India's DISCOM finances: the off-taker risk behind renewables

In 50 words: India has nearly cleared the ₹1.4 lakh crore legacy dues that once strangled renewable developers, cutting them to ₹4,109 crore by February 2026. But ₹25,287 crore in current dues, ₹6.47 lakh crore of accumulated DISCOM losses and a 40 GW PSA backlog keep off-taker risk — and the cost of capital — stubbornly high.

India's renewable boom rests on a buyer most investors never meet: the state distribution company, or DISCOM, that actually purchases the power. Almost every utility-scale solar and wind project sells to a DISCOM, directly or through an intermediary like SECI, so the financial health of these 60-odd state utilities is the credit quality sitting underneath the entire renewable build-out. The good news of 2026 is real: the legacy payment crisis of 2019-2022 has been largely solved. The harder truth is that the structural finances underneath have not — and that gap is the quiet tax on India's energy transition, keeping clean-power cost of capital roughly 80% above advanced-economy levels.

Why DISCOM finances are the renewable sector's hidden credit risk
The legacy-dues success: from ₹1.4 lakh crore to ₹4,109 crore
The number that did not fall: ₹25,287 crore in current dues
The structural leak: AT&C losses, the ACS-ARR gap and accumulated losses
The PSA hold-up: 40 GW of stranded auctions
How off-taker risk prices into the cost of capital
RDSS and the reform machinery
What to watch next
Frequently asked questions

1. Why DISCOM finances are the renewable sector's hidden credit risk

In most power markets a generator's biggest worry is whether it can build cheaply. In India the bigger worry has long been whether it will be paid on time. The distribution segment is dominated by state-owned DISCOMs that buy power, run the wires, and bill consumers — making them simultaneously the renewable sector's customer and its single largest source of credit risk.

When a developer wins a SECI or NTPC tender, the chain runs developer to intermediary to DISCOM: SECI signs a Power Sale Agreement (PSA) with one or more DISCOMs, then a Power Purchase Agreement (PPA) with the developer. The tariff is fixed for 25 years on the assumption of full, timely payment. If the DISCOM at the end of that chain is financially stressed — slow to pay, sign, or procure — the risk flows back to the project's lenders and equity. That is "off-taker risk," and in India it has historically sat in distribution rather than in technology or construction. The International Energy Agency puts it bluntly: financially troubled distribution companies are a primary reason the cost of capital for utility-scale solar PV in India remains, by its estimate, about 80% higher than in advanced economies, with regulatory, currency and off-taker risk among investors' top three concerns.

2. The legacy-dues success: from ₹1.4 lakh crore to ₹4,109 crore

The acute phase of the crisis is over. For years the defining statistic of Indian power was the mountain of unpaid bills DISCOMs owed generators: as recently as June 2022 that legacy pile stood at ₹1,39,947 crore across 13 states, according to the Ministry of Power — money owed to thermal, renewable and transmission companies waiting to be paid.

The fix was the Electricity (Late Payment Surcharge and Related Matters) Rules, 2022, notified on 3 June 2022. They let DISCOMs reschedule the entire outstanding amount — principal plus surcharge — into up to 48 interest-free equated monthly instalments (EMIs), and added a real enforcement trigger: a DISCOM that defaults on a current bill or an EMI can be cut off from the power exchanges and short-term open access. That combination of a payment runway and a credible threat changed behaviour fast. By 10 February 2026, utilities had paid 43 of the scheduled EMIs — including some pre-payment — cutting legacy dues to ₹4,109 crore, a 97% reduction from the June 2022 peak. The Ministry of Power says no separate liquidation scheme is now needed, because the LPS trajectory has done the job.

| Legacy DISCOM dues to generators | Amount | Date | Source | |---|---|---|---| | Peak legacy dues (13 states) | ₹1,39,947 crore | 3 June 2022 | Ministry of Power | | After LPS rules (IEA dollar terms) | ~USD 18 bn → USD 9 bn | Jun 2022 → Jan 2024 | IEA | | Legacy dues remaining (43 EMIs paid) | ₹4,109 crore | 10 February 2026 | Ministry of Power |

This matters directly for renewables: the 2019-2022 crisis hit solar and wind generators hard, with delays running into hundreds of days, and the LPS clean-up removed a genuine source of distress from the sector's balance sheets.

