Wind CUF volatility
Wind CUF declined to 38.7% from 47% YoY due to lower wind speeds and Cyclone Biparjoy, impacting generation.
ADANIGREEN / bear-case history
Track the concerns that keep returning.
Adani Green Energy · risk themes across the available quarters.
Research layer active
Bear-case history
Risks carried through the record.
medium
Module price fluctuations
While the company gets preferential pricing, discounts are smaller when market prices are low; future module price direction is uncertain.
Execution capacity constraints
Management acknowledged that supplier and contractor ecosystem is near upper limits, requiring proactive vendor development.
Dependence on group companies for wind turbines
The 5.2 MW turbine from group company is key for Khavra; any delays in commercial launch could impact project timelines.
Merchant solar price volatility
Q1 solar merchant realization was ~INR 4/unit, below the guided INR 4-4.5, due to seasonal softening.
Execution risk in pumped storage
Pumped storage CapEx is INR 4.5-5 crore/MW, but equipment is imported and supplier details undisclosed, posing supply chain risk.
Dependence on promoter warrants for funding
Management stated no equity dilution needed, relying on promoter warrants and internal cash flows, which may be constrained if execution slips.
Regulatory changes in solar imports
New import duty on solar glass may increase module costs, though management claims limited near-term impact due to ALMM exemptions.
Transmission evacuation constraints at Khavda
Curtailment due to transmission lag is impacting <5% of EBITDA; management expects resolution in weeks/months.
Merchant price volatility
Solar merchant prices fell to ₹2.2/unit in Q1 from ~₹3 in Q4 due to early monsoon and oversupply; wind prices also seasonal.
Monsoon-related operational disruptions
Extended monsoon last year impacted generation; management claims better preparedness but monsoon fury remains uncertain.
ISTS waiver taper impact on tariffs
25% reduction in ISTS waiver from July 2025 may affect merchant pricing; management sees limited near-term impact.
Execution risk for H2 commissioning
With only 200 MW added in H1, the company needs to commission ~2.6 GW in H2 to meet its 2.8-3 GW target. Any delays in Khavda or module supply could cause slippage.
ALMM compliance for imported modules
An analyst raised concerns about using Chinese modules (non-ALMM) for projects with SCOD near March 2024. Management clarified that current projects are exempt, but future projects may face restrictions.
Module price volatility
While recent module price declines benefit returns, management noted that prices are volatile and a $0.01 change impacts IRR by 1-1.2%. A sudden price spike could affect project economics.
Refinancing risk for Holdco bond
The $750 million Holdco bond maturing in FY2025 is expected to be repaid from a group liquidity pool, but any disruption in group-level liquidity could create refinancing pressure.
Extended monsoon causing construction delays
Monsoon extended by about a month, causing some delay in capacity addition, though within the 10% variation built into the construction S-curve.
Evacuation infrastructure bottlenecks
While management claims de-risking for 50 GW, analysts questioned evacuation readiness for 7-8 GW; management acknowledged reliance on sister company and Power Grid projects.
Minority interest and PAT dilution
Minority interest increased sequentially from INR 182 crore to INR 239 crore, impacting PAT attributable to shareholders, which fell from INR 372 crore to INR 276 crore YoY.
Merchant price volatility
Merchant realizations for solar were subdued in Q2 (INR 2.59/kWh) due to high hydropower availability; recovery expected but not guaranteed.
Evacuation delays at Khavda
Grid availability for new projects is impacted by transmission infrastructure delays, though management expects 10 GW evacuation capacity by year-end.
Margin compression from infirm power conversion
As infirm power (currently sold at merchant rates) gets converted to PPAs, blended realizations may decline, impacting EBITDA margins.
Competition in BESS tenders
Management acknowledged aggressive bidding in BESS tenders, which may pressure returns; they chose not to participate in recent tenders.
Monsoon impact on solar PLF
Prolonged monsoon in Q2 FY26 reduced solar PLF, though management expects normalization in H2.
Execution delays due to transmission and supply chain
Transmission evacuation readiness and supply chain constraints for long-lead items could delay capacity additions.
ALMM policy impact on module costs
Implementation of ALMM from April 2024 may restrict procurement from China, potentially increasing module costs for new projects.
Pumped storage project execution risks
Pumped storage projects have long gestation periods (5 years) and require clearances; past industry stalling poses a risk.
Module price volatility affecting returns
While lower module prices improve returns, sustainability of current low prices is uncertain, impacting project economics.
Transmission delays impacting project timelines
Delays in grid connectivity by CTU/PGCIL have shifted some projects to the right. Management is coordinating closely but this remains a key risk for future capacity additions.
ALMM compliance and solar cell import restrictions
Upcoming ALMM norms and restrictions on solar cell imports may increase costs by $0.02-$0.03 per watt initially. Management has secured supply agreements but cost impact is uncertain.
Refinancing risk for $1 billion construction facility
Analyst questioned backup plans if domestic bank refinancing fails. Management cited advanced discussions and multiple options, but any delay could impact liquidity.
DISCOM reluctance to sign new PPAs
DISCOMs are hesitant to sign PPAs due to existing backlog. Management expects RPO obligations to drive demand, but near-term PPA signing may remain slow.
Grid curtailment delays impacting generation
Delays in grid augmentation (2-3 GW pushed to Q4) have caused curtailment, particularly at Khavda, reducing revenue and EBITDA.
Subdued merchant power pricing
Merchant power realizations fell sharply (solar Rs 2.20/unit vs Rs 2.82 last year) due to market conditions, impacting revenue.
Commodity price risk (silver/module costs)
Rising silver prices (3x increase) could increase module costs by ~10%, potentially impacting project IRRs if not hedged.
CERC DSM regulation tightening
CERC draft regulation on tighter DSM norms for renewables could increase penalties, though management sees storage as mitigation.
ALMM module supply constraints
ALMM regulations may restrict module imports, but management stated all FY25 requirements are fully locked in and de-risked.
Execution risk in pumped hydro projects
Pumped hydro is a complex infrastructure project with longer timelines (3-3.5 years) and higher capital costs (INR 4.5-5 crore/MW).
Merchant power price volatility
Increased merchant exposure to 10% exposes the portfolio to spot price fluctuations, though management sees strong demand tailwinds.
Transmission evacuation delays
While management claims 100% transmission tie-ups for the pipeline, any delays in grid connectivity could impact project commissioning.
DOJ/SEC case uncertainty
The ongoing DOJ and SEC cases against individuals (not the company) remain unresolved; management provided no update on hearings or progress.
Execution risk at Khavda
Scaling Khavda to 30 GW by 2029 involves significant execution challenges; any delays could impact capacity addition targets.
Debt funding for 50 GW target
While equity is funded, debt for the full 50 GW target is not yet tied up; management only has visibility for 1-1.5 years.
Transmission evacuation constraints
Inadequate transmission infrastructure could limit capacity additions and utilization, especially at Khavda.
Curtailment and merchant price volatility
Curtailment and lower merchant realizations caused an estimated INR 1,200-1,500 crore EBITDA loss in FY26; recovery depends on PPA conversion and grid improvements.
Execution risk on battery storage ramp-up
Ramping battery storage to 10 GWh in one year involves supply chain and capital flexibility challenges.
Regulatory and policy uncertainty
Changes in renewable energy policies or grid regulations could impact project economics and timelines.