Continuum Restricted Group 2 / CGRNEG issuer summary: FY2026 results and Q1 FY2027 operating update

Report date: 2026-09-18
Issuer: Continuum Trinethra Renewables Private Limited and Other Co-Issuers
Substantive credit exposure: Continuum Restricted Group 2 (RG2) / CGRNEG co-issuer group
Security covered: US$650 million 7.50% Senior Secured Notes due 26 June 2033

1. Business Snapshot and Recent Developments

CGRNEG should be analysed as a portfolio restricted-group project-bond credit, not as the standalone corporate credit of Continuum Trinethra Renewables Private Limited and not as a direct unsecured claim on the wider Continuum group. The repayment case is tied to the operating renewable assets and cash flows of Continuum Restricted Group 2 (RG2). The FY2026 special-purpose combined financial statements identify eight Indian entities in the RG2 perimeter: Bothe Windfarm Development, DJ Energy, Uttar Urja Projects, Watsun Infrabuild, Trinethra Wind and Hydro Power, Renewables Trinethra, Kutch Windfarm Development and Continuum Trinethra Renewables. The same statements are prepared for a special purpose and restrict their use and distribution; they are useful evidence on the restricted group but are not parent-group consolidated financial statements.

The latest official operating disclosure covers the quarter ended 30 June 2026 (Q1 FY2027) and is expressly unaudited. It shows 1,026MWp of operating capacity, compared with 991MWp a year earlier. The offtake mix moved toward commercial and industrial (C&I) customers, which represented 66.7% of capacity at quarter-end, versus 33.3% for discom fixed-in-tariff capacity. This is a useful operating development because C&I diversification can reduce dependence on a small group of state distribution companies, but it does not eliminate the risks of customer renewal, open-access charges, wheeling and banking rules, or changes in industrial power economics.

FY2026 generation rose 8.9% to 2,060 million kWh from 1,892 million kWh in FY2025. Q1 FY2027 generation increased to 678 million kWh from 663 million kWh in Q1 FY2026. Management reported plant availability, internal-grid availability and external-grid availability of 98.30%, 98.96% and 99.91%, respectively, in Q1 FY2027. These data are supportive of the physical repayment base, particularly after FY2025's generation decline, but they do not establish whether output met the portfolio's resource assumptions or project-level P50/P75/P90 cases. A wind-heavy portfolio can show high mechanical availability while cash generation is still affected by resource variability, curtailment, grid conditions or power-curve performance.

The FY2026 annual statements were management-signed on 18 May 2026, and the independent auditor's report is dated 30 May 2026. The auditor expressed an unmodified opinion, while drawing attention to the special-purpose basis and restricted use/distribution of the combined statements. Continuum's investor page does not state the publication date of those materials or of the Q1 FY2027 update. The numerical identifiers embedded in the download URLs resolve to 19 June 2026 for the FY2026 files and 16 September 2026 for the Q1 FY2027 files, but those technical identifiers are not treated here as confirmed public-release dates.

2. Industry Position and Franchise Strength

RG2 is an operating Indian renewable portfolio rather than a development-stage platform. The mix of wind and solar assets across Gujarat, Tamil Nadu, Maharashtra and Madhya Pradesh provides diversification across resources, grid conditions and state-level regulatory settings. The portfolio was previously described by CRISIL as effectively fully contracted, with a material C&I share and a diversified customer base. The latest reported C&I capacity share of 66.7% makes that commercial customer channel more important to the cash-flow profile than it was at FY2025-end.

C&I offtake is neither uniformly stronger nor uniformly weaker than discom offtake. It may benefit from shorter collection cycles and customer diversification, while exposing the group to contract renewal, customer credit quality and the net economics of open access. Discom contracts can provide longer-term visibility, but their value for a project-bond holder is affected by payment discipline and state-specific tariff administration. The Q1 FY2027 data do not provide customer-level revenue, contract tenor, renewal schedules, tariff resets or offtaker-level ageing. Accordingly, the higher C&I share is best viewed as a change in the mix of risks rather than proof of improved contractual cash-flow quality.

