The grid problem is not
the same in every market.
A British DNO is short of headroom on a feeder. A Dutch operator has a connection queue and no capacity to sell. An Australian distributor has too much solar at noon. A Gulf utility has ten million smart meters and no market to settle against. Pick your region below. Each one takes under a minute to read.
You contracted nine gigawatts.
You dispatched twenty two gigawatt hours.
Great Britain runs the largest local flexibility market in the world and still cannot get the volume out of it. In 2024 the electricity networks secured a record 9 GW of contracted flexibility. Across the whole year, 22 GWh was actually harnessed. The contract is not the constraint. Delivery is.
You have moved from network operator to system operator, you run tenders, and Ofgem now holds you to Flexibility Market Rules through the Market Facilitator. The rules are settling. The megawatt hours are not.
NESO's own winter review is blunt about why. Across winter 2024/25 the Demand Flexibility Service accepted 5,449.6 MWh of bids and 3,917.7 MWh turned up, an accuracy of 71.9 per cent. Over 99 per cent of registered meter points were manually initiated: a text message asking a human to switch something off. 91 per cent of domestic delivery came in below 1 kW per meter.
Meanwhile half hourly settlement reform is coming for your retail business on a fixed date, not a consultation timeline.
AmpVerve orchestrates the device directly across roughly 33 vendor clouds covering solar inverters, home batteries, EVs, chargers and heat pumps. A dispatch instruction becomes a setpoint on real hardware, not a request to a customer.
That is the difference between 1 kW of hoped-for behaviour change and 7 kW of charger that answers on time, every time, and reports what it did at half hourly granularity per asset.
AmpVerve is a registered flexibility provider with SSEN, under designation VAOU_WA, and with UK Power Networks. It is a BSC Party with qualification in assessment, and applications are lodged for the Elexon virtual party roles.
- Per asset, half hourly. Every asset carries its own settlement grade half hourly series, which is the unit MHHS will actually settle on.
- Charger side: OCPP 1.6J, 2.0.1 and 2.1, plus ISO 15118 for vehicle to charger identification and bidirectional control.
- Tenant side: if you white label, your customers are isolated by a 78 test gate that includes 27 cross tenant attack cases and runs on every build.
- Commercially: AmpVerve holds the DNO registrations, so an asset in SSEN or UKPN territory can be onboarded without you standing up a market entity.
Fourteen thousand companies are queuing
for a wire that takes a decade to build.
In the Netherlands the regional grid operators are holding 14,044 connection requests for electricity offtake, worth 9 GW. TenneT is holding another 212 requests worth 38 GW. New high voltage infrastructure has a lead time of 8 to 12 years. Nobody is building their way out of this queue. The only capacity available before 2035 is capacity that already exists and is not being used at the right moment.
The Dutch government's own February 2026 assessment says it plainly: the terms of flexible contracts, the limited financial benefit and the uncertainty about when flexibility will actually be called are a barrier to companies signing them. Connected parties have no location specific view of how often they would be curtailed, so they cannot underwrite the risk.
Germany went the other way and made it compulsory. Since 1 January 2024, section 14a EnWG stops a network operator refusing or delaying a heat pump, battery, air conditioner or private charge point over 4.2 kW, in exchange for the right to dim it. You now have an obligation to connect and a control duty you have to execute, on hardware you do not own.
And the interface is different in every country you operate in.
A flexible connection is only worth signing if the asset genuinely respects the limit and can prove it afterwards. AmpVerve holds the setpoint on the device, across roughly 33 vendor clouds, and produces settlement grade half hourly evidence per asset that the limit was respected.
The country configuration carries Germany, France, the Netherlands, Sweden, Norway and Ireland as first class markets, each with its own regulator, licensing route, metering arrangement, DER protocol, privacy regime, payment rail, currency and locale. The German 4.2 kW floor is a setpoint, not a disconnect, and is handled as one.
AmpVerve has delivered work into the IEA Task 53 programme, generating charging setpoints directly from a Swiss distribution system operator's dynamic network tariff. That is the same problem as a Dutch time based transport right, expressed in a different currency of constraint.
