Aggregation and revenue
What a battery can earn on the grid.
A battery connected in France can earn revenue from several mechanisms: frequency reserves, balancing, capacity, demand response. Each has its own power threshold, time interval and prequalification conditions. These revenues are distinct from bill savings, which come from the network charges – TURPE, the French tariff for the use of the public electricity networks – and pass through no market.
Facts verified on 2 October 2026.
Which mechanisms pay a battery in France?
Six routes exist, and they are not of the same nature. Five are markets where a third party buys a service and pays for it; the sixth is a saving on your own bill, where nobody pays anything. For each, the table gives the access threshold, the time interval of the commitment and the text that sets them.
| Mechanism | Nature | What is bought | Time interval | Access | Source |
|---|---|---|---|---|---|
| FCR – frequency containment reserve | Market revenue | Power held available, activated automatically on the frequency deviation. | Four-hour blocks, six a day. Auction at 8:00 the day before. | 1 MW minimum, bids in 1 MW steps. Aggregation possible through a reserve provider. | RTE (the transmission system operator), Règles de marché (market rules), chapter 4 V02, art. 4.H.3.2 and 4.H.3.3in force since 1 January 2026 |
| aFRR – automatic frequency restoration reserve | Market revenue | Power adjusted continuously by RTE’s signal, plus the energy actually activated. | Capacity at hourly intervals, through a daily call for tenders. Energy in 15-minute intervals. | 1 MW minimum. For stationary storage, participation is experimental (transitional provisions): certificates are valid until 1 October 2027. | RTE, Règles de marché, chapter 4 V02, art. 4.H.4.2.1 and 4.S.2in force since 1 January 2026 |
| Balancing mechanism | Market revenue | An upward or downward modulation, called by RTE to balance the system. | Intraday bids, called continuously. | 10 MW as a general rule. A derogation admits 1 to 10 MW, but its “non-standardised” route is closed to stationary storage entities. | RTE, Règles de marché, chapter 2 V02, art. 2.J.1.3.5.1 and 2.S.1in force since 1 January 2026 |
| NEBCO – RTE’s demand response mechanism | Market revenue | A demand response block; the rules also provide for upward modulations – consumption shifted or brought forward – from a date RTE notifies. | Continuous declaration, from 9:30 the day before to 22:00 on the day. | Sign a participation agreement as a demand response aggregator and designate the associated balance responsible party – for a site connected to the distribution network, also sign an agreement with the network operator. 100 kW minimum per control interval. | RTE, Règles de marché, chapter 5 NEBCO, art. 5.D.1.1, 5.I.1 and 5.I.2in force since 1 September 2025 |
| Capacity mechanism | Market revenue | An availability commitment during the winter peak periods. | Delivery period from 1 November to 31 March. At most two auctions per period; for the first four, up to winter 2029–2030, RTE may hold only one. | Certification is mandatory. Below 1 MW, aggregation is mandatory; between 1 and 100 MW, it is the operator’s choice. | RTE, Règles de fonctionnement du mécanisme de capacité (capacity mechanism rules), art. E.5.4.1 and N.1annex to the order of 18 March 2026 |
| Peak shaving | Bill saving | Nothing: nobody buys. The site lowers its subscribed power under the network charges. | Continuous, over the peak hours from December to February. | No threshold, no prequalification, no third party. The only row in the table that depends on the site alone. | CRE (the French energy regulator), deliberation no. 2025-78, § 5.2.1.513 March 2025 |
Why do you need an aggregator?
An aggregator provides a service, and it opens a door. For an asset the size of an industrial site, aggregation is first of all an access condition: on most mechanisms the threshold is at least one megawatt, and a smaller asset gets in by aggregating.
What taking part in the mechanisms requires
Capacity mechanism
Below 1 MW, a storage facility must aggregate with others to form an entity of at least 1 MW; between 1 and 100 MW, the operator has the choice.
RTE, Règles de fonctionnement du mécanisme de capacité, art. E.5.4.1, annex to the order of 18 March 2026 Reserve providing group
On ancillary services, a reserve providing group can pool several sites. The reserve provider – who may be a third party – holds the participation agreement and answers for performance at group level, with the user’s prior written authorisation.
