Tata Power Mundra Keeps Running on Policy, Not Economics

A power plant that shut down nine months ago because it was losing money is now being ordered to run at full capacity for the third time in six months. The latest instruction, confirmed today, 26 September 2026, keeps Tata Power’s Mundra plant switched on until the end of the year.

That paradox is not a corporate quirk. It is the most visible pressure valve on an electricity system operating at demand levels its planners did not forecast. India hit an all-time peak of 270.82 GW in May 2026, and demand in the April-June quarter ran roughly 12% above the same period a year earlier. The central government keeps reaching for a legal emergency instrument, quarter by quarter, because the structural fixes are not yet in place.

The Tata Power Mundra directive extension is worth understanding not for what any single order means, but for what the pattern of three consecutive renewals reveals. Read together, the extensions expose the legal mechanism keeping an uneconomic plant alive, the demand surge forcing the government’s hand, and where India’s grid is actually heading.

A financially broken plant that India cannot afford to switch off

The Mundra Ultra Mega Power Project sits in the Kutch district of Gujarat, operated by Coastal Gujarat Power Ltd (CGPL), a wholly owned subsidiary of Tata Power. It runs five generating units for a combined operating capacity of 4,150 MW. Roughly half its output goes to Gujarat, with the balance shared between Maharashtra, Punjab, Haryana, and Rajasthan.

The plant went dark on 2 July 2025. The reason was straightforward: sustained losses under power purchase agreements (PPAs) that priced coal at levels bearing no relation to actual import costs. When international coal prices climbed, Mundra bled money on every unit it produced, so its operator switched it off.

It stayed offline for around nine months. Then, on 1 April 2026, it restarted, not because the economics had improved, but because the central government issued a direction under Section 11 of the Electricity Act, 2003, compelling it to run at maximum capacity to help meet summer peak demand.

How Section 11 turns a loss-making plant into a viable one

Section 11 authorises the central government to direct a generating company to operate in a specified manner in the public interest during extraordinary circumstances. In plain terms, it lets the Centre override a plant’s own commercial decisions when the grid needs the power.

Section 11 of the Electricity Act, 2003 empowers the central government to direct a generating company to operate in a specified manner during extraordinary circumstances, and includes provisions for offsetting any resulting financial impact on the plant’s operator.

For Mundra, the practical effect is cost pass-through. CGPL recovers its actual imported coal costs, freight, and reasonable operating expenses from the beneficiary distribution companies, replacing the original low-tariff PPAs that made the plant uneconomic in the first place.

Without this mechanism, the plant would revert to its contracted position and lose money again at current international coal prices. That is precisely why it shut down before the directive arrived.

Three extensions, none longer than a quarter

What makes the story is not the first direction. It is the rhythm of what followed. The initial validity ran to 30 June 2026. On 23 June 2026, Tata Power filed with the exchanges confirming an extension to 30 September 2026. Then, on 26 September 2026, a further filing confirmed a third extension carrying the directions through to 31 December 2026.

Every extension has been decided in three-month increments. None longer. That rhythm tells you something the headlines do not: this is not a resolution, it is a deferral. Each renewal signals a government managing a capacity problem one quarter at a time, because the underlying commercial and structural issue remains unsolved.

What 270 GW tells you about why the directive keeps being renewed

To understand why the Centre keeps pulling the same lever, look at what India’s grid has been asked to carry through 2026. The records did not arrive in gentle increments. They stacked up in weeks.

• 9 January 2026: peak demand of 245.4 GW
• 25 April 2026: all-time peak of 256.1 GW, roughly one-third met by renewables
• 19 May 2026: 260.45 GW during solar hours
• 21 May 2026: 270.82 GW, the fourth consecutive day of new all-time highs
• July 2026: demand exceeded 270 GW on two more occasions

The jump from 256 GW in April to nearly 271 GW in May, compressed into under a month, is the part that matters. Peak demand is not climbing in smooth steps that grid planners can comfortably anticipate. The pace of escalation is itself a risk, and it explains why emergency instruments keep being reached for rather than structural ones.

Heatwave-driven grid stress contributed directly to the pace of demand escalation that pushed India past 270 GW in May 2026, with cooling loads arriving faster than the forecasting models that underpin capacity planning had anticipated.

The government has been explicit about the link. When the Ministry of Power extended Mundra’s directions in June, coverage from ETEnergyWorld quoted the mandate for the plant to run at full capacity to avoid electricity shortage amid an estimated peak demand of 270 GW during summer. Mundra was activated precisely because the grid was staring at the number it eventually hit.

The trajectory is not flattening. In a written reply to Parliament on 23 July 2026, Power Minister Manohar Lal Khattar stated that peak demand in the April-June period had risen by approximately 12% year-on-year and was expected to stay high. The structural gap between firm, dispatchable capacity and peak demand is widening, not stabilising.

The Mundra directive sits within a broader coal plant mandate that extended across 112 thermal generators simultaneously, revealing how narrowly India’s fuel buffer was being managed as demand records stacked up through September 2026.

Power Minister Manohar Lal Khattar, speaking to ETEnergyWorld on 8 July 2026, stated that India’s peak power demand is set to reach 300 GW in the following year, driven by the rapid expansion of data centres, artificial intelligence workloads, and electric vehicles.

That projection reframes the whole story. The directive is not a narrow corporate footnote about one plant. It is a symptom of a demand curve outrunning the country’s ability to add reliable capacity. Understand the trajectory, and Mundra stops looking like the cause of the problem and starts looking like the pressure valve.

The Section 11 instrument under pressure: what repeated use reveals about structural gaps

The first use of Section 11 was hard to argue with. A 4,150 MW dispatchable plant sitting idle during record peak demand is an obvious target for emergency activation. Turning it back on to keep the lights on across five states is exactly the kind of extraordinary circumstance the provision was written for.