- Contract types differ, the asset does not. A Dutch CSC or bid obligation contract, a German section 14a dimming instruction and a Swiss dynamic network tariff all resolve to the same thing: a power limit on a device in a time window.
- Protocols: OCPP 1.6J, 2.0.1 and 2.1 on the charger, ISO 15118 to the vehicle.
- Proof: per asset half hourly series, retained, so a curtailment can be evidenced to the operator and settled with the customer.
- Scope: AmpVerve holds no market registration outside Great Britain. In Europe it integrates behind your licence, not instead of it.
Minus 209 megawatts at noon.
3,274 megawatts at half past seven.
South Australian operational demand hit a record low of minus 209 MW on 19 October 2024. Four months later, on 12 February 2025, the same state peaked at 3,274 MW at 7:30 PM, with rooftop solar contributing an estimated 102 MW. You do not have a solar problem. You have a timing problem, and the fleet that could fix it is already installed in your customers' garages.
South Australia was the first jurisdiction to build an emergency backstop to curtail distributed PV for system security. AEMO's own November 2025 assessment of how it performs: around 80 per cent of Flexible Exports sites pass capability tests, and 70 to 85 per cent of correctly installed sites actually respond to an at-scale activation. Net result, roughly 56 to 68 per cent of the devices required to have a backstop may respond when you call it.
Meanwhile the price signal has stopped working. In Q3 2025, 18.9 per cent of all NEM dispatch intervals cleared at or below zero. Between 9am and 5pm, Queensland was negative in 66 per cent of intervals.
And AEMO is explicit that more rooftop PV will not touch your evening maximum unless it is coupled with storage.
Australia added 183,245 home batteries in the second half of 2025 alone. In the same year 103,270 battery electric vehicles were sold, each carrying several times the energy of the average home battery, and almost none of them are in a VPP.
AmpVerve orchestrates both. It carries IEEE 2030.5 with CSIP-AUS and AS/NZS 4777.2 in its country configuration, so a flexible export instruction and a charging setpoint are handled by the same control path, on the same asset model, with the same evidence trail.
AmpVerve runs a residential V2X pilot in Melbourne, and a UK residential pilot with a genuinely bidirectional V2G charger operating daily. AmpVerve holds no AEMO or AER registration and does not claim one. In Australia it operates behind your market entity.
- DER side: IEEE 2030.5 with the CSIP-AUS profile, which is already the active DER management mechanism for new sites in South Australia.
- Inverter side: AS/NZS 4777.2 region settings held in country configuration, not hard coded.
- Vehicle side: OCPP 1.6J, 2.0.1 and 2.1 with ISO 15118, so the car is a dispatchable asset rather than an uncontrolled evening load.
- Confidence: the point of orchestrating the device cloud directly is that a response rate near 60 per cent is a data path problem, not a physics problem.
There is no market to settle against.
One regulator is building one.
Across the Gulf there is no wholesale flexibility market, no capacity market and no residential time varying tariff. V2G Hub tracks 157 projects, over 12,200 chargers and 27 countries, and not one Middle East or North Africa country appears in the listing. That is not a gap in the research. That is the market. Which makes the one exception worth reading carefully.
Saudi Arabia installed or replaced more than ten million smart meters in a thirteen month deployment, roughly four million of them locally manufactured. It has no demand response programme. Metering was never the binding constraint. No published source claims those meters can control or curtail load, and none should.
Egypt's regulator publishes a residential tariff, effective April 2026, that is a pure consumption band structure from 68.0 to 258.0 piastres per kWh with no time of use, peak or dynamic component. DEWA residential pricing is a consumption slab with no time dimension either.
Oman opened the GCC's first electricity spot market on 1 January 2022, with half hourly wholesale price discovery. It has no demand side participation, no DR unit registration and no balancing or ancillary services market. Dubai's demand side management strategy runs twelve programmes, and not one of them is a dispatchable load programme.
