At 18:47 on a cold February evening in 2024, something remarkable happened in the Swedish power grid. Electricity consumption surged as people came home, turned on the heating and started cooking dinner. At the same time, wind-power output was falling fast. The grid was approaching critical load.
Twenty years ago, this would have required starting up fossil-fuel peaking plants or imposing rolling blackouts. Instead, thousands of distributed energy resources across southern Sweden responded automatically within seconds: industrial heat pumps reduced their consumption, batteries in commercial buildings began to discharge, electric-vehicle charging was paused, and houses with solar panels and batteries fed power into the grid.
The grid stabilised. No one noticed any outage. No emergency power plants were needed. This was not science fiction. It was a virtual power plant (VPP) in action.
What is a virtual power plant?
A virtual power plant is exactly what it sounds like: a power plant that does not physically exist as a single facility. Instead, it is an aggregation of distributed energy resources — batteries, solar panels, electric vehicles, smart thermostats, industrial equipment — coordinated through software to act collectively as a single, flexible power source.
Distributed energy resources (DER): solar installations, battery storage systems, electric vehicles with bidirectional charging, smart HVAC systems and heat pumps, industrial equipment with flexible load, combined heat and power, and backup generation.
Aggregation platform: software that monitors, forecasts and controls thousands of individual assets, communicates with grid operators in real time, optimises for both the grid’s needs and the owners’ preferences, and handles settlement so the assets are compensated.
Grid services: frequency regulation (keeping the grid at exactly 50 Hz), voltage support, peak shaving, renewable-energy integration, congestion relief and emergency reserve capacity.
The magic happens in the orchestration: individual assets are small and intermittent, but aggregated together they provide reliable, controllable capacity that competes with traditional power plants — with far greater flexibility and lower environmental impact.
Why VPPs matter now
The energy transition is not just about adding solar panels and wind turbines. Those technologies are mature and cost-effective. The hard part is making renewable energy reliable when the sun and wind vary.
Traditional solutions — massive battery installations, hydrogen storage, fossil-fuel plants on standby — are expensive and often inefficient. VPPs offer a different approach: instead of building expensive infrastructure to handle the variation, use the distributed resources that are already being installed for other purposes.
The enablers are converging: technical maturity (IoT sensors and smart meters are everywhere, battery costs have fallen 90% in a decade, communication networks are reliable, AI can coordinate millions of devices in real time), policy support (EU regulations increasingly require flexibility markets, Swedish energy strategy encourages demand response), economic incentives (asset owners can earn from their flexibility, grid operators save billions, society gets cleaner air) and the pace of deployment (millions of electric vehicles, accelerating solar power, exploding heat-pump installations).
VPP architecture: how it works
Layer 1: Edge intelligence
Every connected asset needs local intelligence to respond safely: smart inverters on solar panels, battery management systems that understand charge level and degradation, EV charge control that knows the vehicle’s status and the owner’s departure time, and building controls that balance comfort against available flexibility. This intelligence ensures that VPP commands never compromise safety or the primary function. Your EV is not discharged if you need it for the morning commute. Your heat pump does not leave the house cold.
Layer 2: Aggregation and optimisation
The VPP platform sits between thousands of edge devices and the grid operator: real-time monitoring (tracks each asset’s status, forecasts solar production, loads and charging patterns), an optimisation engine (decides which assets to dispatch when, minimising cost and respecting all owner preferences), a communication layer (secure, redundant connections with minimal latency) and a settlement system (tracks each asset’s contribution and calculates compensation transparently).
Layer 3: Grid interface
The VPP presents itself to the grid operator as a single, controllable resource. Capacity offers might sound like: “I can deliver 50 MW of load reduction within 5 minutes, sustained for 4 hours” or “I can increase consumption by 30 MW to absorb surplus renewable energy.” With reliability metrics, predictable response times and participation in day-ahead and real-time markets, a well-designed VPP is in practice indistinguishable from a conventional power plant — except that it is cleaner, more flexible and geographically distributed.
The Swedish opportunity
Sweden is uniquely positioned to lead in VPP deployment.
Favourable conditions: Sweden already gets over 60% of its electricity from renewables (hydro, wind, nuclear), and more variable renewable power increases the need for flexibility. Heat-pump installations are accelerating, solar power is growing despite the northerly location, and the electric-vehicle share is among Europe’s highest. Sweden’s broadband, meter rollout and digital maturity make VPP coordination technically straightforward. The industrial sector has deep experience of energy-intensive processes. Svenska Kraftnät is progressive on grid modernisation and has mechanisms for DER participation in the balancing markets.
Remaining challenges: Minimum bid sizes in some markets exclude smaller VPPs. Settlement rules designed for large producers are a poor fit for distributed resources. The Swedish electricity market spans several bidding zones with different congestion patterns. Asset owners need clear, reliable revenue streams. And coordinating millions of assets requires detailed data on energy use, which raises requirements under GDPR.
Business models: who profits from VPPs?
1. Aggregator-owned model. A third-party company owns the platform and contracts asset owners. The owner earns passive income without investment; the aggregator profits from grid services, energy arbitrage and capacity payments. Example: an aggregator pays Swedish homeowners with solar panels and a battery €200–500 per year to let the batteries provide grid services during critical hours — comfort is always prioritised, but the surplus capacity earns money.
2. Grid-operator-led model. The local utility builds and operates the VPP, with intimate knowledge of the grid’s needs and a trusted customer relationship. Example: Fortum or Vattenfall could offer VPP participation in exchange for a discount on the electricity bill.
3. Distributed ownership. Emerging blockchain-based models where participants own the platform collectively — smart contracts compensate contributions automatically, governance is democratic. Mostly pilot projects today, but well aligned with Swedish cooperative traditions.
