ACME Solar Targets Early BESS Scale-Up, 2.3GW Operational

ACME Solar Holdings Limited — Q4 & FY26 Earnings Call (held May 8, 2026)

1. Overall Tone of Management

Optimistic. Management highlights strong sector tailwinds and execution momentum (e.g., “successfully commissioned approximately 2.3 gigawatt BESS,” “EBITDA margin of over 90%,” “grid availability and plant availability… over 99%”). They also provide confident forward targets (e.g., “10 gigawatt hour… target,” “commissioning… early”) while framing risks as manageable via regulatory structures and CTU connectivity.

2. Key Themes from Management Commentary

• BESS as the core value driver (merchant arbitrage + early cashflow):
• Commissioned ~2.3 GW BESS and running on merchant/short-term contracts, delivering “net realization… INR2.2 crores per day” and round trip efficiency ~88–90%.
• Strategy: commission batteries at operational substations to monetize before FDRE/long-term connectivity fully integrates.
• Regulatory tailwinds enabling faster deployment and monetization:
• SECI notified as single REIA (streamlined bidding).
• MNRE clarification: BESS charged from conventional power under FDRE bids can sell in merchant mode (until RE is commissioned).
• CTU processing connectivity under RoFR and 36 months grid charging from GNA effective date.
• CERC draft order: extend SCOD timelines by up to 1 year with compensation.
• Portfolio shift toward CTU-connected projects to reduce curtailment/payment risk:
• Management emphasizes “all of our projects are in the CTU” and curtailment impact is small (INR5–6 crores real curtailment impact for the year).
• Strong financial performance and balance sheet actions:
• Revenue growth driven by capacity additions and CUF.
• Debt optimization: refinancing secured; WACC for operational projects ~8.4%.
• Execution roadmap tied to transmission readiness:
• Batteries targeted to scale quickly (connectivity permitting), with generation commissioning milestones mapped to substations and CTU timelines.

3. Q&A Analysis

Theme A: BESS economics, capex, and operating performance

• Core questions
• Battery capex capitalized/ spent to date; commissioning progress.
• Run-rate EBITDA contribution from operational capacity and BESS.
• Economics/IRR expectations for specific BESS projects (e.g., 550 MWh).
• Management response
• Capex: last quarter ~INR1,000–1,200 crores; commissioning 1.3 GW by last quarter; current BESS ~2.3 GW operational.
• EBITDA/margins: reiterated EBITDA margin ~88–90% and cited INR2.2 crores/day net realization from BESS.
• 550 MWh project: IRR “mid-to-high teens”; end-of-life 8,000–10,000 cycles; tariff/capex timing dependent on “zero date.”
• Notable signals
• Some answers were high-level (e.g., “run rate EBITDA… around INR2,200-odd crores” including other income; limited separation of BESS vs non-BESS).
• Strong confidence on operational metrics (efficiency, realization), but less disclosure on unit economics beyond headline numbers.

Theme B: Curtailment, Rajasthan concentration, and future allocation risk

• Core questions
• Curtailment impact due to Rajasthan transmission constraints; quantify EBITDA loss.
• How future allocations (Gujarat/Maharashtra) are considered if constraints persist.
• Management response
• Curtailment: only ~2 Rajasthan projects on state grid; real curtailment impact INR5–6 crores for FY26; STU curtailment INR3 crores and O&M-related INR2–3 crores.
• CTU portfolio is regulator-protected; curtailment can be used as an opportunity to charge/discharge via BESS.
• As BESS scales in Rajasthan, curtailment should reduce.
• Notable signals
• Management reframed “curtailment” vs pre-COD/pre-GNA situations (suggesting some impacts may be timing/definition-driven, not purely grid constraint).

Theme C: Working capital / receivables sustainability

• Core questions
• DSO improved to ~14 days from ~180 days—one-off vs structural?
• Sustainability of working capital profile as portfolio scales.
• Management response
• Structural shift: portfolio moving to 100% central offtakers; central offtakers take cash discount in ~10 days; hence ~15 days receivable cycle.
• Regulatory reform LPS helped settle delayed state dues; payment discipline now improved.
• Notable signals
• Clear causal explanation; acknowledges earlier issues from specific DISCOMs (Telangana/Andhra) but says normalized.