The Abu Dhabi Department of Energy's Demand Response Policy, effective 1 January 2024, sets a strategic target of 200 MW of contracted DR capacity by 2030 and an interim 80 MW by 2027. The accompanying regulations make the Department the sole issuer of Demand Response Licences and explicitly permit a DR Provider to be an aggregator representing a portfolio of customers. Third party aggregation is legal, in writing.
Phase 1 has already run. Ten events in 2024 delivered an average peak reduction of 106 MW and a maximum of 210 MW against 137 MW contracted, from twelve large commercial and industrial facilities and forty two residential consumers.
The licence conditions ask for a privacy and data security policy aligned to UAE data protection law, evidence of customer consent, and a demonstration that demand response will not degrade supply to the sick and the elderly. Those are software obligations, and they are the artefacts AmpVerve already produces: per tenant isolation, per asset consent, per asset half hourly evidence.
- Jordan is the live case. 1,196 MW of distributed solar across 82,780 systems, roughly 9 per cent of national electricity sales. Net metering ended in September 2024, and prosumers now choose between wheeling, net billing, zero to grid, and buy all sell all. Four settlement models, per site.
- Shams Dubai: 725 MW connected across 8,430 buildings, on a single distributed programme.
- Sequence honestly. Abu Dhabi's own efficiency strategy places Vehicle to Grid Charging Infrastructure in its Outlook Post 2030 section. Solar, storage and cooling load come first. AmpVerve orchestrates those today.
- Scope. AmpVerve holds no licence or market registration anywhere in MENA and does not claim one. Adding a jurisdiction is a configuration record: regulator, licensing route, metering, DER protocol, privacy regime, payment rail, currency, locale.
You need 224 gigawatts in ten years.
The queue will not deliver them.
NERC's ten year summer peak demand growth forecast has run 55 GW, then 80 GW, then 132 GW, and now 224 GW across four successive assessments. Around 2,000 GW of generation and storage sits in interconnection queues, and only 13 per cent of the capacity that requested interconnection between 2000 and 2020 has reached commercial operation. The only resource that can be connected inside this decade is already behind your customers' meters.
Order 2222 was issued in September 2020. PJM's implementation lands in 2028. As of early 2026, no state has fully developed rules for ongoing coordination between distribution utilities and DER aggregators. In CAISO, not one Schedule 4 communications protocol has been filed.
SPP complied on operational coordination by allowing distribution utilities to override DER dispatch, without proposing any requirement for the utility to tell the aggregator it happened. Across every RTO, the specifics of aggregator to utility communication were left out of the tariffs.
The result is visible in the market data. VPP deployments, offtakers and monetised programmes each grew more than 33 per cent in a year while capacity grew 13.7 per cent. The market is broadening faster than it is deepening.
Wood Mackenzie names the blocker on residential VPP capacity precisely: third party data access for enrolment and market settlement. That is not a market design problem you can wait out. It is a software problem, and it is what AmpVerve is.
Roughly 33 vendor clouds across solar, batteries, EVs, chargers and heat pumps. A settlement grade half hourly series per asset, retained and exportable for measurement and verification. Multi tenant isolation enforced by a 78 test gate that includes 27 cross tenant attack cases, so a programme run for one affiliate cannot see another's customers.
AmpVerve holds no US market registration and does not claim one. It runs behind your registration, under your brand, with the customer relationship staying yours.
- DER side: IEEE 2030.5. Vehicle side: OCPP 1.6J, 2.0.1 and 2.1 with ISO 15118.
- Settlement: per asset, per interval, so an aggregation can be evidenced down to the individual device that did or did not respond.
- Override handling: where a distribution utility can pre-empt dispatch, the per asset record shows what was instructed and what actually happened. That is the difference between a dispute and an audit trail.
- Security posture, stated plainly: AmpVerve is not SOC 2 or ISO 27001 certified and will not imply otherwise. What it can evidence is the isolation test gate and its 27 cross tenant attack cases, running on every build.
Ten countries are configuration records,
not marketing copy.