RTE, Règles de marché, chapter 4 V02, art. 4.F.2.4.1.1, in force since 1 January 2026
An aggregator therefore pools several assets to clear the thresholds, holds the participation agreement with RTE, and answers for the performance of the whole. It also carries the penalty risk in case of unavailability, which is why it keeps a share of the value produced.
NEBCO: what has changed since 1 September 2025?
NEBCO has been in force since 1 September 2025. It replaced NEBEF, the former name of the mechanism until 31 August 2025. The acronym says exactly what the mechanism covers, in the CRE’s own words – a notification of consumption block exchanges – and it does not mention storage:
« notification d’échanges de blocs de consommation »
NEBCO pays for demand response – a drop in consumption that a behind-the-meter battery can produce, by ceasing to draw from the grid. That distinction determines who declares, who measures and who gets paid.
What NEBCO changed
NEBCO
The NEBCO rules entered into force on 1 September 2025 and replace the NEBEF rules, approved in July 2023.
CRE, deliberation no. 2025-199, § 1.2, § 2.1.4 and decision, 23 July 2025 Upward modulations
The substantive change is the introduction of upward consumption modulations – shifting and bringing forward – where the mechanism previously covered demand response only. The volume declared upward cannot exceed the volume declared downward; the balance is assessed over seven calendar days for a remotely-read demand response entity, and over two days for a profiled entity.
CRE, deliberation no. 2025-199, § 2.1.2 and 2.1.4, 23 July 2025 Participation agreement
Taking part directly means signing a participation agreement as a demand response aggregator, designating the associated balance responsible party, signing an agreement with the network operator for a site connected to the distribution network, and declaring at least 100 kW of modulation per control interval.
RTE, Règles de marché, chapter 5 NEBCO, art. 5.D.1.1, 5.I.1 and 5.I.2, in force since 1 September 2025 When upward modulations open
Upward modulations only open from a date RTE notifies to participants one month in advance. Until a second notified date, scheduling them remains restricted during the capacity mechanism’s PP1 periods (its peak days) or stress periods.
RTE, Règles de marché, chapter 5 NEBCO, art. 5.C (dates NF30 and NF35), in force since 1 September 2025
Opening up to upward modulations is the change that matters for a storage asset. Until 2025, the general framework paid only for a drop in consumption. The new rules provide for planned charging to be eligible too, provided it is offset by an equivalent drop over the balance period – from a date RTE notifies, and outside the capacity mechanism’s peak days.
Peak shaving and demand response: what is the difference?
Both terms describe a drop in withdrawal from the grid, and they are often used interchangeably. Yet they differ in trigger, in beneficiary and in how the payment flows.
Triggered by the site
Peak shaving
Triggered by the site, for itself, when its own consumption approaches the power it has subscribed. No third party is involved, no threshold applies, and the gain shows as a reduction in the network charges.
Triggered from outside
Demand response
Triggered by an external signal, for the power system, and paid by a third party. It requires a declaration, a power threshold, a balance responsible party and a measurement of what was actually achieved against a reference curve.
Can several mechanisms be combined?
Yes – that is revenue stacking. It has a cost you should know before choosing: a megawatt committed in one place is not available elsewhere, and every strategy uses up a physical resource.
A reserved megawatt does not shave
The state of charge decides what is left to sell
Every strategy uses up cycles
Priorities are decided before commissioning
Why arbitrage is becoming a topic
Arbitrage is not in the table: it goes through none of the six mechanisms, only through the price of energy. Negative-price hours have multiplied on the French spot market. That is what makes shifting consumption worthwhile – and what makes arbitrage a question industrial sites are asking today.
The market context
Negative prices
Negative-price hours on the French spot market had never exceeded 102 hours a year up to 2022. They reached 147 hours in 2023, then 235 in the first half of 2024 alone.
CRE, note of 26 November 2024 on negative electricity prices, figure 2, series ending in the first half of 2024 Negative prices in 2025
The CRE counted 513 hours of strictly negative prices in France in 2025, 46% more than in 2024 (352 hours).
