A virtual power plant is not a place. It is a decision layer.
The name is misleading. A virtual power plant has no chimney, no turbine hall, no physical address you could visit. It is software coordinating thousands of small energy assets — rooftop solar, commercial battery packs, EV charging depots, flexible industrial loads — and making them behave, from the grid's perspective, like a single dispatchable generator.
The underlying mechanic is aggregation. A 50 kWh battery in a logistics warehouse is too small to matter to the grid. A thousand of them, orchestrated in real time by a dispatch intelligence that knows which ones are charged, which loads are flexible, and what the grid needs in the next fifteen minutes — that is a 50 MW resource. That is a grid participant. That is a VPP.
Software platforms now account for 45.8% of the entire VPP market value. The intelligence layer is the product. The batteries are just the raw material it works with.
Precedence Research — Global VPP Market Analysis, 2025This matters because the economics of hardware are changing fast. LFP battery costs fell 40% in 2024 alone. India's latest BESS auction tariffs have dropped 65% in two years. When hardware commoditises, the value migrates to whoever controls the orchestration. The physical asset becomes fungible. The intelligence running it does not.
Three things a VPP does that a battery alone cannot
Grid frequency deviates when supply and demand fall out of balance. Primary frequency response requires an asset to inject or absorb power almost instantly. Batteries managed by a VPP can do this at scale, across hundreds of sites, with predictable availability — which is what grid operators actually need.
India's Day Ahead Market price spreads have grown fivefold since 2022, reaching INR 2.4 million per MWh in 2024. A VPP sees those spreads in advance, models when to charge across its entire fleet, and dispatches into the high-price windows. A standalone battery sees only its own meter.
RMI research shows that an Indian BESS operating across energy arbitrage, ancillary services, and transmission deferral simultaneously generates margins 24 to 70% higher than under an energy-only strategy. The stack requires coordinated intelligence across all three — a VPP operating system, not a battery controller.
Each of these functions individually justifies the cost of the software layer. Together they represent the difference between a battery asset that earns a marginal return and one that earns a compelling one. The arithmetic is not subtle: RMI's modelling shows that at higher BESS cost tiers, an energy-only strategy barely clears the investment hurdle. The same asset under full value stacking exceeds it comfortably.
India is the fastest-growing VPP market in Asia Pacific. The policy is now moving fast.
For years, distributed storage in India had one clear role: provide backup power when the DISCOM could not. That was the entire revenue story. A battery would sit idle for most of its life, waiting for an outage that might come once a week, and the economics reflected it. Low utilisation. Thin returns. Limited deployment.
That picture is changing structurally, not incrementally. 2025 has seen a sequence of regulatory shifts that collectively redesign the commercial landscape for battery storage in India.
What this means for fleet operators and C&I battery owners
Every battery asset that gains formal ancillary services access stops being a cost centre and becomes a revenue source. The shift is not theoretical — India's Day Ahead Market delivered a 17% IRR from energy arbitrage alone for a system installed in 2024. Add ancillary services and that number improves further.
The question is no longer whether the market will open. It is whether you will have the aggregation and dispatch layer in place when it does. That layer takes 18 to 24 months to build and certify. It is not something you bolt on at the last minute. The companies that start now will be certified participants when the market formally opens. The ones that wait until after the framework is published will miss the first contract cycle.
The revenue stack for a managed battery asset in India
The table below shows the revenue streams available to a battery asset under different operating models. Under current rules, most commercial assets in India access only the first column. The regulatory direction is toward enabling all of them — and the sequence of change has been faster than most analysts predicted eighteen months ago.
RMI's analysis of Indian BESS economics found that under a full value stack — energy, ancillary services, and transmission and distribution deferral — project margins run 24 to 70% against all reported cost benchmarks. Under an energy-only strategy, the same assets are barely viable at higher cost tiers. The gap between these two scenarios is not hardware. It is dispatch intelligence.
EV fleets are the sleeping giant of India's grid flexibility story
By 2030, India is projected to have 70% of commercial vehicles and last-mile delivery fleets running on electric power. That is not just a transport transition. It is the creation of millions of battery units, parked for hours every day at predictable locations, connected to the grid.
V2G — vehicle-to-grid — turns that parked EV fleet into a dispatchable storage resource. An e-rickshaw charging overnight. A logistics van idle at a depot from 10am to 3pm. An e-bus parked between morning and evening peak routes. Each of these assets, individually, is noise. Aggregated and intelligently dispatched, they represent the kind of distributed storage capacity that can reshape India's grid flexibility picture without building a single new power plant.
By 2030, V2G could enable up to 20 GW of distributed storage capacity in India — equivalent to roughly 10% of peak demand — if fleet-based adoption scales as projected.
EMobility Academy — V2G India Analysis, 2025The challenge is the same as it is for stationary BESS: the aggregation layer. Fleet operators cannot individually bid into ancillary markets. They need an entity that can see their full fleet's state of charge in real time, model dispatch availability, manage battery degradation across the charge-discharge cycle, and respond to grid signals within seconds. That entity is the VPP operator.
When the commodity cost falls, the intelligence layer becomes more valuable. Not less.
There is a pattern in every commodity compression cycle. When hardware gets cheap, the race to the bottom begins. Margins compress on cells, on racks, on EPC. The underbidding that IEEFA documented in India's BESS tenders is precisely this dynamic playing out in real time.