Most platforms are built for one market and localised afterwards. AmpVerve carries the regulator, the licensing route, the metering standard, the DER protocol, the privacy regime, the payment rail, the currency and the locale for ten countries as first class product data. Adding a country is a configuration record with a named owner, not a rewrite.
| Country | Regulator | Licensing route | DER and metering protocol | Currency |
|---|---|---|---|---|
| United Kingdom | Ofgem | Electricity supply licence under the Electricity Act 1989, or licence-lite virtual lead party | SMETS2, EREC G99 and G100 | GBP |
| Ireland | CRU | CRU electricity supply licence or aggregator agreement | DLMS COSEM, EN 50549-1 and 50549-2 | EUR |
| Germany | BNetzA | EnWG section 5 notification plus aggregator agreement | EEBus, EN 50549, VDE-AR-N 4105 | EUR |
| France | CRE | Autorisation de fourniture under Code de l'energie L333-1 | DLMS COSEM, EN 50549, NF C 15-100 | EUR |
| Netherlands | ACM | Leveringsvergunning under the Elektriciteitswet 1998, or aggregator under the Energiewet | DLMS COSEM and DSMR P1, Netcode Elektriciteit | EUR |
| Sweden | Energimarknadsinspektionen | Trading registration plus balansansvarsavtal | DLMS COSEM, EN 50549, Svk FIKS | SEK |
| Norway | RME within NVE | Omsetningskonsesjon under the Energiloven | DLMS COSEM, EN 50549, NEK 399 | NOK |
| United States | FERC and state PUCs | FERC Order 2222 plus state PUC certification | IEEE 2030.5 with CSIP, IEEE 1547 | USD |
| Australia | AER, AEMC and AEMO | AER retail authorisation under the NERL | IEEE 2030.5 with CSIP-AUS, AS/NZS 4777.2 and 4755.3.1 | AUD |
| New Zealand | Electricity Authority | EIPC 2010 retailer or aggregator registration | IEEE 2030.5 with CSIP-AUS, AS/NZS 4777.2 and 4755.3.1 | NZD |
Every country also carries its privacy regime in the same record: UK GDPR and the Data Protection Act 2018 in Britain, EU GDPR with national additions across Europe, CCPA and CPRA with state regimes in the United States, the Privacy Act 1988 and Australian Privacy Principles in Australia, the Privacy Act 2020 in New Zealand. EV charge communication is OCPP with ISO 15118 in all ten. This is the product's regulatory configuration, not a claim of registration. AmpVerve holds market registrations in Great Britain only.
What AmpVerve can prove,
and what it will not claim.
Utility procurement teams check. It is faster for both of us if the boundary is written down.
Evidenced today
- Device orchestration across roughly 33 vendor clouds spanning solar, batteries, EVs, chargers and heat pumps, evidenced by 429 test functions across 35 files.
- Multi tenant isolation enforced by a 78 test gate that includes 27 cross tenant attack cases.
- Settlement grade, per asset, half hourly data handling.
- A live UK residential pilot running a genuinely bidirectional V2G charger daily, and a second residential V2X pilot in Melbourne.
- Registered flexibility provider with SSEN and UK Power Networks. BSC Party with qualification in assessment. Applications lodged for the Elexon virtual party roles.
- OCPP 1.6J, 2.0.1 and 2.1, ISO 15118, IEEE 2030.5 with CSIP-AUS, and AS/NZS 4777.2 in the country configuration.
- Work delivered into the IEA Task 53 programme, generating charging setpoints from a Swiss distribution system operator's dynamic network tariff.
Not claimed, and will not be
- Qualified, certified or accredited under any scheme.
- SOC 2 or ISO 27001.
- Any AEMO or AER registration.
- Any market participation outside Great Britain.
- Balancing Mechanism access. The Elexon interfaces are built, the qualification is in assessment, and until it completes this route is not open to customers.
Everything on this page that describes a market is sourced to the operator, regulator or programme that published it. Where a figure could not be verified against a primary source, it is not here.
Tell us the constraint.
We will tell you what we can move.
Send us a feeder, a queue position, a minimum demand curve or a settlement deadline. You get back an honest assessment of what device orchestration changes and what it does not.