Karnataka has finalized distributed solar regulations that raise the net metering ceiling to 1 MW across all consumer categories and remove a proposed storage mandate for projects above 10 kW, clearing a major regulatory hurdle for commercial and industrial rooftop deployment in India’s second-largest solar state. The Karnataka Electricity Regulatory Commission’s (KERC) final Grid Interactive Distributed Solar Photovoltaic Plants Regulations, 2026 replace a draft that would have capped net metering at 500 kW and required batteries on larger installations, a shift that directly improves project economics for mid-scale rooftop and ground-mount systems. By making storage optional rather than compulsory, the Commission has signaled that grid integration costs should be managed through market mechanisms and future ancillary-service markets rather than upfront capital requirements on developers.
Regulatory Backdrop and the Draft-to-Final Pivot
Karnataka’s distributed solar framework has evolved through multiple regulatory cycles since the state first introduced net metering in 2014. The draft regulations circulated in late 2024 proposed a 500 kW net metering limit – down from the 1 MW ceiling that had applied under earlier orders – and introduced a novel requirement that any DSPV project exceeding 10 kW install energy storage sized at a minimum of 25% of the solar capacity with two hours of discharge duration. That storage mandate would have added roughly ₹4-6 crore per MW of solar capacity at current lithium-ion battery prices, a cost burden that industry stakeholders argued would render most commercial rooftop projects unviable without a corresponding revenue stream for stored energy.
The Commission received over 120 written submissions during the consultation period, with developer associations, captive power consumers, and distribution licensees (BESCOM, HESCOM, MESCOM, GESCOM, and CESC) all flagging the storage requirement as premature in the absence of defined ancillary service markets or time-of-day tariff signals that would allow storage to earn a return. KERC’s final order, issued in March 2025, cites these responses explicitly: the Commission concluded that mandating storage without a supporting market framework would “increase the cost of renewable energy integration without commensurate benefit to the grid.” The 1 MW net metering cap restores the limit that existed under the 2019 regulations, effectively reversing the proposed contraction.
Critically, the final regulations retain the gross metering option for projects above 1 MW and preserve the banking facility for captive consumers, allowing unused solar generation to be carried forward across billing cycles within the same financial year. The settlement period remains annual, and the tariff for net export continues to be the average power purchase cost (APPC) of the respective distribution licensee – currently in the range of ₹3.50-4.00 per kWh across Karnataka’s five ESCOMs – rather than the higher retail tariff that commercial and industrial consumers pay. That APPC-linked export rate remains the primary economic constraint on mid-scale projects, since the value of exported energy is roughly half the avoided-cost savings from self-consumption.
Grid Integration Economics and the Storage Timing Question
Karnataka’s decision to drop the storage mandate reflects a broader tension in Indian power sector reform: states are under pressure to integrate rising variable renewable shares – Karnataka already exceeds 30% annual solar and wind penetration – but the institutional infrastructure to value flexibility remains embryonic. The Central Electricity Regulatory Commission (CERC) has issued ancillary services regulations and is piloting a day-ahead market for tertiary reserves, yet participation by behind-the-meter storage is not yet enabled in any state. Without a clear revenue stack – frequency regulation, peak capacity payments, or arbitrage under dynamic tariffs – a mandated battery becomes a sunk cost rather than an asset.
By comparison, states such as Gujarat and Maharashtra have taken a market-first approach: Gujarat’s 2023 distributed solar policy allows net metering up to 1 MW and explicitly permits storage to participate in the state’s deviation settlement mechanism, while Maharashtra’s recent tariff order introduced time-of-day rates for high-tension consumers that create an implicit arbitrage signal for batteries. Karnataka’s final regulations do not preclude storage; they simply make it a commercial choice. That points to a de facto segmentation: developers with strong load profiles that align with solar generation – data centers, cold storage, continuous-process industries – will continue to build without storage, while those facing high evening peaks or demand charges may add batteries voluntarily once time-of-day tariffs sharpen.
If this trend holds, the next regulatory lever in Karnataka will likely be the introduction of dynamic retail tariffs for HT consumers, a step the Commission has signaled in its tariff philosophy but not yet implemented. A 2024 CERC staff paper estimated that effective time-of-day price spreads of ₹2.50-3.00 per kWh between solar and peak hours would make two-hour behind-the-meter storage commercially attractive at current battery costs of roughly ₹5.5-6.5 crore per MWh. Karnataka’s current peak-off-peak differential for HT consumers is under ₹1.50 per kWh, well below that threshold.
Who This Affects
- Commercial & Industrial Rooftop Developers: The 1 MW net metering cap restores project sizes that match typical large-factory roof areas (8,000-10,000 m²), enabling single-installation coverage of 60-80% of annual consumption for energy-intensive users without splitting projects across multiple connection points.
- Distribution Licensees (ESCOMs): BESCOM and peers avoid the near-term operational complexity of managing thousands of small mandated batteries but must now accelerate feeder-level visibility and forecasting tools to handle higher reverse power flows on 11 kV networks where 1 MW injections can exceed local minimum load.
- Storage Integrators and Battery OEMs: The optional-storage framework shifts the sales pitch from compliance-driven to value-driven; vendors must now demonstrate payback through demand-charge reduction or future market participation rather than regulatory obligation, lengthening sales cycles but potentially expanding the addressable market to quality-focused buyers.
- Captive Solar Investors: Group-captive and third-party PPA structures above 1 MW remain on gross metering, but the raised net metering ceiling makes the captive route more attractive for loads in the 500 kW-1 MW band, where developers can now offer a simpler net-metered contract instead of a two-part gross-metered PPA with separate wheeling and banking charges.
What to Watch Next
- Time-of-Day Tariff Rollout for HT Consumers: KERC’s next tariff order (expected FY2026) will indicate whether peak-off-peak spreads widen to levels that trigger voluntary storage adoption; a spread above ₹2/kWh would be the practical inflection point.
- Feeder Hosting Capacity Studies: ESCOMs are required to publish updated hosting capacity maps by September 2025; watch for feeders where 1 MW net-metered projects are already queued beyond 30% of peak load, as these will face curtailment or costly upgrades first.
- Ancillary Service Market Design for Behind-the-Meter Assets: CERC’s ongoing consultation on virtual power plant participation rules – draft expected Q3 2025 – will determine whether Karnataka’s optional batteries can aggregate into tertiary reserve markets, creating the missing revenue stack.
- Banking Settlement Rule Amendments: The current annual banking cycle with no carry-forward beyond March 31 creates end-of-year dumping; any move to monthly banking or indefinite carry-forward (as in Gujarat) would materially improve project IRR for seasonal industries.
Bottom line: Karnataka has chosen regulatory pragmatism over technology prescription, betting that market signals – not mandates – will drive storage deployment when the economics align. The 1 MW net metering ceiling unlocks a pipeline of shovel-ready commercial and industrial projects that were stalled under the draft’s uncertainty, but the real test for distributed solar-plus-storage in the state will be whether the Commission follows through on time-of-day tariffs and ancillary market access within the next 18 months.
Read the full report at Mercom India
Note: facts and figures attributed above to Mercom India (Indian solar & clean energy business news) reflect that outlet's original reporting. Broader context, cross-sector connections, and forward-looking scenarios reflect independent analysis by our editorial team.
About this article: Drafted by Energy Ai with AI-assisted research and writing based on public reporting, then reviewed under our editorial process before publication.
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