Adani Power shares require a plant-by-plant review of dispatch, tariffs, fuel, collections, debt and construction—not a conclusion based on reported profit or a headline PPA percentage. The company’s audited FY26 consolidated results show ₹54,240.52 crore of revenue from operations, ₹15,499.51 crore of profit before tax and ₹12,971.08 crore of continuing-operations net profit for the year ended 31 March 2026. Those are historical results, not a forecast or a buy signal.
The most useful decision is whether the price you are considering adequately compensates you for merchant-power volatility, thermal-fuel and environmental exposure, counterparty collections, expansion execution and financing risk. The checklist below uses company and exchange disclosures through 13 October 2026 and identifies what still needs verification before investing.
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What the latest figures say—and what they do not say
Adani Power’s FY26 audited consolidated filing, approved by its board on 29 April 2026, covers 1 April 2025 to 31 March 2026. It reports the following historical figures:
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A free scan shows the junk files, broken settings and background clutter dragging Windows down - then fixes them in one click.Free scan · Windows 10 & 11| Measure | FY26 reported figure | Why it matters |
|---|---|---|
| Revenue from operations | ₹54,240.52 crore | Scale of reported operating revenue; compare with cash collection and recurring revenue. |
| Profit before tax | ₹15,499.51 crore | Profit after operating costs but before tax; investigate one-time items and financing burden. |
| Continuing-operations net profit | ₹12,971.08 crore | Audited historical earnings, not an estimate of future earnings. |
| Finance costs | ₹3,366.83 crore | Shows the cost of funding a capital-intensive fleet and expansion program. |
| Depreciation, depletion and amortisation | ₹4,564.53 crore | Reflects the heavy asset base; compare accounting profit with operating cash flow and maintenance capital expenditure. |
The nine-month operating update for the period ended 31 December 2025 reported 18,150 MW of installed capacity, a 64.1% plant load factor (PLF) and 71.8 billion units sold. In 9M FY25, the company reported 17,550 MW, a 69.2% PLF and 69.5 billion units. More units sold despite a lower PLF reflects the effect of added capacity; it does not by itself prove that each plant is earning an attractive return.
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For 9M FY26, continuing revenue was ₹40,523.67 crore, continuing EBITDA ₹15,713 crore, continuing profit before tax ₹9,896 crore and profit after tax ₹8,700 crore. The comparable 9M FY25 figures were ₹41,950.67 crore, ₹16,478 crore, ₹10,679 crore and ₹10,150 crore. Management attributed the year-on-year pressure to lower power-selling rates, lower other income and the absence of some one-time prior-period income. Treat that explanation as management commentary and reconcile it to the audited notes.
How Adani Power makes money
The company generates electricity, mainly from thermal plants, and sells it through long-term and medium-term power-purchase agreements (PPAs), alongside open-capacity, short-term and merchant sales. Management describes two-part, availability-based tariffs as supporting core earnings visibility while open capacity can provide upside when market prices are favorable.
For an investor, the economic chain is more specific than “capacity multiplied by tariff.” A plant must be available, have fuel delivered at an acceptable cost, receive dispatch from the buyer or market, invoice under the applicable tariff and collect the invoice. A PPA percentage does not establish the realized margin, dispatch level, payment timing or protection from curtailment.
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As of the Q3 FY26 update, the company reported 90% of operating capacity under long- and medium-term PPAs. The FY25 annual report gave a different, earlier measure: 87% of capacity was contracted under LT/MT PPAs, and 92% of that contracted capacity had assured fuel-cost recovery. Do not substitute the FY25 figure for the later Q3 FY26 figure. The annual report also stated that 98% of domestic-coal-based open capacity was near mine pitheads and 91% of domestic fuel requirements were secured under long- or medium-term contracts; both are FY25 company indicators that require current plant-level confirmation.
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Risk 1: Dispatch, merchant prices and changing demand
Contracted capacity reduces—but does not remove—exposure to electricity-market conditions. In Q3 FY26, Adani Power reported 4.3 billion units of merchant and short-term sales, down from 4.6 billion units in Q3 FY25. It linked softer merchant rates and lower offtake under some PPAs to extended monsoons, cooler weather, weaker demand and rising renewable generation.
The company reported all-India energy demand of 392 billion units in Q3 FY26 versus 393 billion in Q3 FY25. For the first nine months, demand was 1,287 billion units versus 1,280 billion. It reported a 242 GW peak demand for 9M FY26, compared with a 250 GW peak during FY25. These figures describe the periods cited; they are not a forward demand forecast.
