#electricitytariff

GERC's latest order shows Power Procurement decisions differ sharply between normal and peak demand periods. GUVNL purchased 793 MW of round-the-clock supply for August 2026 at Rs 6.05-6.15 per kWh, while securing 800 MW for the March 2027 evening peak at Rs 9.96 per kWh. The selected suppliers include Adani Raipur, Greenko AP01, ACME Venus, ACME Sigma and other market participants. Although some bids for other months reached Rs 20 per kWh, they were not accepted. The pricing pattern indicates that Gujarat is prepared to pay higher rates for limited evening shortages while avoiding costly purchases where supply conditions are less constrained. The latest order highlights how Power Procurement increasingly depends on time-specific demand rather than average energy availability. EnergylineIndia.com tracks these developments.

GERC has maintained the existing Electricity Tariff for Jubilant Infrastructure Ltd. in FY2026 after finding a projected surplus instead of the claimed deficit. While the licensee sought higher tariffs based on a Rs 9.27 crore revenue gap, the Commission calculated projected revenue of Rs 64.29 crore against an aggregate revenue requirement of Rs 42.63 crore, creating a surplus of Rs 21.66 crore. Accordingly, FY2025 tariff rates will continue for FY2026. The regulator also stated that any actual revenue gap or surplus will be settled during the true-up exercise with applicable carrying or holding costs. In addition, GERC directed the utility to propose its own fuel and power purchase adjustment mechanism instead of continuing with the DGVCL-linked formula. The ruling highlights stricter scrutiny of Electricity Tariff proposals. EnergylineIndia.com tracks these regulatory developments.

Jubilant Infrastructure claimed a Rs 9.27 crore FY2026 gap. GERC calculated a Rs 21.66 crore surplus and kept tariffs unchanged.

Actuals will return at true-up, so the order is not the final financial word. But it rejects the premise for an immediate increase. JIL must also develop its own FPPAS formula rather than rely indefinitely on DGVCL’s. The regulatory hook is the Rs 30.93 crore distance between two diagnoses of the same year.

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DERC has introduced an automatic Power Purchase Cost Adjustment mechanism, replacing the earlier system that required quarterly regulatory approval. As part of the transition, the Commission disposed of pending PPCA petitions submitted by Delhi's distribution companies for the second half of FY2025-26.

The first calculation under the revised framework produced surcharge levels above the previous 10% cap, with 25.07% for BSES Rajdhani, 19.91% for BSES Yamuna and 12.21% for Tata Power-DDL. The Commission approved recoveries of 17.94%, 17.43% and 12.21% respectively through phased implementation.

The latest regulatory reform highlights evolving tariff mechanisms in Power distribution India, improving cost pass-through while enhancing transparency. EnergylineIndia.com delivers trusted Indian Power news and Electricity tariff coverage.

Power regulator attention is needed after CSPGCL’s March 2026 FCA filings showed a net consumer-favourable fuel-cost adjustment of Rs. 13.33 crore. The filings cover Hasdeo TPS, Korba West TPP, DSPM and ABVTPS. Power regulator data shows three stations recording negative FCA because actual fuel costs were below tariff assumptions. HTPS showed negative FCA of Rs. 8.52 crore, KWTPP Rs. 5.26 crore and ABVTPS Rs. 2.35 crore. DSPM was the only outlier, with positive FCA of Rs. 2.80 crore. EnergylineIndia.com highlights this update for readers tracking State electricity regulator developments and News on Indian power sector. The technical point is important: negative FCA at HTPS and KWTPP occurred even though landed coal prices were higher than tariff assumptions, because coal GCV was better than the normative value. At ABVTPS, lower landed coal price drove the savings despite weaker GCV. Power regulator scrutiny matters because consumers do not get a refund cheque; the adjustment is normally reflected in later electricity bills. The filings do not disclose the exact pass-through timeline. Power regulator monitoring should therefore focus on CSPDCL billing treatment and cumulative settlement. Power regulator decisions will decide whether the benefit is real or only accounting, Power Regulator, CSPGCL, FCA, DISCOMs Latest News, Electricity Tariff.

State electricity regulator scheduling in Haryana has drawn attention for its rapid public hearing circuit on new tariff petitions. Hearings are clustered within days across cities, while written objections must be filed in the first week of March.

This administrative structure compresses review time for stakeholders analysing Regulatory Assets and prior-year true-ups. Effective Power tariff analysis India requires detailed scrutiny of power purchase claims and deviation penalties. Filing summaries show these components are major drivers in the petitions.

Indian Electricity Tariff Reports indicate rising fuel costs and accumulated grid charges forming part of the requested revision. The pace adopted by the State electricity regulator limits the ability of intervenors to assess evidence presented at each hearing before the next session begins.

Consumer groups argue that partial document uploads reduce transparency. Recent DISCOMs Latest News has pointed to liquidity stress prompting accelerated tariff filings in several regions.

The debate centres on procedural fairness. A State electricity regulator must balance timely revenue approval with meaningful public participation. Compressed timelines risk narrowing scrutiny of complex cost pass-through mechanisms.EnergylineIndia.com tracks verified regulatory notices and updates from the State electricity regulator impacting tariff governance, Electricity Tariff, Regulatory Review, Energyline India, Power Economics, Due Process.

The sharp fall in Pragati Power Corporation Ltd’s gas bills between August–September and November 2025 offers a revealing case study for POWER TARIFF ANALYSIS INDIA. Invoice data shows the plant’s gas cost dropping by around 44% in a single quarter, driven entirely by a shift from RLNG-based supply to Non-APM diverted gas. There is no evidence of efficiency improvement or operational optimisation.

For those engaged in POWER TARIFF ANALYSIS INDIA, the message is clear: gas-based power tariffs remain structurally dependent on supply categorisation rather than plant performance. The same generating asset can oscillate between high-cost and relatively affordable operation purely due to administrative gas allocation.

Yet the relief is only partial. While the commodity component softened dramatically, pipeline transportation tariffs increased steadily, rising to about Rs 94.5 per MMBtu. These charges, regulated by PNGRB, apply uniformly across gas consumers and do not respond to commodity price cycles. This creates a one-way pressure point within POWER TARIFF ANALYSIS INDIA.

The invoices underline a deeper policy issue. Gas price volatility can occasionally favour generators, but transport tariffs quietly accumulate regardless of market direction. Over time, this erodes the benefit of cheaper gas and complicates tariff stability for power utilities and consumers.

As India leans on gas-based generation for flexibility and cleaner peaking power, POWER TARIFF ANALYSIS INDIA must grapple with this imbalance. Without regulatory attention on transport cost trajectories, gas risks becoming a fuel where headline price relief masks steadily rising embedded charges.