RG2's operational data show high portfolio availability and rising generation, while the public source does not provide a peer-normalised capacity factor, project-level curtailment or resource-adjusted production bridge. The franchise therefore supports the bond through a diversified operating asset base and contracted customer relationships, but the strength of that support depends on continuing conversion of generation into collections and cash retained inside the restricted group.

3. Segment Assessment

The available disclosure does not provide segment revenue or EBITDA by asset, state or customer class. A segment assessment must therefore remain qualitative and distinguish the information that is reported from what remains unavailable.

Receivables improved materially at year-end: days receivable outstanding fell to 15 at 31 March 2026 from 29 a year earlier, as overdue Ratlam collections were received. This should be read as a cash-conversion positive rather than a structural conclusion about all discom exposure. Receivables and days outstanding rose to INR817 million and 30 days at 30 June 2026, respectively, which management attributed to seasonal high-wind invoices. The seasonal explanation is plausible, but the lack of offtaker-level ageing means the Q1 movement should be monitored rather than dismissed.

4. Financial Profile and Analysis

The FY2026 result combines better operating output and revenue with accounting volatility from foreign-exchange remeasurement. Revenue from operations increased 5.8% to INR10,880 million and management-defined Adjusted EBITDA increased 6.6% to INR9,497 million. Operating cash flow increased to INR8,745 million from INR8,223 million. The reported loss after tax of INR3,522 million should not be read in isolation as a cash-loss proxy: it included INR2,712 million of non-cash foreign-exchange loss in other expenses related to restatement of the USD notes, as well as other accounting adjustments. Conversely, the EBITDA reconciliation should not be substituted for cash available to debt service, because it does not establish the treatment of reserves, cash sweep, restricted payments or the contractual debt-service waterfall.

The annual comparison is limited to two reported RG2 years, FY2025 and FY2026. It is neither a three-year through-the-cycle trend nor a resource-normalised comparison, and the Q1 data are presented as a separate quarter rather than annualised.

Two supplementary FY2026 ratios help describe, but not replace, a project-finance cash-flow analysis. Adjusted EBITDA divided by reported external borrowing cost was 1.37x (INR9,497 million / INR6,908 million). Contractual-principal borrowings divided by Adjusted EBITDA were 6.10x (INR57,894 million / INR9,497 million). Both calculations use the RG2 special-purpose combined scope and the management MDA definitions. Neither is covenant DSCR, a measure of cash available for debt service, or evidence of DSRA adequacy.

Q1 FY2027 confirms that the group continued to generate positive operating cash flow, but it also illustrates why cash balances should not be over-read. Cash and bank balances declined to INR2,536 million from INR4,109 million at March 2026. Management attributes this principally to June debt servicing and repayment. Cash used in financing was INR3,827 million in the quarter; selected components reported in the MDA were INR845 million of note principal repayment, INR2,405 million of finance cost paid on the notes and INR567 million of other finance cost, mainly option premium. Those selected components total INR3,817 million; the residual INR10 million is not separately described in the MDA and is not assigned here to a waterfall item. The disclosure is consistent with ongoing contractual servicing and amortisation, but it does not reveal DSRA balances, MCS paid or deferred, restricted-payment status or debt-service coverage under the indenture.

5. Structural Considerations for Bondholders

The legal issuer name should not obscure the relevant credit perimeter. The notes were issued by Continuum Trinethra Renewables Private Limited and other co-issuers, while the public operating and financial disclosure covers RG2's identified entities. CRISIL's 2025 domestic rating rationale described a co-obligor approach based on cross guarantees, pooled cash flows, common promoter, management and treasury, and the common renewable-energy business. This is relevant historical and domestic-facility context for understanding the operating group, but the reviewed materials do not establish that those features map unchanged to the current USD note collateral, waterfall or cash-retention protections.