4. Behind-the-meter optimisation. Instead of aggregating across many owners, optimise energy flows within a single organisation’s portfolio — e.g. a property company with 200 buildings with solar panels, batteries and smart HVAC. Often simpler to adopt (one owner, one decision-maker) and still delivers significant grid value.
Technical deep dive: the hard problems
Forecasting distributed resources. Grid operators must be able to rely on VPP commitments, which requires accurate forecasts for thousands of locations. Solutions: machine-learning models (85–95% accuracy for solar, 80–90% for buildings), ensemble forecasts that quantify uncertainty, adaptive learning and graceful degradation when individual assets fail.
Large-scale real-time optimisation. Optimising the dispatch of 100,000 assets in real time is computationally demanding. Solutions: hierarchical optimisation (pre-filter assets into tiers), approximate methods (good enough fast beats perfect slow), edge pre-processing and specialised hardware.
Cybersecurity. A VPP is a massive attack surface — thousands of internet-connected devices controlling critical infrastructure. Solutions: zero-trust architecture, encrypted communication, AI-based anomaly detection, fail-safe default modes (devices revert to safe local operation on a disruption) and compliance with grid cybersecurity standards like IEC 62351.
Baseline accuracy. To know whether a VPP delivered the promised load reduction, you need to know what the load would have been without the intervention. Solutions: control groups, statistical baselines via regression models, high-resolution meter-based verification and conservative estimation to maintain credibility.
Battery degradation. Every charge cycle degrades lithium-ion batteries, and VPP participation accelerates it. Solutions: degradation-aware optimisation (use the battery only when the grid value exceeds the degradation cost), battery-health monitoring, compensation models that pay the owner for degradation, and newer chemistries (LFP) with a longer lifespan.
Real-world VPP examples
- Tesla Virtual Power Plant (South Australia): 50,000+ homes with Powerwall batteries, ~250 MW. It has prevented several potential blackouts and delivered grid services at a third of the cost of peaking plants. Insight: even small home batteries aggregate into grid-scale capacity.
- Sonnen (Germany): homeowners with a sonnenBatterie form a community with peer-to-peer trading; 10,000+ systems. Insight: VPPs can enable local energy communities, not just grid services.
- OhmConnect (California): demand response via smart thermostats, electric vehicles and batteries; 200,000+ participants. It prevented rolling blackouts during the 2020 energy crisis. Insight: VPPs can mobilise flexibility faster than building new power plants.
The way forward: VPPs in 2030
Extrapolating today’s trends, by 2030 VPPs could account for 20–30% of Sweden’s flexibility needs (today under 5%). Vehicle-to-grid (V2G) becomes standard and unlocks enormous mobile storage; AI forecasts reach 95%+ accuracy; clear regulations and standardised contracts mature; new applications emerge (microgrids capable of island operation, integration with hydrogen for long-term storage, cross-border VPPs). The societal impact: millions earning extra from their energy assets, a dramatically reduced need for fossil-fuel peaking plants and a more resilient grid.
Getting started: practical advice
- Industrial energy managers: Map the load profile (when is consumption flexible versus critical?), quantify the flexibility, understand the market opportunities in your region, contact aggregators and model the business case.
- Property owners/managers: Introduce smart building controls, understand the building’s thermal mass and HVAC flexibility, evaluate battery storage when installing solar, and start with a pilot in one building. Payback period typically 3–5 years; tenants’ comfort must never be compromised.
- Utilities/grid operators: Assess the customer base’s DER deployment, evaluate build-versus-buy-versus-partner for the platform, design the customer value proposition and pilot with interested customers.
- Technology providers: The ecosystem needs edge devices, communication platforms, optimisation software and cybersecurity solutions. Success requires a deep understanding of both energy markets and software, proven reliability and scalable architecture for millions of devices.
Conclusion: flexibility as infrastructure
Virtual power plants represent a fundamental shift in how we think about electricity infrastructure. Instead of building massive centralised plants to meet demand peaks that occur only a few hours a year, we coordinate the distributed resources that already exist in our homes, buildings, vehicles and industries.
This is not just economically more efficient — it is more resilient, more sustainable and more democratic. Energy flexibility becomes a service anyone can provide. The technology is mature, the economics favourable and the policy evolving. What is needed now is coordinated action: grid operators creating market opportunities, utilities developing offers, asset owners participating and technology providers building. The grid of the future will not resemble that of the past — it will be millions of active participants coordinating in real time.
How Hisland makes the VPP concept real
The virtual power plant described here is not theoretical for Hisland — it is a solution area where we have already delivered real impact.
Featured delivery: VPP feasibility study in Gothenburg. A client wanted to understand the viability of Sweden’s first comprehensive virtual power plant. We didn’t just write a report — we took ownership of the entire analysis: mapped interconnected energy resources across residential, commercial and industrial sectors, evaluated frequency-regulation opportunities specifically for Svenska Kraftnät’s balancing market, built return-on-investment models accounting for technology, market and degradation costs, and charted the path from pilot to full deployment. The result: a clear, actionable roadmap with a quantified business case that positioned the client as an innovation leader.
Why Hisland for energy solutions: multidisciplinary expertise (power systems, embedded control, communication networks, market mechanisms and business models under one roof), solution delivery rather than just advice, a local + global approach and systems thinking — we understand that VPPs are not just technology, but sociotechnical systems that require coordination between grid operators, asset owners, authorities and technology providers.
Our Energy & Smart Grids solution area covers VPP feasibility studies and adoption, microgrid design, demand response, battery-storage optimisation, charging infrastructure and grid integration, industrial energy management, renewable integration and grid modernisation.
This article is part of Hisland’s Eternal Evolution series. The VPP feasibility study mentioned is a real Hisland project.