Europe’s Smart Meter Divide Is A Flexibility Divide – And Grid Tech Providers Are Moving To Close It

The latest retail market monitoring report from the EU Agency for the Cooperation of Energy Regulators (ACER), finds that eight EU member states still had smart meter penetration below 50% in 2025. It reads like a retail story about dynamic tariffs, but for distribution system operators (DSOs) and their technology providers it is more fundamental: the clearest available measure of how ready each national grid edge is for flexibility.

Why smart meter penetration is the best proxy for flexibility readiness

Europe’s flexibility ambitions rely on millions of heat pumps, EV chargers, rooftop PV systems and home batteries responding to price and grid signals – none of which can be safely orchestrated without granular interval data at the connection point. Smart meters underpin dynamic price contracts and demand-side response, and are increasingly the most scalable source of low voltage (LV) network visibility for DSOs. Penetration is an imperfect measure – it says nothing about data granularity, latency, DSO access or whether meters are first- or second-generation – but no other grid edge metric is reported consistently across member states. It is the closest thing Europe has to a flexibility readiness index.

A two-speed grid edge

Approximately 60% of European households had a smart meter by 2024, with penetration rates above 80% in 15 EU countries – including Denmark at 100% and France at 94%. At the other end of the scale, Hungary’s 2024 penetration rate was 11% and Cyprus’s was 0%, though a mass rollout began in 2025. Germany is the starkest outlier: just 2% of households had an advanced smart meter in 2024, despite rollout becoming mandatory for some consumers in 2025. Europe’s largest power market – and one of its largest fleets of rooftop PV, heat pumps and EVs – has almost no consumer-side visibility at LV.

What the disparity means: blind spots at low voltage

Utilities across Europe consistently cite the same challenge: poor visibility of the LV network and insufficiently granular customer-side data. In leading markets, DSOs have moved from rollout to exploitation – using meter data for LV state estimation, topology identification, outage detection and hosting-capacity analysis, and preparing second-generation rollouts with edge computing. In lagging markets, DSOs are connecting EV chargers, heat pumps and PV to feeders they cannot see, resulting in conservative connection limits, over-investment in copper, connection queues and avoidable curtailment – while consumers without dynamic tariffs leave flexibility untapped exactly where networks need it most.

However, high penetration is not the same as high visibility. Many first-generation fleets, built for billing, deliver data with significant latency and route it to suppliers rather than grid operations. Even the frontrunners have a granularity problem – just a different one.

What this means for grid technology providers

Advanced metering infrastructure (AMI) vendors are already repositioning from metering hardware to grid-edge intelligence – expanding their own edge analytics and LV monitoring capabilities, or partnering with LV sensing, network analytics and distributed energy resource management (DERMS) specialists. For example, Itron and GE Vernova’s collaboration integrates Itron’s Grid Edge Intelligence portfolio with GE Vernova’s GridOS ADMS and DERMS software through a unified data model, bringing high-resolution data from behind the meter into the control room. The data point to three opportunities:

• Lagging markets are a different kind of procurement wave.

  Tens of millions of metering points in Germany, Poland, Belgium and elsewhere remain to be digitized, and tenders will specify flexibility use cases from day one: second-generation functionality, edge compute and interoperable DSO data access.

• Leading markets are a software and data opportunity.

  Above 90% penetration, value shifts to extracting operational insight from AMI data, integrating it with ADMS and DERMS, and preparing second-generation refreshes.

• Bridging solutions will win in the interim.
  Providers of secondary substation and LV feeder monitoring, EV charger and inverter data, and analytics that infer LV conditions from sparse meter data can deliver visibility on constrained feeders now and will be well placed as rollouts mature.

What it means for utilities

For utilities, the first step is to treat AMI as grid infrastructure rather than a billing asset, with business cases that capture network benefits – deferred reinforcement, faster connections and reduced curtailment – not just meter-reading savings. Securing the data matters as much as deploying the device: near-real-time DSO access to granular data depends on data governance, communications architecture and head-end design.

Targeting rollout and complementary LV monitoring where distributed energy resource (DER) growth and congestion are highest will deliver value sooner. Finally, each utility’s position on the penetration curve shapes its agenda: lagging DSOs can leapfrog by specifying flexibility-ready systems from the outset, while frontrunners must plan second-generation upgrades before first-generation fleets constrain flexibility markets.

The Verdantix view

ACER’s figures are a map of where Europe’s grid edge is ready for flexibility and where it is operating blind. Penetration is necessary but not sufficient: the winning utilities will turn meter data into LV network intelligence, and the winning technology providers – through organic expansion or well-chosen partnerships – will help them do it.

To learn more about unlocking the energy flexibility opportunity, read Verdantix Best Practices: Unlocking The Energy Flexibility Opportunity.