3. The number that did not fall: ₹25,287 crore in current dues

Here is the point most coverage misses: legacy dues are not the same as current dues, and only the first number collapsed. The same Ministry of Power data that reports ₹4,109 crore of legacy dues in February 2026 also reports about ₹25,287 crore in total current outstanding dues to suppliers. The historical backlog has been refinanced and paid down, but DISCOMs are still falling behind on bills as they come due. The crisis did not disappear; it changed shape, from a one-time legacy mountain into a recurring flow of late payment.

That distinction is decisive for off-taker risk. A lender financing a 25-year solar PPA does not primarily fear a one-off historical pile already rescheduled into EMIs; it fears a DISCOM chronically slow on the monthly invoice for the life of the asset. The persistence of roughly ₹25,000 crore in current dues tells lenders that payment discipline is better than in 2021 but still not the clockwork low-cost infrastructure finance assumes.

| DISCOM dues snapshot (Feb 2026) | Amount | |---|---| | Legacy dues remaining | ₹4,109 crore | | Total current outstanding to suppliers | ₹25,287 crore | | Implied current (non-legacy) dues | ~₹21,000 crore |

The risk is concentrated, not uniform. The same release shows current dues clustered in a few utilities — Gujarat (~₹6,546 crore), Karnataka (~₹3,012 crore), Uttar Pradesh (~₹2,938 crore), Maharashtra (~₹2,932 crore) and Andhra Pradesh (~₹1,983 crore) — a reminder that "DISCOM risk" in India is really a set of very different state-level credit stories rather than one national number.

4. The structural leak: AT&C losses, the ACS-ARR gap and accumulated losses

Why do DISCOMs keep falling behind? Because most still sell power for less than it costs to supply, and lose a chunk of what they buy before it is ever billed. Two flow metrics capture this, and they compound into one stock figure.

AT&C losses — aggregate technical and commercial losses — measure the share of power dispatched but never converted into collected revenue, through theft, metering gaps, billing errors and non-collection. They fell from 21.91% in FY21 to 15.5% in FY23, then stalled at 16.16% in FY25, well above the Revamped Distribution Sector Scheme (RDSS) target of 12-15% by March 2028. Every remaining percentage point is power a DISCOM paid a generator for and never recovered from a consumer.

The ACS-ARR gap — the per-unit difference between the average cost of supply and the average revenue realised — shows whether tariffs and subsidies cover costs. Per Power Line's reading of the Ministry of Power's annual stocktake, it narrowed from about Re 0.71/kWh in FY21 to roughly Re 0.39/kWh in FY24. But a positive gap means DISCOMs still lose money on every unit sold unless a state subsidy plugs it — and subsidies are themselves often paid late.

| Structural metric | FY21 | FY23 | FY24/FY25 | Target | |---|---|---|---|---| | AT&C losses | 21.91% | 15.5% | 16.16% (FY25) | 12-15% by FY28 | | ACS-ARR gap (Re/kWh) | ~0.71 | — | ~0.39 (FY24) | Zero (cost-reflective) |

Selling below cost year after year compounds into a balance-sheet hole. The Ministry of Power's 14th Integrated Rating and Ranking Report, released in January 2026, pegged DISCOMs' accumulated losses at about ₹6.47 lakh crore against borrowings of roughly ₹7.26 lakh crore at end-FY25. (Earlier estimates put FY24 accumulated losses nearer ₹6.9 lakh crore; figures vary by edition.) These numbers explain the sector's repeated bailouts — UDAY in 2015, the 2020 liquidity package, LPS in 2022 — and why the government concedes that high DISCOM debt obstructs even the listing of state power firms. The ratings also show wide dispersion: in the FY24 review of 63 DISCOMs, only 32 earned a top-three grade. For a renewable investor that distribution is the real off-taker map — Gujarat and Odisha utilities sit near the top of the latest ranking, while several northern and eastern utilities remain perennial laggards.

5. The PSA hold-up: 40 GW of stranded auctions

The clearest place DISCOM weakness now bites renewables is not unpaid bills but unsigned contracts. By late 2025, more than 40 GW of awarded renewable capacity was stalled in advanced stages of signing PSAs, PPAs or securing connectivity, with SECI's intermediary pipeline accounting for a large share. The mechanics are specific to India's model: SECI runs a reverse auction, awards a tariff, then has to find DISCOMs willing to sign PSAs for that power. When state utilities drag their feet, the developer holds a winning bid it cannot finance.

DISCOMs have two reasons to wait, as IEEFA and trade analysts describe. First, financial stress: a loss-making utility is reluctant to add a new 25-year fixed obligation. Second, a bet on falling prices: with module and battery costs declining, some anticipate cheaper tariffs next year and delay signing today's. There is genuine progress — SECI has now signed more than 60 GW of PSAs cumulatively — but the backlog shows how DISCOM behaviour, not technology, increasingly sets the pace of deployment.