Theme D: Cash flow / balance sheet movements (capex advances)

• Core questions
• Why cash flow from operations is lower; jump in other non-current assets.
• What are “capital advances” and what they relate to.
• Management response
• Mainly capex buying; capital advances ~INR323 crores, tied to battery contracts (10% advance) and turbines (20%); international procurement requires advances + bank guarantees.
• Notable signals
• Straight-through explanation; no evasion.

Theme E: Connectivity/LOA conversion and regulatory mechanisms (CERC draft)

• Core questions
• How much LOA inventory is exposed to potential surrender/exit option.
• Strategy to convert LOA to PPA; view on RE tender momentum FY27.
• Management response
• They have ~6.2 GW signed PPA under construction; LOA converted to PPA for most.
• If worst-case surrender occurs, they’d redeploy connectivity for future bids or battery-connected projects.
• Demand view: peak power is the fastest-selling product; SECI aggregation expected to drive PPA signing; bids may be lower but PPAs faster.
• Notable signals
• “Backup plan” language is conditional (“just in case it happens”), but overall confidence is high.

Theme F: Commissioning timelines and FY27/FY28 targets

• Core questions
• Commissioning schedule for FDRE projects (SJVN, NTPC hybrid) and battery scaling.
• How much of 10 GWh battery is merchant vs FDRE-linked; expected EBITDA margins.
• Management response
• Generation: Neemuch first (June charging); Fatehgarh/SJVN long-term open access in March ’27; NTPC hybrid LTA by Dec ’26; by March ’27 “all this will be commissioned.”
• Battery: target 10 GWh; ~8.5 GWh merchant and ~1.5 GWh FDRE format in FY27.
• EBITDA margin assumption for merchant: ~75–80% (based on tariff arbitrage assumptions).
• Notable signals
• Strong specificity on substation-driven sequencing; however, repeated dependence on CTU timelines implies execution risk remains.

Theme G: Arbitrage sustainability (merchant BESS)

• Core questions
• How long buy-sell arbitrage will sustain.
• Management response
• “Anybody’s guess” but provides a structured argument: thermal evening prices remain high; gas constraints; battery needed to match growing solar; expects “at least for around 4, 5 years” not to go down.
• Notable signals
• This is the most uncertain area; management hedges (“anybody’s guess”) while still offering a time horizon.

4. Guidance / Outlook

Explicit guidance (quantitative)

• BESS
• Operational BESS commissioned: ~2.3 GW (to date).
• Target battery installed base: ~10 GWh (operational battery portfolio) with ~1.5 GW contracted generation (subject to connectivity).
• FY27 commissioning target (battery): 10 GWh total; in FY27 specifically ~8.5 GWh merchant and ~1.5 GWh FDRE format.
• FY27 generation commissioning target: ~1.5 GW projects (with some battery pre-charging).
• Generation / under construction
• Under construction portfolio expanded to 5.1 GW; total portfolio 8,071 MW.
• Commissioning by FY28: “commissioned by FY 28” for under construction portfolio (PPA-signed portion).
• Financial
• No new numeric FY27 revenue/margin guidance provided in this transcript; management reiterated EBITDA margin >90% for Q4/FY26.

Implicit signals (qualitative)

• Merchant arbitrage is expected to remain attractive due to peak power pricing and gas constraints.
• Curtailment risk is being actively engineered away via CTU focus + BESS merchant operations.
• Execution confidence is high because batteries are being installed at operational substations and long-lead items are on track.

5. Standout Statements (direct / high-signal)

• BESS monetization
• “delivering net realization value of approximately INR2.2 crores per day”
• “round trip efficiency of approximately 88% to 90%”
• Profitability
• “EBITDA margin of over 90%”
• Curtailment minimization
• “only INR5 crores to INR6 crores of impact on the curtailment”
• “all of our projects are in the CTU”
• Merchant arbitrage outlook
• “at least for around 4, 5 years, we don’t see this going down”
• Execution approach
• “commissioning… early” by installing batteries at “operational substations”
• “We will defer our capex” (modules) when transmission timelines slip.

6. Red Flags / Positive Signals

Red flags
– Arbitrage sustainability uncertainty: management admits “anybody’s guess” and relies on assumptions (thermal price, gas constraints).
– Some answers are aggregation-heavy: EBITDA/run-rate figures include “other income” and are not always cleanly decomposed by BESS vs solar/wind.
– Regulatory dependence: multiple strategies hinge on MNRE/CERC/CTU interpretations (merchant eligibility, connectivity rules, extensions).

