SJVN Q4 FY26: Profit hinges on PLF rising above 70%

SJVN Limited — Q4 FY26 Earnings Call (Quarter/Year ended Mar 31, 2026)

1. Overall Tone of Management: Neutral (slightly optimistic)

• Management highlights strong generation growth and successful commissioning milestones (e.g., Nathpa Jhakri, Rampur, Buxar Unit-1 COD; Bikaner solar commissioned).
• However, tone is tempered by clear acknowledgements of earnings headwinds (subsidiary losses due to ramp-up/PLF/CUF) and material execution/market risks (RE PPA conversion uncertainty; curtailment/connectivity issues; Nepal dam/geology delays).
• Also, they walk back prior expansion targets (“we are reviewing it… new business plan very soon”), which reduces confidence.

2. Key Themes from Management Commentary

• Operational outperformance in hydro (generation up YoY):
• Nathpa Jhakri: 7,506 MU vs 7,421 MU
• Rampur: 2,108 MU vs 2,074 MU
• Total generation: 13,302 MU vs 10,646 MU (~25% growth)
• Capacity additions progressing (thermal + solar):
• Buxar Thermal (1320 MW): Unit-1 commissioned 14 Nov 2025; Unit-2 synchronized 8 May 2026, COD expected “by end of this month”.
• Solar: Bikaner 1000 MW commissioned 24 Dec 2025; Dhubri (Assam) commissioned 5 Feb 2026.
• Total installed capacity: 4,196 MW
• Renewables expansion via REIA / CPSU schemes + BESS:
• Awarded 850 MW solar (Gujarat); total REIA awards 16 GW across solar/wind/hybrid/storage.
• Awarded 4 GW and signed PSA for ~2,177 MW; awarded 2,000 MWh BESS projects (UP/Haryana).
• Project execution progress with specific risks:
• Hydro under construction: Dhaulasidh 69.5 MW targeted by Mar 2027; Arun-III 900 MW (Nepal) advanced (electromechanical + logistics), but dam/geological surprises and stabilization time.
• Financial drivers dominated by accounting + ramp-up effects:
• Revenue growth driven by tariff truing-up/provisional tariff orders.
• Subsidiary losses explained by commissioned-but-not-ramped assets (finance cost + depreciation charged before full CUF/PLF).

3. Q&A Analysis

Theme A: Consolidated losses / subsidiary losses (SGEL, Buxar STPL)

• Core question(s):
• Why is there a loss at consolidated level?
• Is it because new plants are booked with lower PAF/PAF and tariff before final orders?
• Request for SGEL revenue/EBITDA/PAT and operational factors (PLF/PAF).
• Management response:
• Losses were not at SJVN standalone, but in:
  • SGEL: loss ~INR 257–258 cr
  • STPL (Buxar): loss ~INR 92 cr
• Explanation: commissioned assets have finance cost + depreciation already hitting P&L, while generation is still ramping:
  • Buxar: operating ~60% PLF; profit expected once PLF >70%
  • SGEL: solar is cyclical; lower CUF and Bikaner flagship only fully ramping in FY26-27
• Provided SGEL numbers:
  • Revenue INR 510 cr (vs 232 cr)
  • Expenses INR 802 cr (vs 415 cr)
  • Loss INR 258 cr
• Assessment (evasive/strong/partial):
• Strongly explanatory on “why losses exist” (accounting timing + ramp-up).
• But did not fully quantify how much of consolidated loss is timing vs structural (beyond PLF/CUF narrative).

Theme B: Forward capacity additions & guidance (FY27/FY28)

• Core question(s):
• Capacity addition plans for FY27/FY28 (solar/hydro/thermal).
• Nepal hydro commissioning timing.
• Whether prior long-term targets still hold.
• Management response:
• FY27 commissioning plan:
  • Buxar 660 MW thermal
  • Dhaulasidh 69.5 MW hydro (Mar 2027)
  • ~1,555 MW solar (commissioning May’26–Mar’27)
• FY28: ~650 MW (solar-driven); hydro commissioning scheduled FY29–30
• Nepal (Arun-III) commissioning:
  • Geological/dam issues tackled; stabilization needed
  • Plan: commission all four units by Dec 2028
• Long-term vision:
  • Prior 25,000 MW by 2030 / 50,000 by 2040 is under review due to delays; “we will be sharing… new business plan very soon.”
• Assessment:
• Clear on near-term MW additions.
• Notably cautious on long-term targets (explicit review/withdrawal of prior ambition).