CRE, report no. 2026-07 on wholesale market monitoring (year 2025), p. 72, 17 June 2026 First half of 2026
RTE counted 407 hours of negative prices in the first half of 2026 – 10% of the time – against 363 hours in the first half of 2025 and 513 over the whole of 2025.
RTE, review of the first half of 2026 and outlook for security of supply, 16 July 2026
- 20180.1% of hours
- 20190.3% of hours
- 20201.2% of hours
- 20210.7% of hours
- 20220% of hours
- 20231.7% of hours
- H1 2024 – six months5.4% of hours
What monetisation requires of the installation.
Access conditions are not only administrative: they translate into sizing constraints, decided at the design stage and hard to correct afterwards. An asset sized without them can turn out to be ineligible for the mechanism it targets.
Four sizing constraints
Energy-to-power ratio
To take part in FCR, a reserve providing group made up exclusively of limited energy reservoirs must show a ratio of usable energy to reserve power strictly above 0.5 – more than 0.5 MWh of usable energy per megawatt. The usable energy is the band made available for frequency control, not the battery’s total energy capacity.
RTE, Règles de marché, chapter 4 V02, annex 4.A12 § 4.A12.5.1, in force since 1 January 2026 Limited energy reservoir
A battery whose stored energy would be exhausted in two hours by continuous activation of the full reserve is classed as a limited energy reservoir. Once exhausted, it must restore its stored energy no later than two hours after the return to normal state.
RTE, Règles de marché, chapter 4 V02, annex 4.A12, § 4.A12.2.5 and 4.A12.5.3.2, in force since 1 January 2026 Activation time
FCR requires activation to begin within two seconds and to be complete within thirty seconds, the entire reserve being released for any frequency deviation of at least 200 millihertz.
RTE, Règles de marché, chapter 4 V02, art. 4.G.2, in force since 1 January 2026 Minimum round-trip efficiency
To access the capacity volume reserved for carbon-free flexibilities, a storage site must not have a round-trip efficiency below 67%.
RTE, Règles de fonctionnement du mécanisme de capacité, art. F.2.2, annex to the order of 18 March 2026
Two ways of working with an aggregator.
Value sharing is set out in the contract: the proportion, and who carries the penalty risk. AlphaTech Energies offers two arrangements, and those terms are written down before installation.
The relationship stays with you
You keep your aggregator
AlphaTech Energies designs and integrates the asset so that it meets your aggregator’s conditions: energy sizing, control protocols, telemetry, prequalification. The commercial relationship and the value sharing stay between you and them.
A single point of contact
AlphaTech Energies holds the relationship
Aggregation is provided by our partner Tilt, and AlphaTech Energies remains your single point of contact – from study to operation. The value-sharing terms are written into the contract before installation.
Four points to get in writing, whatever the aggregator
Value sharing
The unavailability penalty
The commitment term and the exit terms
The priority between on-site use and market signal
What is moving right now.
Four changes are under way and will alter the access conditions. They are dated here, because a regulatory framework must be read alongside its date.
The four changes under way
Capacity mechanism
The capacity mechanism changes nature on 1 November 2026: from a decentralised scheme built on a capacity obligation to a centralised mechanism, where RTE is the contracting party and the demand curve is administered. The European Commission has authorised it until 31 March 2036.
CRE, deliberation no. 2026-24, § 1.1 and 1.2, 27 January 2026 Multi-year contracts
The first auction of the new mechanism to award multi-year contracts, for winter 2030–2031, is expected at the end of 2026 or early 2027. These contracts last at most 15 years. On 17 September 2026, the CRE proposed granting that maximum to new storage, provided its final investment decision is not taken before the application; the criteria are set by a ministerial order.
CRE, deliberation no. 2026-185 of 17 September 2026, § 2.3.2 and 3.3; public consultation no. 2026-07 of 9 April 2026 for the timetable, 17 September 2026 aFRR
Stationary storage takes part in aFRR on an experimental basis, under transitional provisions: the qualification certificates issued to these entities are valid until 1 October 2027, and entities that are non-compliant or judged unsatisfactory will not be renewed at that date.
