What “30% flexibility from green hydrogen” actually means
Amber Grid’s new analysis puts a concrete number on a topic that’s been discussed for years: by 2050, electrolyser-based green hydrogen production could provide up to 30% of Lithuania’s power system flexibility (6.5 GW). This post unpacks what “flexibility” means in practice, why it’s unlikely to be the main revenue stream for hydrogen producers, and what infrastructure + market design would need to align for this to work.
NEWS
PtXBaltic
2/18/20263 min read
Amber Grid has published an analysis on how Lithuania’s emerging green hydrogen ecosystem could interact with the power sector. The headline number is striking: by 2050, electrolyser-based hydrogen production could provide up to 30% of Lithuania’s electricity system flexibility (cited as 6.5 GW of flexible capacity in the National Energy Independence Strategy).
In plain terms, this is not a claim that hydrogen will “generate” 30% of electricity. It is a claim about flexibility: the ability of the power system to balance variable wind and solar by adjusting demand and supply quickly and predictably.
Why electrolysers are being discussed as “flexible demand”
Electrolysers convert electricity and water into hydrogen. If they are designed and operated with flexibility in mind, they can:
Increase consumption when renewable generation is high (and prices are lower)
Reduce or pause consumption when the grid is tight
Potentially participate in system services / flexibility markets (depending on technical configuration and market rules)
This is one of the more practical near-to-mid-term roles for hydrogen in power systems: not only as a molecule for industry and transport, but also as a tool to manage variability in a renewables-heavy grid.
A key nuance: flexibility revenues are unlikely to be the main business case
One of the more realistic points in Amber Grid’s message is that participation in flexibility markets would likely be an optimisation layer, not the core revenue stream for hydrogen producers.
The main driver remains the economics of hydrogen production and offtake. Flexibility participation can help reduce costs (especially operating costs that, over time, become a large part of delivered hydrogen price), but it won’t automatically “make the project bankable” on its own.
What needs to happen for this to work (three enablers)
Amber Grid highlights three measures that would strengthen the interaction between hydrogen and the electricity sector:
Hydrogen transport infrastructure
A network (or repurposed gas assets where feasible) can reduce the need to solve everything with on-site storage and can allow producers to operate more flexibly.
Dynamic electricity transmission tariffs
If network tariffs better reflect system conditions, hydrogen producers can respond economically (not only technically) and optimise when they run.
Clear definition of national flexibility needs + development of flexibility services
Markets need products, rules, and procurement that allow new technologies—including electrolysers—to participate in a predictable way.
The Baltic angle: this is not just a Lithuanian discussion
From a PtX Baltic perspective, the interesting part is how quickly this “hydrogen-as-flexibility” logic is becoming a system planning topic, not just a project-level conversation.
Across the Nordic-Baltic region, we’re seeing the same ingredients:
Rapid growth in variable renewables
Increasing value of flexibility (fast, controllable, measurable)
Early-stage hydrogen offtake that needs cost discipline
Infrastructure planning questions (electricity grids, hydrogen networks, storage)
Lithuania’s framing—electrolysers as a meaningful share of future flexible capacity—puts a number on something many stakeholders have discussed qualitatively for years.
Questions worth asking now (for developers, TSOs/DSOs, policymakers)
If electrolysers are expected to play a material flexibility role, then the “how” matters:
Which electrolyser technologies and configurations are best suited for flexibility without excessive degradation or efficiency penalties?
What will be the dominant business model: baseload hydrogen, merchant hydrogen, contracted offtake, or hybrid models?
How will hydrogen transport and storage constraints shape operational flexibility?
What flexibility products will be procured (and how often), and what telemetry/verification will be required?
These are not academic details—they determine whether flexibility becomes a real value stream or remains a theoretical potential.
Takeaway
Amber Grid’s analysis is a useful signal: hydrogen is entering the grid flexibility conversation in concrete terms. The next step is aligning infrastructure planning, tariff design, and market rules so that electrolysers can respond to system needs without undermining the core economics of hydrogen production.