Positive signals
– Operational proof points: efficiency (88–90%), realization (INR2.2 cr/day), availability >99%.
– Clear working capital causality: DSO improvement attributed to central offtaker cash discount + LPS settlement.
– Risk framing on curtailment: quantified and tied to CTU protection and BESS mitigation.

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

a. Change in Tone Over Time

• More Optimistic in FY26 Q4 call vs earlier calls:
• Q3 FY26 (Jan 30, 2026): optimistic but more about “on track” and planned BESS ramp; mentioned 2 GWh BESS becoming operational and expected demand revival.
• Q4 & FY26 (May 8, 2026): shifts to execution certainty with commissioned BESS already running and quantified daily realization.
• Will give guidance more confidently now: explicit merchant/FDRE battery split and commissioning sequencing.

Classification: More Optimistic

b. Tracking Past Commitments vs Outcomes

• BESS ramp guidance (Q3 FY26 → Q4 FY26)
• Past: Q3 call upgraded guidance to 2 GWh operational in current quarter and additional 2 GWh in Q1 FY27.
• Current: management states ~2.3 GW BESS commissioned to date and operational, implying at least the near-term ramp was delivered (✅ Delivered for the “current quarter” portion; additional Q1 FY27 ramp not explicitly quantified here, but target trajectory remains).
• Curtailment issue (Sikar)
• Past (Q3 FY26): curtailment loss ~INR17.5 crores in Sikar due to temporary GNA; expected line commissioning by Dec 2025.
• Current (Q4 FY26): real curtailment impact for FY26 is INR5–6 crores, and they distinguish pre-COD/pre-GNA impacts.
• Assessment: likely improved materially (✅ Delivered/Resolved in practice; the narrative now downplays “curtailment” vs timing/definition).
• PPA signing urgency
• Past (Q2 FY26 / Q3 FY26): repeated emphasis on PPA signing acceleration and urgency.
• Current: still conditional language around PPA signing for some capacity, but they provide clearer commissioning targets and signed/under construction portfolio expansion.
• Assessment: directionally delivered, but not fully “clean” (⏳ Delayed/ongoing for remaining unsigned portions; not dropped, but still not fully converted).

c. Narrative Shifts

• From “BESS as planned upside” → “BESS as already monetized engine”:
• Earlier calls framed merchant BESS as an upside potential (e.g., EBITDA upside math).
• Now it’s backed by daily realization and efficiency.
• Curtailment narrative becomes more technical/definitional:
• Earlier: acknowledged meaningful curtailment loss (Sikar).
• Now: emphasizes CTU protection and quantifies “real curtailment,” separating pre-GNA issues.
• Connectivity/CTU focus strengthened:
• Earlier: connectivity inventory and general mitigation.
• Now: “all projects are in CTU” is a central risk-reduction pillar.

d. Consistency & Credibility Signals

• Medium-to-High credibility:
• Consistent operational metrics: availability >99% repeated; CUF improvements in Rajasthan repeatedly cited.
• Credible causal explanations for working capital (central offtakers + LPS).
• However, some financial metrics remain aggregated and not always cleanly attributable (BESS vs other income), which slightly reduces transparency.

Overall credibility: Medium-High

e. Evolution of Key Themes

• Demand/macro: from “demand revival expected” (Q3) to “peak demand milestones + summer progression” (Q4).
• Margins: consistently high EBITDA margins; now explicitly >90%.
• Execution: from “on track” to “commissioned and running,” with more granular sequencing.
• Regulatory: increasing specificity on MNRE/CERC/CTU mechanisms enabling merchant BESS and connectivity extensions.

f. Additional Insights (cross-period intelligence)

• Risk is being shifted from “grid curtailment” to “merchant price/arbitrage sustainability”:
• Curtailment risk is minimized via CTU + BESS; the remaining key uncertainty is whether peak-vs-offpeak spreads remain favorable.
• Capex timing risk is actively managed via deferring solar modules:
• This is a recurring operational tactic (modules “not called,” batteries installed first), suggesting management is learning to reduce stranded/idle capex when transmission timelines slip.