RTE, Règles de marché, chapter 4 V02, art. 4.S.2, in force since 1 January 2026 Classification threshold
The general threshold of the balancing mechanism is due to fall from 10 MW to 1 MW. The date is a milestone RTE will notify with one month’s notice, with no calendar deadline to date.
RTE, Règles de marché, chapter 2 V02, art. 2.C and 2.J.1.3.5.1, in force since 1 January 2026
What has changed, and what is coming
TURPE 7 enters into force
New grids for the network charges – TURPE, the French tariff for the use of the public electricity networks – for four years, adjusted every 1 August. Their structure stays close to TURPE 6: the subscribed power component remains the saving lever that peak shaving pulls.
CRE (the French energy regulator), deliberation no. 2025-78 of 13 March 2025
NEBCO replaces NEBEF
The framework that pays for demand response changes its name and its rules: NEBCO, the demand response mechanism of the transmission system operator (RTE), replaces NEBEF, the former name of the mechanism until 31 August 2025. Any documentation that still speaks of NEBEF describes a mechanism that no longer exists.
The guichet ouvert closes above 100 kWp
Between 100 and 500 kWp, the guichet ouvert – the feed-in scheme open as of right without a tender – no longer applies: projects must bid in the “Petit PV” call for tenders. Selling to the grid stops being the default option.
ARENH comes to an end
The €42/MWh of regulated nuclear electricity – ARENH, the Regulated Access to Incumbent Nuclear Electricity – disappears after fifteen years. An industrial site’s purchase price no longer rests on a volume of nuclear electricity at a regulated price.
The Versement Nucléaire Universel replaces it
The Versement Nucléaire Universel (VNU), the universal nuclear payment that replaces ARENH from 2026, is a redistribution mechanism, not an access price. An industrial site can no longer build its electricity budget on a guaranteed tariff.
Law no. 2025-127 of 14 February 2025, the finance law for 2025
The new capacity mechanism framework is set
The decree of 31 December 2025, published on 1 January, writes into the French Energy Code the mechanism that takes over in November 2026 and its multi-year contracts (articles R. 316-35 to R. 316-42). This is the text that gives the capacity revenue of a storage asset its legal basis.
Decree no. 2025-1441 of 31 December 2025, Journal officiel no. 0001 of 1 January 2026
The PPE 3 is published
The PPE 3, France’s multiannual energy programme for 2026–2035, sets the country’s energy trajectories to 2035. It becomes the denominator of every “actual versus target”.
Injected solar falls to 1.1 c€/kWh
Up to 100 kWp, injected output is bought at this tariff, whether surplus or full export, and the self-consumption premium disappears. Self-consumption becomes the reference use of the output.
TURPE opens a component of its own for storage
The annual injection-withdrawal component becomes applicable. Optional, it is reserved for stand-alone storage connected at HTA (medium voltage, 1–50 kV), HTB 1 and HTB 2 (high voltage, above 50 kV): a battery coupled with generation or consumption is not eligible. It lowers the network bill of a battery that relieves local peaks and raises it when the battery worsens them, without the annual bill ever turning negative. Over the TURPE 7 period, it applies only in the listed zones: 320 injection zones and 1,121 withdrawal zones at HTA.
CRE, deliberations no. 2025-78 of 13 March 2025 and no. 2025-227 of 1 October 2025
A decree adjusts the capacity mechanism
It amends three articles of the framework set by the decree of 31 December 2025, including the one that sets eligibility for multi-year contracts (article R. 316-36 of the French Energy Code).
Decree no. 2026-771 of 13 August 2026, Journal officiel no. 0189 of 14 August
Upcoming
The capacity mechanism changes regime
The new scheme starts, with RTE as the single buyer; the old one covered its last delivery year up to 31 March 2026. For this winter, RTE selected capacity in a single auction, on 6 July 2026: a storage asset seeking capacity revenue now prepares for the next one.
Verified on 2 October 2026