Madhya Pradesh has become the latest state to codify how green energy open access consumers bank surplus solar and wind generation, setting monthly settlement cycles, a 20% banking charge, and time-of-day restrictions that will materially shift the economics of behind-the-meter and third-party renewable procurement for industrial and commercial users. The Madhya Pradesh Electricity Regulatory Commission’s (MPERC) standard operating procedure (SOP), issued in late May 2025, replaces an ad hoc framework that left developers and consumers guessing about carry-forward limits, valuation of banked energy, and curtailment risk – uncertainty that has stalled several hundred megawatts of proposed open access solar-wind hybrid projects in the state over the past 18 months. For a state with 6.2 GW of installed renewable capacity and an industrial load base that accounts for roughly 40% of peak demand, the SOP is the clearest signal yet that Madhya Pradesh intends to align its open access regime with the Centre’s 2022 Green Energy Open Access (GEOA) Rules while protecting distribution utility revenue.
Banking Mechanics and the Regulatory Vacuum They Filled
Banking allows an open access consumer to “deposit” surplus renewable generation with the distribution licensee during high-production hours and “withdraw” it later – typically at night or during cloudy periods – without selling it into the wholesale market. Until now, Madhya Pradesh operated on a patchwork of interim orders: the 2021 MPERC open access regulations permitted banking but left the settlement period, charges, and time-of-day (ToD) windows undefined, forcing each distribution company (Discom) to negotiate bilateral agreements. That vacuum created three practical problems. First, developers could not model revenue with confidence; a 100 MW solar-wind hybrid project in the Malwa region, for instance, faced a ±15% swing in levelised cost of electricity (LCOE) depending on whether banked energy was valued at the average power purchase cost (APPC) of ₹3.85/kWh or the higher ToD peak tariff of ₹6.20/kWh. Second, Discoms – primarily Madhya Pradesh Poorv Kshetra, Madhya Pradesh Paschim Kshetra, and Madhya Pradesh Madhya Kshetra – resisted banking volumes they deemed disruptive to their load balancing, occasionally curtailing open access injection without compensation. Third, consumers in the state’s auto-component clusters (Pithampur), textile belt (Burhanpur), and pharma hubs (Dewas) delayed power purchase agreement (PPA) signings because they could not quantify the effective landed cost of renewable power after banking losses.
The new SOP resolves these by mandating a monthly settlement cycle with a 20% banking charge levied on the energy deposited – effectively a storage fee paid in kind. Banked energy can only be withdrawn during the same month; any unutilised balance lapses to the Discom at zero compensation. Withdrawal is further restricted to off-peak and normal ToD blocks (22:00-06:00 and 10:00-18:00), explicitly blocking peak-block (18:00-22:00) drawal. The SOP also caps banking at 30% of the consumer’s annual contracted open access capacity, a limit designed to prevent large consumers from using the grid as a de facto battery while avoiding fixed demand charges.
Alignment and Divergence from the Central GEOA Framework
The Centre’s GEOA Rules, notified in June 2022, mandated uniform banking at a monthly or shorter settlement period, capped banking charges at the difference between the average renewable tariff and the APPC, and required states to finalise implementing regulations within six months. As of mid-2025, only Gujarat, Maharashtra, Karnataka, and Andhra Pradesh have issued comprehensive banking frameworks; Rajasthan and Tamil Nadu operate on draft orders. Madhya Pradesh’s SOP is broadly compliant but diverges in two financially significant ways. The 20% in-kind charge translates to an effective cost of roughly ₹0.77/kWh on banked energy (assuming a ₹3.85/kWh APPC), which is higher than Gujarat’s 15% and Karnataka’s 12% but lower than Maharashtra’s 25% (which includes a separate wheeling loss component). More critically, the 30% annual capacity cap is stricter than the Centre’s guideline, which only suggests a “reasonable limit” linked to the consumer’s load profile. That points to a deliberate policy choice: MPERC is signalling that banking is a grid-balancing tool, not a substitute for storage procurement. If this trend holds, other states with strong industrial bases – notably Chhattisgarh and Odisha – may adopt similar caps when they finalise their own SOPs, creating a de facto national ceiling well below the 50-60% banking ratios some developers had modelled for hybrid projects.