Theme C: Buxar economics & profitability inflection

• Core question(s):
• Regulated equity for Buxar (Unit-1 vs full plant)
• Generation, revenue contribution, profitability/losses
• Design energy and when profitability turns positive
• Management response:
• Regulated equity:
  • Unit-1: ~INR 2,000–2,100 cr
  • Full plant: ~INR 4,000 cr
• Unit-1 economics (FY26):
  • Revenue ~INR 522 cr (last three months)
  • Expenses ~INR 644 cr
  • Post-tax comprehensive income ~-INR 93 cr
• Profitability expectation:
  • Losses due to curtailment / low demand and running at ~60% PLF
  • “very much sure that during FY ’27 we are going to have a profit”
• Assessment:
• Unusually confident (“very much sure”) contingent on PLF rising—still a key execution/market risk.

Theme D: Renewable tendering slowdown, unsigned PPAs (~40 GW)

• Core question(s):
• Is there a slowdown in RE tendering?
• Status of unsigned PPA pipeline (~40 GW) and conversion likelihood.
• Management response:
• For SJVN REIA:
  • Awarded ~16 GW, signed PSA ~6 GW
  • Balance pending due to:
  • DISCOM adequacy plans (not all tender configurations match)
  • tariff declines in subsequent bids
• They expect demand to continue but with different configurations (e.g., solar + BESS, FDRE/hybrid mixes).
• Conversion outlook:
  • “Very, very difficult to say” on converting remaining.
  • Hopeful due to attractive tariffs (e.g., 2.53–2.54 vs newer 2.8–2.9).
• Assessment:
• Partially evasive on the “40 GW” question (no hard % conversion).
• Provides plausible market mechanics, but acknowledges risk of PPAs not being done.

Theme E: RE curtailment & mitigation (Bikaner, connectivity)

• Core question(s):
• Curtailment in solar assets and mitigation steps.
• Reasons for delays (SVR/reactor equipment; connectivity).
• Management response:
• Curtailment:
  • Bikaner: 1,000 MW commissioned; ~120 MW curtailed due to SVR requirement (grid balancing)
  • Connectivity: Khawada, Gujarat may face ~300 MW curtailment due to transmission line delay
• Mitigation:
  • SVR commissioning planned by Oct 2026; then run at full 1,000 MW
• SVR definition clarified as “reactor for compensation purpose.”
• Assessment:
• Specific and operationally grounded.
• Still implies near-term generation underperformance risk.

Theme F: CAPEX guidance & funding

• Core question(s):
• CAPEX guidance and how to fund “huge CAPEX”.
• Past capex guidance consistency.
• Management response:
• CAPEX:
  • FY26 plan ~INR 9,400 cr
  • FY28 ~INR 7,800 cr, FY29 ~INR 7,500 cr
• Funding approach not detailed in this call (no explicit debt/equity plan given in Q&A).
• Assessment:
• CAPEX numbers are clear; funding mechanics are not.

4. Guidance / Outlook

Explicit guidance (quantitative)

• Capacity additions
• FY27: ~2,284 MW commissioning (stated in response to long-term vision question)
  • Includes Buxar 660 MW, Dhaulasidh 69.5 MW, and ~1,555 MW solar (separately discussed)
• FY28: ~650 MW (solar)
• FY29–30: hydro commissioning ~2,500 MW (stated as part of earlier schedule)
• Nepal hydro commissioning
• Entire plant (4 units) by Dec 2028
• CAPEX
• FY26: ~INR 9,400 cr
• FY28: ~INR 7,800 cr
• FY29: ~INR 7,500 cr
• Operational expectations
• Buxar profitability: “very much sure… profit from Buxar Thermal Power plant during FY27”
• RE curtailment mitigation:
  • Bikaner full run expected after SVR commissioning by Oct 2026

Implicit signals (qualitative)

• Long-term expansion targets are no longer “committed”: management says prior 2030/2040 targets are being reviewed due to delays and underperformance in ramp-up/CUF.
• RE PPA conversion risk is real: PPAs may not be executed due to DISCOM adequacy plan mismatch and tariff compression.
• Near-term earnings volatility likely continues due to:
• subsidiaries ramping (SGEL/Buxar losses)
• curtailment/connectivity constraints

5. Standout Statements (direct / highly revealing)

• Walk-back of prior growth ambition:
• “we are reviewing it… making our new business plan and we will be coming out with the new business plan very soon.”
• Clear reason for subsidiary losses (timing/ramp-up):
• “finance cost and depreciation are already being charged… this will improve substantially in ’26-’27.”
• Buxar profitability confidence (conditional):
• “we are very much sure that during this FY ’27, we are going to have a profit from the Buxar Thermal Power plant.”
• RE PPA conversion uncertainty:
• “Very, very difficult to say anything as of now… possibility that all the PPAs may not be done…”
• Curtailment quantified + fix timeline:
• “Bikaner… curtailment of around 120 MW… we will be commissioning this year by October 26… then… full capacity.”
• Nepal execution risk acknowledged:
• “issues with the dam… geological surprises… minimum time required to stabilize… plan to commission… by December ’28.”