Checks before buying
- Obtain the percentage of capacity, generation and EBITDA exposed to merchant or short-term prices.
- Review plant-wise PLF, availability, scheduled generation and actual generation rather than relying only on fleet averages.
- Compare realized tariffs with exchange or bilateral market prices for the same period.
- Check whether lower offtake reflects buyer curtailment, plant outages, transmission constraints or weak demand.
- Stress-test earnings using lower merchant prices and a lower PLF.
Risk 2: Coal supply, delivered cost and tariff pass-through
Thermal generation depends on reliable fuel at an economic delivered cost. Coal linkage allocations, imported-coal exposure, rail and port logistics, inventory and quality all affect the cost of producing a unit. Tariff treatment differs by PPA: some contracts may permit fuel-cost recovery, while others leave more of the variation with the generator or require regulatory approval.
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Checks before buying
- Map domestic linkages, imported coal, captive or secured sources and spot-market purchases by plant.
- Review delivered fuel cost, inventory days, quality adjustments and logistics bottlenecks.
- Read the fuel-cost-adjustment, indexation and pass-through clauses in material PPAs.
- Compare assured fuel-cost recovery with actual collections and regulatory approval timing.
- Ask whether a plant can run economically if imported coal, freight or exchange rates move sharply.
Risk 3: PPA quality, offtake and customer collections
A signed PPA is not the same as cash earnings. Returns depend on the counterparty’s credit quality, dispatch obligations, tariff provisions, payment security, disputed bills and the timing of regulatory compensation. The company has referred to realization of DISCOM dues in FY24 and FY25 and to the resolution of major regulatory matters. That history makes receivables and claims a central diligence item.
Separate billed revenue from cash collected. A period with high reported revenue but rising receivables can consume working capital and increase borrowing. Conversely, a cash collection from an old claim can lift a year’s cash flow without representing recurring generation economics.
Checks before buying
- Request receivable aging, overdue balances, disputed amounts and counterparty concentration.
- Identify payment security mechanisms, letters of credit, state guarantees and escrow arrangements.
- Reconcile PPA revenue, regulatory claims, interest on delayed payment and cash receipts.
- Check the status of renegotiations, curtailment notices and termination or compensation clauses.
- Compare contracted capacity with actual scheduled and dispatched generation.
Risk 4: Expansion and construction execution
Growth plans can increase future earnings, but they require capital before new units generate cash. The Q2 FY26 project update described a 23,720 MW expansion program and stated a capacity target of 41,870 MW by FY2031–32. The Q3 FY26 release announced a 3,200 MW project award in Assam and reported that 90% of operating capacity was tied up in LT/MT PPAs. Management also said nearly half of the 23.7 GW expansion was tied up in PPAs with state DISCOMs.
That statement is attributable to CEO S. B. Khyalia in the 29 January 2026 Q3 FY26 release; it is management’s description, not independent verification that all projects will be commissioned on schedule or at budget. Expansion can destroy value if land, environmental approvals, equipment, transmission, fuel or offtake are not ready when debt is drawn.
Checks before buying
- Build a project-by-project schedule showing location, capacity, technology, PPA status, fuel source and expected commissioning date.
- Verify land, water, environmental, forest, transmission and other statutory approvals.
- Compare original and current project cost, spending to date, remaining commitments and contingency.
- Track boiler, turbine, generator and balance-of-plant orders, contractor progress and commissioning tests.
- Confirm whether each announced PPA is executed, effective and supported by payment security.
- Measure additions against operating cash flow and debt raised, not only against the stated capacity target.
Risk 5: Debt, interest costs and liquidity
Adani Power reported total debt of ₹47,253.69 crore at 30 September 2025, up from ₹38,334.88 crore at 31 March 2025. Net debt was ₹36,775.72 crore versus ₹31,023.43 crore. The company attributed the increase to bridge financing for capital expenditure and working-capital borrowings associated with increased operating scale. A later Q3 disclosure reported a ₹7,500 crore issue of non-convertible debentures on 27 January 2026 for expansion and working capital.
These are dated disclosures. Use the FY26 audited balance sheet and subsequent exchange filings to establish current borrowings, because debt may change between reporting dates. FY26 finance costs of ₹3,366.83 crore provide context but do not reveal the full maturity ladder, fixed-versus-floating mix, security, covenants or refinancing exposure.
Checks before buying
- List maturities for the next five years and identify refinancing concentrations.