The harder question arrives with repetition. An instrument designed for the exceptional is now functioning as a de facto operating framework for an asset that cannot sustain itself commercially. That is not what Section 11 was built to do, and three rolling quarterly renewals turn a one-off intervention into something closer to a business model.

To be fair to the proponent view, mainstream business and power-sector commentary generally frames the extensions as pragmatic and time-bounded. The argument runs that abruptly withdrawing large imported-coal capacity during record peaks would risk severe shortfalls, so emergency directives are a sensible reliability tool rather than a long-term endorsement of imported coal. That position deserves acknowledgement before the critique lands.

Section 11 as a recurring mechanism

The problem is what recurring use quietly does to the wider system. Three substantive criticisms stand out:

• Distorted market signals. Cost pass-through shields the plant and its off-takers from full exposure to fuel risk, which can delay investment in the flexible resources that would eventually cover extreme peaks: battery storage, peaking hydro, and demand response.
• Moral hazard. Repeated support at Mundra signals to other owners of uneconomic thermal assets that periodic regulatory rescue may be available, softening the pressure to restructure or repurpose stranded capacity.
• Opacity. No publicly available 2026 sources disclose the per-unit tariff, cost-recovery formula, or compensation amounts under the current regime, which limits transparency for both investors and consumers.

That last point is not abstract. The transparency gap matters directly to anyone holding Tata Power stock or tracking discom finances: the exact cost being passed to beneficiary states is real, but it cannot be quantified from public data. Commentary from BigMint in September 2026 characterised Mundra as a flexible buffer resource, activated when demand surges and coal buffers are adequate, which is a useful description of how policymakers are framing the arrangement, not a substitute for disclosed numbers.

The renewable coexistence paradox

There is an apparent contradiction sitting at the heart of all this. India met nearly one-third of its 256 GW April peak with renewables, then mobilised emergency coal directives to handle 270 GW peaks weeks later.

This is not hypocrisy. It is a system in transition. Renewables are displacing thermal generation in aggregate terms, but the most extreme demand hours still require firm, dispatchable capacity that current renewable and storage configurations cannot yet reliably deliver.

That tension is exactly why Mundra retains strategic value in the near term, even as Tata Power pivots toward clean energy. The plant is a reliability backstop for the hours the transition has not yet solved.

The tension between grid investment versus peak demand sits at the heart of India’s capacity problem: planned infrastructure spending addresses average load growth, but the evening ramp and extreme summer peaks that break records week after week require a different class of dispatchable resource entirely.

What the Tata Power investor reads into a plant running on quarterly policy decisions

For the near term, the signal is genuinely positive. Section 11 cost pass-through improves Mundra’s cash-flow visibility and removes the fuel-price exposure that forced the 2025 shutdown. Market commentary from Sahi.com in June 2026 framed the arrangement this way.

Sahi.com’s June 2026 market commentary noted that the directive “ensures continued cost pass-through” and helps Tata Power “mitigate fuel-price volatility through regulated tariff adjustments.”

That is real risk reduction for the current period. The harder point is what sits underneath it.

Cash flows from this asset are conditional on continued central directives, decided three months at a time, with no publicly disclosed timeline for a permanent tariff resolution or PPA renegotiation. An investor modelling Mundra’s contribution through 2027 is, in effect, modelling the government’s quarterly policy decisions rather than a commercial contract. That is a fundamentally different risk profile from a plant operating under a long-term PPA, and valuations should reflect it.

The three risk factors an investor should weigh are:

• Policy-conditional cash flows running on rolling three-month cycles rather than commercial terms.
• No publicly disclosed timeline for a permanent tariff resolution or PPA renegotiation.
• Capital-allocation tension between an imported-coal asset and Tata Power’s clean-energy growth strategy in renewables, transmission, and distribution.

Continued operation under government support removes immediate write-down pressure, which is helpful. It also anchors part of the business to an asset whose long-term economics depend on policy rather than markets. With demand projected toward 300 GW, further extensions after December remain plausible, but plausible is not contracted. The question worth holding is a simple one: what happens to Mundra if the December direction lapses without renewal?

Whether December 2026 is a turning point or just another checkpoint

Pull the four threads together and a single picture emerges. Mundra is being held in service by emergency instruments because India’s firm, dispatchable capacity gap is real and growing, not because the plant’s economics have been repaired. Nothing in the public record confirms a structural resolution such as a renegotiated PPA.

That makes 31 December 2026 a decision point with two plausible paths. One is a fourth extension, supported by the 300 GW demand trajectory and the precedent of three prior renewals. The other is a shift toward something more durable: a renegotiated PPA, capacity market participation, or a long-term regulated tariff. The rolling three-month pattern suggests a further extension is the path of least resistance, but precedent is not certainty.

The 300 GW demand trajectory is being driven by structural forces — data centres, AI workloads, and EV charging loads — that sit outside the traditional residential and industrial demand curves grid planners modelled for coal-era capacity builds.

For readers tracking this, three variables are worth watching before the year closes:

• Peak demand data through October and November 2026, which will shape the reliability case for another extension.
• Ministry of Power announcements on PPA renegotiation or capacity adequacy frameworks, which would signal a move from deferral to resolution.
• Tata Power’s next quarterly filing and any guidance it offers on Mundra’s status.

The reader who treats 31 December as a policy checkpoint rather than a commercial milestone is better placed to read the next exchange filing or ministry announcement with the right frame, rather than as a surprise.

This article is for informational purposes only and should not be considered financial advice. Investors should conduct their own research and consult with financial professionals before making investment decisions.

Forward-looking statements regarding future extensions, demand projections, and policy decisions are speculative and subject to change based on market developments and government action.