6. Red Flags / Positive Signals

Red flags
– Long-term target uncertainty (explicit review of 2030/2040 MW targets).
– RE PPA conversion risk: management admits PPAs may not mature; conversion “very difficult to say”.
– Generation risk from curtailment/connectivity:
– Bikaner SVR delay (120 MW curtailed until Oct 2026)
– Khawada connectivity delay (up to ~300 MW curtailment)
– Earnings quality risk: revenue growth partly driven by tariff truing-up/provisional orders; not purely operational.

Positive signals
– Strong hydro generation growth (~25% YoY total generation).
– Execution milestones achieved (Buxar Unit-1 COD; solar commissioning; multiple awards under REIA).
– Management provides specific operational explanations for losses (PLF/CUF ramp-up, accounting timing).

7. Historical Comparison & Consistency Analysis (vs prior 3 calls provided)

a. Change in Tone Over Time

• More Cautious vs earlier calls.
• What changed:
• Earlier (May 2025 / Nov 2025) tone emphasized being “on track” and confident about commissioning schedules and growth.
• In May 2026, management explicitly states prior expansion targets are under review due to delays and missed timing.
• More emphasis now on market mechanics (DISCOM adequacy plans, tariff compression) and grid constraints (SVR/connectivity), not just project execution.

b. Tracking Past Commitments vs Outcomes

1) Buxar COD timing
– Past statement (Nov 10, 2025): Unit-1 COD “within may be today itself… or tomorrow”; Unit-2 “within next 2 to 3 months”.
– What happened by May 2026 call:
– Unit-1 commissioned 14 Nov 2025 ✅
– Unit-2 synchronized 8 May 2026, COD expected “by end of this month” (i.e., still in FY26, but later than “Jan/Feb” style expectation in Nov call) ⏳/slightly delayed
– Flag: ✅ for Unit-1; ⏳ for Unit-2 (timing drift)

2) REIA pipeline conversion confidence
– Past statement (Nov 10, 2025): “we will meet my target whatever given to me by the government” and REIA tender targets achieved; issues mainly connectivity delaying commissioning.
– Current (May 15, 2026): admits PPAs may not be done; conversion “very difficult to say”; configuration mismatch and tariff compression.
– Flag: ❌/⏳ (narrative shift from “targets met” to “PPA conversion uncertain”)

3) Long-term expansion targets (25,000 MW by 2030 / 50,000 by 2040)
– Past statement: Vision referenced in Q&A (“earlier we had shared a vision…”).
– Current: “we are reviewing it… new business plan very soon.”
– Flag: ❌/⏳ (not delivered; now explicitly reconsidered)

c. Narrative Shifts

• From execution-led to market/grid-led constraints:
• Earlier calls: focus on commissioning milestones and project progress.
• Current call: more discussion on curtailment, connectivity delays, and DISCOM PPA adequacy/tariff dynamics.
• Subsidiary earnings narrative becomes central:
• Current call spends meaningful time explaining SGEL and Buxar losses due to ramp-up—suggesting consolidated earnings may remain volatile.

d. Consistency & Credibility Signals

• Medium credibility:
• Credible on operational facts (generation numbers, commissioning dates, curtailment MW).
• Credibility reduced by:
  • withdrawal/review of long-term targets
  • increasing defensiveness/uncertainty on RE PPA conversion
  • some schedule drift (Buxar Unit-2 timing)

e. Evolution of Key Themes

• Hydro generation: Improving/strong (consistent positive).
• Thermal ramp-up: Mixed—losses in FY26 expected to normalize in FY27 (directionally improving but contingent).
• Renewables: Deteriorating in narrative quality—less certainty on PPA conversion and more curtailment/connectivity issues.
• Expansion ambition: Deteriorating (targets being reviewed).

f. Additional Insights (Cross-Period Intelligence)

• A gradual build-up of RE monetization risk is visible:
• Nov 2025: delays framed mainly as connectivity/transmission line issues.
• May 2026: adds tariff compression + DISCOM configuration mismatch, which is harder to “fix” operationally.
• The company’s consolidated earnings are increasingly influenced by accounting timing (impairment, finance cost/depreciation pre-ramp)—suggesting investors should separate cash/operational trajectory from P&L optics.