• 10 GW of long-term capacity, primarily hydrogen-ready gas-fired plants (H2-ready CCGT), due online by 2031;
• 2 GW of short-term, technology-neutral capacity, including battery storage and demand-side flexibility;
• the plants must operate fully decarbonised by 2045, with 2 GW converting to hydrogen by 2040 and a further 2 GW by 2043.

Capacity market (Kapazitätsmarkt) tenders begin in 2027, with the mechanism running fully from 2032 — a set-up that, much like the Belgian model, would guarantee dispatchable capacity. So the German model is turning back to gas-fired plants as a safety reserve — the very technologies whose phase-out had previously been planned.

The economic lesson is plain: hitting the 80% renewable target takes more than wind and solar. They need dispatchable backup alongside them, and if nuclear is off the table, gas is what remains — hydrogen-ready, perhaps, but gas nonetheless. This "gas bridge" strategy cements fossil-fuel dependence for decades to come, if at a lower level.

2. Long-Term Outlook (2030–2045)

Under Germany's climate change law, the country must become climate-neutral by 2045. That target carries a gigantic price tag. According to estimates by KfW Research and the EPRS, total investment in the order of €5 trillion is required, of which roughly €500 billion would be direct state financing.

The distortion of capital allocation. In economic terms, the question that matters is not what the transition costs, but what that money is not being spent on. The German economy pours billions each year into rebuilding its energy system, expanding the grid and covering system costs (redispatch, capacity market). That capital does not go into new products, new industries or more competitive manufacturing technologies — but into delivering the same product (electricity) to the same consumers, only at higher cost and with lower reliability. This is classic "malinvestment" (misdirected investment) in the Austrian-school sense: state regulation (EEG, quotas) distorted the price signal, and capital flooded into sectors that would not be competitive without it.

These numbers are of course speculative — technological progress (cheaper batteries, more efficient electrolysis, smart grids) could bring costs down sharply. But the current trajectory looks worrying:

• Renewable investment costs (solar panels, wind turbines) are tumbling — thanks to Germany's first-mover advantage.
• System costs (grid, storage, redispatch, hydrogen), by contrast, are rising exponentially. Grid expansion and storage mean further costs in the hundreds of billions of euros through 2045.
• The erosion of industrial competitiveness may not be over. If the US and China keep offering cheaper energy, German factories will keep moving abroad.

The key question: will technology hit the "tipping point" where storage and smart-grid costs offset volatility? For now, that looks unlikely before 2040. The hydrogen network and capacity market reduce risk, to be sure, but they also make the system more expensive.

3. The German Model in its European Context

It is worth summing up what the German Energiewende has meant for the continent as a whole.

4. Through a Hungarian Lens, Part III — Model or Warning?

Now for the awkward question: is Germany a model or a warning for Hungary?

The answer: both at once. It depends which aspect you look at.

Household bill stress-test: if Hungary followed the German model

Suppose Hungary were to shut down Paks and coal tomorrow and switch exclusively to wind and solar at German-style market prices:

1. Backup requirement: in windless conditions and after dark, gas-fired plants or imports would have to cover total Hungarian consumption (~45 TWh/year). That would mean 15–20 TWh of gas-fired generation a year, drastically raising import dependence.
2. Price surge: Hungarian wholesale prices, which averaged ~€100–120/MWh in 2025, could climb sharply — even to €180–220/MWh — as gas-based backup ramps up. Household prices could rise from €0.10 to €0.30–0.35/kWh if market prices fed through into the state-capped household energy price scheme.
3. Grid expansion: new transmission lines would be needed from northern Hungary (wind) and the south (solar) towards Budapest. That would add another HUF 5–8 (Hungarian forints) per kWh in grid fees.
4. The bottom line: an average family's annual electricity bill could jump from HUF 80,000 to HUF 280,000–350,000 (roughly €200 to €700–875). Electricity costs would swallow 8–10% of household income, against the current 2–3%.

Hungary is not immune. The risks set out above are just as real there. The Mátra Power Plant — the last major bastion of Hungarian coal-fired generation — could close in the next few years, further reducing domestic dispatchable capacity. Meanwhile, the Hungarian government is planning several new combined-cycle gas-fired plants (CCGT) with domestic industry in mind — battery plants, car factories. That means Hungary is increasing its gas dependence too, while Paks II is not yet producing. In the summer months, Hungary's 6+ GW of domestic solar already overproduces, and the Hungarian grid is struggling with connection requests — grid-connection moratoria are in force across numerous regions because the lines cannot handle the surplus. Negative prices (when producers pay to have their electricity taken) have already appeared in Hungary in summer midday hours.

Four lessons for Hungary:

1. Raising the share of renewables is unavoidable — but without dispatchable capacity (nuclear, hydro, gas, storage), backup is expensive. The German model proves the point, racking up €3 billion a year in redispatch costs.
2. Reconciling low household prices with industrial competitiveness is crucial — on this front, the German model is a warning. If industry migrates, the country loses not only jobs but tax revenues.
3. The lesson of Hungary's solar boom: decentralised generation scales fast (witness the 24% solar share), but the grid has to keep up. In Germany in 2025, grid bottlenecks forced operators to curtail nearly 1.75 TWh of renewable generation — Hungary needs to get its grid investment in early.
4. The risk around Paks II is real, but the German alternative is more expensive. A delayed Paks II is a problem. But without nuclear, the choice is either expensive gas backup (the German model) or import dependence (more expensive still).

5. Closing Thought: The Economic Ledger

Twenty-five years of the German Energiewende have made one thing clear: the climate transition is possible, but not free. Germany has brought innovation gains to the world — cheaper solar panels, more advanced wind turbines, smart-grid technology. Yet the first-mover penalty has shown up too: spiralling system costs, industrial decline, social tensions.

The economic ledger looks like this:

The choice is plain: a rapid, costly transition at the technological frontier (the German model), or a measured, balanced shift built on the synergy of nuclear and renewables (the Hungarian model)? Both have arguments in their favour, but the cost and risk profiles differ.

The energy trilemma. The closing thought is this: Germany's "green transition" is not some wicked conspiracy but a noble climate goal executed badly on ideological grounds, one that ignored the iron laws of physics and economics. The Hungarian lesson is that in energy policy, the winner is not the greenest or the fastest country, but the one that can keep its triangle in balance: climate goals — security of supply — competitiveness. If any one corner gains too much weight, the triangle collapses. Germany pushed the climate corner too far at the expense of competitiveness and stability. Hungary's risk is the mirror image: that grid investment falls behind under cover of the state-capped household energy price scheme, and that delays to Paks II leave the country dependent on gas. Those who keep the triangle in balance win. Those who do not pay — on their electricity bill, in debt, or in shuttered factories.