The companies that survive commodity compression are the ones that built the non-commodity layer before it started. In energy storage, that layer is software: the dispatch intelligence, the predictive BMS, the aggregation logic that allows distributed assets to behave like a single coherent resource.
Software does not get cheaper when cell prices fall. It gets more valuable. Because when there are more batteries in the field — which falling prices guarantee — there are more batteries that need to be managed intelligently. The total addressable market for orchestration software grows exactly as fast as hardware adoption accelerates. The two curves are, by construction, perfectly correlated.
The software flywheel: how scale compounds value in VPP platforms
More assets under management → richer operational data → better predictive models → more accurate dispatch commitments → better ancillary service performance → more credible bids → more assets under management. The entity that enters this cycle first, and executes it competently, builds a compounding advantage that becomes extremely difficult to dislodge. This is why the first two years of commercial VPP market operation are likely to define the competitive structure of the Indian market for a decade.
The analogous dynamic played out clearly in cloud infrastructure, in ride-hailing, and in food delivery. First-mover advantage is not guaranteed — execution quality matters — but the combination of first-mover positioning and competent execution is historically very durable in platform markets. VPP aggregation is a platform market.
We built the aggregation layer.
Not as an afterthought.
TEC has been building distributed battery intelligence since day one. FlexiTwin creates a real-time digital twin of every battery pack in the field — state of charge, state of health, thermal state, degradation trajectory. FlexiMax manages the physical pack. The software layer runs on top of it, connecting individual assets into a coordinated fleet.
That architecture was designed from the start for the world the regulatory framework is now catching up to: where distributed battery assets participate in grid services markets, where EV fleets are grid resources, and where the intelligence managing them earns as much as the hardware it runs on.
Real-time state-of-charge, state-of-health, and thermal modelling for every pack in the fleet. Continuous degradation tracking updates each pack's available capacity and preferred operating window in real time. The data foundation that makes dispatch decisions possible — and auditable.
Charge and dispatch scheduling optimised simultaneously against DAM prices, ancillary signals, demand tariffs, and battery degradation curves. Not rule-based. Model-driven. The optimiser runs continuously against a rolling 48-hour forecast horizon, updating as market prices, grid signals, and fleet state change.
FlexiPack assets are built to operate as a coordinated fleet. The aggregation logic is part of the product architecture, not an integration layer bolted on by a third party. New assets join the fleet and are available for dispatch within hours of installation, not weeks.
Active participation in CERC consultation processes and NLDC technical trials. TEC submitted technical comments to CERC's March 2025 distributed storage consultation. Compliance documentation in progress for the anticipated aggregator licence framework. We are not preparing for regulation — we are helping write it.
The window to get on the right side of this market is not indefinite
When CERC's ancillary services framework for distributed storage opens commercially, the first question every fleet operator and C&I battery owner will face is: do I have an aggregation partner who can put my asset into these markets?
The second question will be: does my battery management system generate the telemetry that NLDC requires? Sub-second state-of-charge reporting. Real-time availability declaration. Verified response time logs. These are technical requirements that need to be built into the hardware and software stack from day one. They cannot be retrofitted economically.
The companies that arrive at this market with clean data, certified assets, and an aggregation partner in place will earn from it immediately. The companies that arrive six months later, scrambling to retrofit their BMS and find an aggregator, will spend a year catching up. In a market where regulatory windows open once and early movers capture the initial contracts, that delay is commercially significant.
What we are building toward
Every TEC FlexiMax installation is being built to a standard that can participate in grid services markets as soon as those markets formally open to distributed assets. The BMS generates the telemetry. The FlexiTwin maintains the state model. The dispatch logic is ready to respond to grid signals. We are not waiting for the regulation to finalise before building for it.
We have 12,000 batteries deployed across six industries. That is a fleet. When the regulatory door opens, we want that fleet to walk through it immediately — not spend 18 months seeking certification.
1. Precedence Research — Virtual Power Plant Market Size, Share and Trends, October 2025. Global market sizing, CAGR projections, and software platform revenue share analysis.
2. IEEFA — The Standalone Energy Storage Market in India: Costs, Contracts, and Competitive Dynamics, April 2025. Underbidding patterns, BESS tender analysis, and tariff trajectory data.
3. Ember Energy — The Age of Storage: Batteries Primed for India's Power Markets, August 2025. IRR modelling, DAM price spread data, and revenue scenario analysis.
4. Rocky Mountain Institute — Growing Markets for Grid-Connected Battery Storage in India, October 2024. Value stacking analysis and margin improvement quantification across service categories.
5. CERC — Terms and Conditions of Tariff (Second Amendment) Regulations, December 2025. Integrated Energy Storage Systems framework, revenue-sharing mechanism, and Regulatory Sandbox provisions.
6. CERC — Ancillary Services Regulations (Third Amendment), 2022. Formal inclusion of energy storage resources in ancillary services eligibility framework.
7. Ministry of Power — Viability Gap Funding Scheme for BESS and ISTS Charge Waiver Notification, June 2025. 30 GWh sanction and IRR impact analysis.
8. Ministry of Power — National Framework for Promoting Energy Storage Systems, 2023. Original VGF scheme structure and procurement targets.
9. EMobility Academy — V2G in India 2025-2030. Fleet V2G capacity and revenue projections.
10. Mercom India — Top Policies Shaping the Indian BESS Market in 2025, December 2025.
