Volume growth offsets margin compression; market headwinds acknowledged

Consolidated volume 25.8 Bn units, +12% YoY confirmed by CFO; underlying margin 3.35 paise/unit

Consolidated PAT fell 54% YoY, standalone 33% decline despite 2% operational income growth; CFO cited lower surcharge/rebate income due to improved Discom liquidity

MD confirmed no expirations in 3 years; however, Bikram Singh stated 'no expecting to add any long-term contracts' in FY27–28 due to regulatory constraint (traders barred from SBD bids). Hydro generation down YoY.

Confirmed; Bikram Singh stated operational timeline is FY29, not near-term

Bikram Singh: construction ongoing, expected December 2026–March 2027, 40–50% generation initially; timeline uncertain due to monsoon delays

Prior guidance: 'stable margins.' Delivered: PAT –54% consolidated, –33% standalone. Surcharge/rebate income collapsed due to Discom liquidity; structural, not temporary.

Regulatory constraint on trader SBD participation blocks new long-term contracts FY27–28. Hydro generation down YoY. NTPC Green and Teesta only bright spots, both FY27/FY29+ delayed.

MD in discussion mode on battery storage tie-ups; no concrete details or timeline. Positioning for future trading margin uplift via arbitrage (charge off-peak, sell peak).

MD stated 'protocol prohibits prediction.' Prior calls had narrative guidance ('stable margins,' 'volume growth'). Now zero numeric targets, only qualitative 'stable business.'

Nothing expires in 3 years. Specifics not readily compiled; will send via email.

80% power on long-term is regulated. Traders thrive on variability (seasonal, day/night imbalance, short-term gaps). Storage + renewable arbitrage are evolving opportunities. Margins depend on portfolio mix, not fixed.

In discussion mode. Evaluating both ownership (capex) and rental (OpEx). Whichever is cheaper. Cannot reveal details yet.

Lesser generation from hydro projects (where we have LT agreements). Hydro generation below last year. No new LT capacity expected (regulatory constraint); battery/seasonal opportunities will be taken.

Long-term PPF, but will take time. FY29 expected online.

Under construction. Expecting December 2026 or March 2027. Monsoon delays. 40–50% generation initially.

Rebate provision is if payment before due date. We paid early to get rebate; recover later from Discoms. Now Discoms also paying on time, so they capture rebate too. Net rebate to us is lower. Structural, not temporary.

Concerned about underperformance. Intend to disinvest. SBI case appointed transaction advisor. Exploring strategic options for best shareholder value.

Long-term power trading intermediary role. Generator demanding payment; adjudicating authority ruled we pay first, recover from utility later. Provision made. Recovery visibility unclear due to potential further litigation.

Most are back-to-back (generator due to us; utility due to them). PTC exposure <60 days. Top: Punjab PSEB ₹860 Cr, UPPCL ₹600 Cr, Haryana ₹500 Cr, Rajasthan ₹400 Cr, Tamil Nadu ₹300 Cr.

Pricing is competitive. Market fragmented; 80% still long-term (traders blocked). Depth only 8–9 GW trading vs 260 GW peak. Traders earn reputation, connectivity, balance-sheet strength. Returns are moderate. Policy reform needed for merchant power depth.

Stable business, no destabilizing bids foreseen. Dividend was one-time (PEL sale proceeds). NTPC sole promoter: shareholders already voted; result reported to market. Protocol prevents forward prediction.

Difficult to timeline. Two regulators involved (RBI, SEBI). Multiple approvals needed. Transaction advisor just appointed (concrete step 1). Expect to update market closer of FY27.

CERC said trading members must limit shareholding to 5%. PTC owns 22%; cannot become trading member unless equity <5%. Decision to reduce depends on many factors; management will decide.

NLC India JV approved by DPE. MOUs with SECI, ESL. JV formalities underway. Board approved investment up to ₹500 Cr over time. Cannot give specifics yet.

From both. Specifics not readily available; will send via email.

Net cash ₹2451 Cr (standalone). Interim dividend ₹23/share already declared and paid out.

Total income ₹13.98 Cr, PAT ₹5.16 Cr for June 2026.

Yes. Cyclical. With better Discom liquidity, they avail rebates, no late payment penalties. Less surcharge income. Situation can change.

Board approved investment up to ₹500 Cr rupees into JV. Unfolds over time based on projects chosen.

Received ₹1185 Cr gross, ₹1100 Cr net after taxes. ₹900 Cr used for dividend (₹200 Cr prior years + ₹700 Cr now). ₹200 Cr retained.

MD cited this as medium-term trend; National Electricity Policy 2026 targets 2,000 kWh/capita by 2030 support this.

Prior FY26 guidance. Q1 delivered +12% (beat ~5% base), but structure shifted to lower-margin exchange. Future growth uncertain; depends on policy depth (merchant power availability).

Prior narrative guidance from FY26. Delivered: structural compression due to Discom liquidity improvement. MD now cites 'pretty moderate' ROCE and 'depends on evolving portfolio.' No forward margin commitment.

MD in discussion mode; evaluating ownership vs rental model. No timeline, no economics, no quantified margin target.

Board approved; unfolds based on projects. Specifics not defined; will emerge post-JV formation completion.

SEBI/CERC rules prohibit traders from bidding on SBD long-term contracts. 80% of power trading remains long-term. Traders can only compete in 20% (short-term, medium-term, exchange). Caps addressable market and margin.

Surcharge (late payment penalties) and rebate income declined sharply Q1 due to Discoms paying on time. This income is not cyclical if liquidity remains strong. CFO stated: 'there is cyclicity to it,' but if Discom health persists, headwind is structural. Margin per unit under pressure.

Generator demanding payment under long-term contract; adjudicating authority ruled PTC must pay first, recover from utility later. Provision booked; recovery visibility poor; further litigation risk. MD noted: 'no clear visibility regarding recoverability.'

PFS 20 years old, delivering minimal shareholder value. Consolidated PAT includes PFS negative contribution. Divestment process initiated (SBI case); timeline to closure uncertain; expected closer FY27. Multiple regulator approvals (RBI, SEBI) required.

NTPC Green 1200 MW (FY29), Teesta Urja 1.2 GW (Dec 26/Mar 27, uncertain), NLC JV (formalities ongoing). All face construction delays, regulatory hurdles, monsoon risks. Teesta cofferdam first (40–50% generation); full dam later. NTPC Green timeline pushed.