6. How off-taker risk prices into the cost of capital

All of this converges on the number that decides whether India's targets are affordable: the cost of capital. Renewable projects are capital-intensive and front-loaded — once built, fuel is free — so their levelised cost is dominated by financing cost. Higher off-taker risk raises the return lenders and equity demand, which raises the tariff, which raises the bill the DISCOM must pay, in a loop. The IEA's roughly 80% cost-of-capital premium over advanced economies captures the cumulative penalty from regulatory, currency and off-taker risk; IEEFA makes the same point from the financing side, noting that the instruments which de-risk the DISCOM — payment-security funds, tri-partite agreements and the LPS enforcement trigger — are precisely what bring the premium down. The encouraging signal in 2026 is that the legacy clean-up has measurably reduced this premium from its 2020-2022 peak; the discouraging one is that current dues and the PSA backlog keep a floor under it. Closing the gap is less about generation policy than about making the buyer creditworthy.

7. RDSS and the reform machinery

The government's main structural answer is the Revamped Distribution Sector Scheme, a result-linked programme with an outlay of about ₹3 lakh crore that ties central funds to measurable improvement in AT&C losses and the ACS-ARR gap. Its two big levers are loss-reduction infrastructure (feeder segregation, system strengthening) and prepaid smart metering, which attacks collection at source by making consumers pay before they consume. Smart metering is the centrepiece, with tens of millions of meters deployed, led by Bihar and Assam; the theory is sound — a prepaid meter cannot accumulate arrears — but rollout has been uneven and consumer pushback real. Alongside the LPS rules and tariff rationalisation by state regulators, RDSS is the machinery meant to turn DISCOMs from a credit risk into a creditworthy buyer. The AT&C plateau at 16% suggests it is working slowly, not failing — but slowly is the operative word.

8. What to watch next

Three indicators will tell investors whether DISCOM finances are de-risking renewables fast enough. First, current dues rather than legacy dues: whether the ~₹25,000 crore of current outstanding to suppliers falls or creeps up through 2026-27, the live measure of payment discipline. Second, the PSA conversion rate — how quickly the 40 GW backlog of awarded-but-unsigned capacity clears. Third, the AT&C trajectory against the FY28 RDSS target: a decisive move below 15% would signal the structural leak is closing, while another year stuck at 16% would tell lenders the risk premium is here to stay. If all three improve together, India's clean-power cost of capital should keep converging toward global levels, making the 2030 targets cheaper to hit. If they stall, the cheapest electricity in India's history will keep paying a premium for the weakness of the entity that buys it.

Frequently asked questions

Why are DISCOM finances important for renewable energy in India?

Because DISCOMs are the buyers. Almost every utility-scale solar and wind project sells its power to a state distribution company, directly or through SECI or NTPC, so the DISCOM's ability to pay on time and sign long-term contracts is the credit quality underpinning the entire renewable investment chain. Financially weak DISCOMs raise off-taker risk and the cost of capital.

How much do Indian DISCOMs owe power generators in 2026?

Legacy dues fell from ₹1,39,947 crore in June 2022 to ₹4,109 crore by 10 February 2026, after utilities paid 43 instalments under the Late Payment Surcharge Rules, 2022. But total current outstanding dues to suppliers stood at about ₹25,287 crore — so the legacy backlog is nearly cleared while recurring late payment continues.

What are AT&C losses and the ACS-ARR gap?

AT&C (aggregate technical and commercial) losses measure power supplied but never billed or collected — about 16.16% nationally in FY25, down from 21.91% in FY21 but stuck above the 12-15% RDSS target. The ACS-ARR gap is the per-unit shortfall between cost of supply and revenue realised, roughly Re 0.39/kWh in FY24. Both mean most DISCOMs lose money per unit sold.

How much do DISCOMs' financial problems add to renewable costs?

Off-taker risk is a major reason the IEA estimates India's utility-scale solar cost of capital is about 80% higher than in advanced economies. Because renewables are financing-cost-dominated, that risk premium flows straight into tariffs — which is why de-risking DISCOMs through payment-security funds, the LPS trigger and RDSS reform is central to lowering the cost of India's energy transition.

Researched and drafted with AI assistance; reviewed and edited by the named editor within 24 hours of draft. For methodology and sourcing, see our editorial standards and AI disclosure. Explore more policy and tenders coverage, our finance and markets coverage, and our India region hub.

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