Implications for Project Economics and Procurement Strategies
For a typical 50 MW solar-wind hybrid project selling to an open access consumer in Madhya Pradesh at a PPA tariff of ₹3.20/kWh, the new banking rules add an effective ₹0.15-0.18/kWh to the landed cost when the consumer’s load profile requires 25-30% banking utilisation. That narrows the spread against the Discom’s industrial tariff (₹6.50-7.20/kWh including cross-subsidy surcharge and additional surcharge) but does not eliminate it. The bigger shift is behavioural: consumers with flat load profiles – continuous process industries like cement, chlor-alkali, and data centres – will now find banking far more valuable than those with daytime-heavy loads (textiles, food processing), because the off-peak withdrawal window aligns with their night-time baseload. Developers are already responding by oversizing the wind component in new hybrid proposals to increase night-time generation and reduce banking dependence; Mercom’s project tracker shows the wind share in Madhya Pradesh hybrid tenders rising from 28% in H1 2024 to 41% in Q1 2025. That points to a structural shift in technology mix driven purely by banking policy, not resource economics.
Grid Operations and Discom Revenue Protection
From the Discom perspective, the SOP achieves two objectives. The 20% banking charge, collected in energy terms, effectively transfers 1.2-1.5 BU annually (at current open access volumes of 6-7.5 BU) back into the Discom’s supply pool at zero procurement cost – energy that can be sold to tariff-paying consumers during peak hours at ₹6.20/kWh or higher. Simultaneously, the peak-block withdrawal ban prevents open access consumers from arbitraging the ToD differential, preserving the Discom’s peak revenue stream. However, the monthly lapse provision introduces a new operational risk: if a consumer’s load drops unexpectedly (plant maintenance, market downturn), banked energy evaporates, and the Discom receives a windfall of free energy it must absorb or curtail. Madhya Pradesh’s grid operator (MPSLDC) will need tighter day-ahead scheduling coordination with open access consumers to avoid sudden injection ramps when lapsed energy re-enters the Discom’s balancing area. By comparison, Karnataka’s framework allows quarterly carry-forward with a tapering charge, which smooths this volatility but reduces Discom certainty.
Who This Affects
- Utility planner (MPSLDC/Discoms): Must integrate monthly banking settlement into day-ahead scheduling tools and build logic for automatic lapse handling; expect 2-3% increase in forecasting error during monsoon transition months when solar output and industrial load diverge sharply.
- Renewable developer (solar-wind hybrid, storage): Re-run financial models with 20% banking charge and 30% capacity cap; prioritize wind-heavy configurations and consider adding 1-2 hour battery storage to bypass banking entirely for peak-block supply.
- Industrial/commercial procurement head: Recalculate effective landed cost of open access power using new banking parameters; negotiate PPA clauses that share banking charge risk (e.g., developer absorbs charge above 15% if generation profile deviates).
- Policy analyst/state regulator: Track whether the 30% cap becomes a template for other states; monitor Discom revenue impact reports due to MPERC in Q4 FY26 to assess if the 20% charge is sufficient or excessive.
What to Watch Next
- First quarterly banking settlement reports (July-September 2025): Actual banking utilisation rates, lapse volumes, and Discom revenue from the 20% charge will reveal whether the 30% cap is binding or theoretical.
- MPERC’s review petition window (closes August 2025): Watch for filings from Discoms seeking higher charges or from consumer associations challenging the peak-block withdrawal ban – outcomes will set precedent for pending SOPs in Uttar Pradesh and Bihar.
- Central Electricity Regulatory Commission (CERC) amendment to GEOA Rules (expected H2 2025): If CERC mandates a uniform national banking charge ceiling (industry speculation centres on 15%), Madhya Pradesh’s 20% may face legal challenge.
- Hybrid tender results in Madhya Pradesh (next SECI/state auction): Bid tariffs and wind-solar ratios will indicate whether developers have fully priced the new banking regime or are still bidding on pre-SOP assumptions.
Bottom line: Madhya Pradesh’s banking SOP converts a regulatory grey zone into a quantified cost of doing business for green open access – raising the effective tariff floor by 4-5% for banking-dependent consumers while giving Discoms a predictable energy revenue stream. The real test is whether the 30% capacity cap survives the first year of operational data without amendment; if it holds, it becomes the benchmark for every other state finalising its GEOA implementation.
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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