- Separate project debt, working-capital facilities, bridge loans and lease liabilities.
- Review interest rates, hedges, security, covenants and rating triggers.
- Compare operating cash flow with interest, maintenance capex, committed expansion capex and dividends.
- Run a downside case in which commissioning is delayed while interest continues to accrue.
Risk 6: Earnings quality and regulatory timing
The company said prior-period revenue recognition moderated in FY26 after major regulatory matters were resolved and DISCOM dues were realized in FY24 and FY25. This means a headline profit comparison can mix recurring generation with claims, prior-period adjustments, exceptional items and timing differences.
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Risk 7: Environmental and energy-transition exposure
The reported fleet is thermal-focused. Management presents thermal generation as important for reliable supply, while its Q3 update acknowledges that rising renewable generation affected demand and merchant sales. Investors should assess environmental compliance, emissions, water availability, ash handling, retrofit requirements and potential changes in dispatch priority or carbon-related regulation.
The available company material does not independently quantify future transition costs. Treat any long-dated earnings model as incomplete unless it includes plant-specific environmental obligations, remaining useful life, possible retirement dates and the economics of competing renewable, storage and flexible-generation capacity.
Risk 8: Valuation and share-price risk
Strong operating results do not prove that Adani Power shares are cheap. The available issuer information provides financial results, annual reports, shareholding information and announcements, but not a usable live quote in the retrieved material. Therefore, no current price-to-earnings, enterprise-value-to-EBITDA or peer-ranking conclusion can be made here.
Use a dated market price and consistent periods before answering whether the shares are attractive. Normalize earnings for prior-period claims and unusual collections; compare enterprise value with recurring EBITDA and operating cash flow; include net debt, maintenance capex and committed expansion spending; and compare listed generators using the same definitions for PLF, contracted capacity, receivables and debt.
A practical valuation worksheet
| Input | Use in the analysis |
|---|---|
| Current share price and share count | Calculate equity value on a dated basis. |
| Net debt and other debt-like items | Move from equity value to enterprise value. |
| Recurring EBITDA and operating cash flow | Avoid capitalizing one-time claims or collections. |
| Maintenance and growth capex | Estimate cash available after keeping plants operating and funding committed projects. |
| Plant-level PLF, tariffs and fuel costs | Test whether normalized earnings are sustainable. |
What to review in the filings, step by step
- Start with the latest audited statements. Reconcile revenue, profit, finance costs, depreciation, operating cash flow, receivables and debt to the 31 March 2026 filing.
- Move to the latest quarterly release. Compare 9M FY26 with 9M FY25 for capacity, PLF, units sold, tariffs, EBITDA and cash conversion.
- Split contracted and merchant exposure. Obtain capacity, generation and realized tariff by PPA, short-term sale and merchant category.
- Trace fuel economics. Match each major plant’s fuel source, delivered cost, inventory and pass-through mechanism to its PPA.
- Age the receivables. Identify overdue DISCOM balances, disputed claims, security and cash receipts after the reporting date.
- Audit the expansion pipeline. For every project, record approvals, capex spent, remaining cost, PPA effectiveness, fuel and transmission readiness.
- Stress the balance sheet. Model delayed commissioning, lower PLF, weaker merchant prices, higher interest and slower collections together.
- Only then compare valuation. Use a dated quote and normalized, consistently defined peer data.
Questions an investor should be able to answer
- What percentage of expected generation, not just capacity, is contracted for the next three financial years?
- How much EBITDA would be exposed if merchant prices and dispatch fell below the 9M FY26 level?
- Which plants lack assured fuel-cost recovery, and how quickly can tariffs adjust?
- What portion of receivables is overdue, disputed or dependent on a regulatory order?
- How much of the 23,720 MW expansion has binding PPAs, financial closure, permits and equipment orders?
- What are the next material debt maturities, and can operating cash flow cover them without refinancing?
- Which FY26 earnings or cash receipts will not recur?
- What environmental spending or operating restrictions could affect each thermal unit’s useful life?
- At the current dated share price, what assumptions about PLF, tariff, debt and capex are already reflected?
Bottom line for a prospective investor
Adani Power’s reported FY26 profit and growing capacity are starting points for diligence, not answers to the investment question. The central test is whether recurring cash earnings remain adequate after fuel, collections, maintenance capex, interest and the cost of expansion. A disciplined investor should rely on plant-level operating data, PPA and receivable terms, audited cash-flow information, project milestones and a dated valuation rather than on headline capacity, management targets or a single year’s profit.
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