On 19 August, Romania’s energy regulator ANRE approved a regulation that lets electricity consumers get paid for temporarily and voluntarily cutting how much power they use. It is, on paper, an unremarkable piece of market design — the kind of demand-response mechanism regulators across Europe have been rolling out for years. What makes the timing worth pausing on is what else was happening in Romania that same week: the country’s only nuclear power plant had been sitting completely offline for six days, and remains offline as of this writing, because the Danube no longer has enough water flowing through it to cool the reactors.
What ANRE actually approved
The regulation creates a “consumption flexibility service” run by Transelectrica, Romania’s transmission system operator. Eligible consumers — directly, or through electricity suppliers and aggregators — can bid into auctions offering to reduce their consumption by a given amount at a given price. Transelectrica sets how much flexibility it needs for a given period, runs the auction, accepts the most competitive offers until the need is covered, then verifies through metering data that the promised reduction actually happened before paying out.
ANRE has gone out of its way to frame this as a market tool rather than an emergency measure. “We are not talking about rationing, nor about a mechanism reserved exclusively for crisis situations,” ANRE president George Niculescu said in the regulator’s announcement. “We are talking about the possibility for a consumer to decide, on their own, that at a certain time and a certain price, it is more advantageous to temporarily reduce consumption and be paid for that flexibility.” Niculescu framed it as filling in half of an equation regulators have historically only worked from one side: “Until now, we have been accustomed to looking at system balancing primarily from a production perspective: if we need more energy, we increase production… in certain moments, it can be more efficient and cheaper to voluntarily reduce demand.” The stated purpose extends beyond emergencies to routine market conditions too, activating whenever cutting demand is cheaper than dispatching expensive balancing power — with the added benefit, per ANRE, that every megawatt-hour of contracted flexibility that displaces costlier balancing capacity lowers the total cost that ultimately gets passed back to all consumers on the system.
Some of the operational detail — including a reported 500 kW minimum bid size for participants and a requirement that at least half of the resulting revenue be passed through to end customers by suppliers or aggregators — comes from reporting on the draft version of the regulation that ANRE put out for public consultation in late 2025, a process that closed on 3 December that year with an original target of launching the market by spring 2026. ANRE’s own announcement of the final, approved regulation does not repeat those specific thresholds, so it isn’t confirmed here whether they survived unchanged into the adopted text. What is consistent across both the draft-stage reporting and the final announcement is the shape of the mechanism: large consumers, suppliers and aggregators first, with household participation expected only later and only via aggregators or suppliers who choose to offer it.
Why this is landing now
Romania’s electricity system has had a genuinely difficult August. Cernavodă, the country’s sole nuclear power plant and normally the source of roughly a fifth of its electricity, took its first reactor offline in July and shut its second and last remaining reactor on 13 August. The reason wasn’t a technical fault: the Danube’s flow had dropped so far that the plant could no longer draw enough cooling water to run safely. Copernicus data cited in European reporting on the shutdown found that nearly two-thirds of the Danube experienced record-low July flow rates over a 34-year record. The plant’s only previous full shutdown, in 2003, was for the same reason. As of 29 August — ten days after ANRE’s flexibility regulation was approved — Cernavodă still has not restarted: Romania’s National Institute of Hydrology has measured Danube flow at the Băziaș monitoring point running at around 1,600 cubic metres per second, well under the historical August average of roughly 3,900, and plant operator SN Nuclearelectrica says both reactors remain in “safe condition” pending water levels recovering enough to justify a restart, with cooler, wetter weather forecast further upstream in southern Germany, Austria and Slovakia offering the best near-term hope of that happening.
Romania didn’t simply absorb the 1,400 MW loss. Reserve coal capacity came back online — a unit at the Rovinari lignite plant returned to service on 17 August adding roughly 300 MW, alongside a reactivated reserve unit at the Paroșeni coal plant — and two major automotive manufacturers, Dacia and Ford, paused production at their Romanian plants through 19 August, the same day ANRE’s regulation was approved, as part of the effort to manage demand during the shortfall. Separately, engineers spent roughly €2 million on river-engineering work — including altering rock formations and sinking barges — to try to redirect what water remains toward the plant’s intake.
None of the sources reviewed for this piece claim ANRE’s flexibility regulation was drafted specifically because of the Cernavodă shutdown — the underlying policy work traces back to at least the 2025 public consultation, well before the reactors went dark. But the coincidence in timing is real, not manufactured for effect: a mechanism designed to let the grid lean on demand instead of production arrived in force during the most acute domestic test of that exact idea Romania has faced since the plant’s last drought shutdown in 2003, and largely because two carmakers had already been forced to improvise an ad hoc version of the same thing that ANRE has now put a price on.
Romania isn’t drawing up the blueprint from scratch
Demand-side flexibility markets already operate elsewhere in Europe, which gives some sense of where Romania’s might land in practice. Spain has run an “active demand response service” through grid operator Red Eléctrica since October 2022, when its first auction secured 497 MW of demand response from sixteen participating entities, each required to meet a 1 MW minimum consumption threshold — smaller industrial and commercial consumers were excluded at launch, and households were not eligible at all. Participants are paid an availability fee for the length of their contracted period (the original 2022 auction set that at €69.97 per megawatt-hour across roughly 2,714 contracted hours a year) plus a separate activation payment, at the prevailing tertiary-control balancing price, whenever Red Eléctrica actually calls on them. Prices paid for that activation aren’t fixed: reporting on Spain’s market put the highest recorded activation payment at €211.52 per megawatt-hour as of 11 August 2026 — a reminder that a flexibility market’s real value to a participant depends heavily on how tight the system is on the day it gets called, not just the headline structure of the scheme.
That structure — market access for demand alongside supply, including through independent aggregators rather than only a customer’s own electricity supplier — isn’t just a design choice individual countries have converged on by coincidence. EU-wide electricity market rules (Regulation (EU) 2019/943) require that final customers be able to participate in electricity markets, including balancing markets, either individually or through aggregation, and that market design not discriminate against that kind of participation. Romania’s new regulation sits inside that broader European push to treat flexible demand as a resource the grid can call on, not just something suppliers forecast around.
The bet underneath the mechanism
Strip away the market mechanics and ANRE’s regulation rests on a fairly simple wager: that enough companies — and eventually enough households, via suppliers willing to build the retail products to reach them — will find it worth their while to shift or shed load for a price, often enough and in large enough volumes to actually matter when the system is under strain.
Niculescu’s framing leans hard into that shift in mindset: “We are transforming consumers from passive participants into active partners of the National Energy System… It is a market instrument, based on competition and on the economic decision of each participant.”
Spain’s experience over the past four years suggests the concept works at meaningful scale once it exists; whether Romanian industry responds the same way, and how quickly ordinary households get access to it through their suppliers, will only become clear once Transelectrica actually starts running auctions under the new rules. For now, the more immediate test of whether the country needs exactly this kind of tool is still sitting on the banks of the Danube, waiting for the water to come back up.