They are not, however, a substitute for current covenant evidence. The available public materials do not permit confirmation of the current collateral package, account waterfall, DSRA requirement and balance, MCS due/paid/deferred history, restricted-payment lock-up, permitted-debt capacity, consent/waiver history or hedge covenant compliance. The FY2026 accounts show related-party instruments and allocable common overheads. The Q1 FY2027 MDA says INR58 million of allocable common overheads is payable to the holding company only from distributable surplus cash flows. That accounting disclosure is relevant to ring-fence monitoring, but does not prove the operation of distribution covenants or the amount of cash actually paid to affiliates.

The parent group's funding access, IPO plans and sponsor developments can matter indirectly for operational support and refinancing access. They should not be treated as a parent guarantee or direct source of payment for CGRNEG. For bondholders, the decisive question remains whether RG2 operating cash is retained and applied through the contractual debt-service structure. That question is not fully answerable from the published materials.

6. Capital Structure, Liquidity and Funding

The FY2026 MDA separates accounting debt from contractual-principal views. At 31 March 2026, total borrowings under Ind AS were INR66,116 million, including the notes and related-party liabilities, while contractual-principal borrowings translated at the reporting-date exchange rate were INR57,894 million. At 30 June 2026, the corresponding figures were INR64,275 million and INR57,013 million. These are INR translations at the respective reporting dates; they should not be converted into, or presented as, a verified current USD outstanding principal balance.

The notes were issued as US$650 million 7.50% senior secured notes due 2033. The original issue amount is a bond-term fact, whereas the current repayment profile must be assessed from the disclosed INR contractual principal and scheduled payments until trustee or compliance material confirms the current USD amount. FY2026 repayments included INR2,115 million of notes; Q1 FY2027 included INR845 million. This visible amortisation reduces debt on the disclosed accounting and contract-translation measures, but the pace of MCS and the final 2033 residual remain unconfirmed.

Currency risk remains a structural constraint. FY2026 finance cost included INR1,177 million of FX hedging premium cost. In Q1 FY2027, option premium cost rose to INR547 million from INR296 million a year earlier because management undertook additional hedges. The MDA also reports a foreign-exchange gain treated as finance cost in the quarter, while gross note interest rose despite scheduled repayments. The data demonstrate that INR/USD movements and hedging cost can materially affect reported cost and cash use. They do not disclose hedge ratio, tenor, collateral/margin terms, the covered payment schedule or the economic cost of rolling the hedge book.

7. Rating Agency View

India INX's June 2024 listing circular identifies Moody's Ba2 and Fitch BB+ for the notes at listing. This report has not independently confirmed a later original Moody's or Fitch action and therefore does not characterise those ratings as current. The domestic CRISIL A+/Stable and CRISIL A1 assessment for Continuum Trinethra Renewables Private Limited relates to Indian facilities in a co-obligor context and is not equivalent to an international note rating. CRISIL's April 2025 withdrawal notice concerned legacy bank facilities following a no-dues certificate; it is not evidence of a CGRNEG note downgrade.

The useful point in the rating context is qualitative: external analysis has recognised the relevance of the co-obligor portfolio, contracted offtake, collection performance and project-finance risks. It does not remove the need to verify current note-level covenant headroom, reserve funding, hedge coverage and amortisation progress before relying on a rating opinion for a bond-specific decision.

8. Credit Positioning

CGRNEG is positioned as a high-yield renewable portfolio project-bond exposure, rather than as a conventional unsecured corporate credit. Its differentiating features are an operating multi-asset pool, a growing C&I component, secured-note structure and disclosed scheduled amortisation. These features compare favourably with a single-asset or wholly merchant renewable exposure, but the public-information basis is less complete than for a widely followed listed corporate borrower.

No verified market price, yield, spread, current USD principal, dealer liquidity or directly comparable current bond data were obtained. Relative value cannot therefore be assessed. A bondholder considering the notes would need current pricing, trustee/compliance information and an assessment of the residual principal path before deciding whether the structural protections and operating recovery compensate for FX, refinancing and disclosure risks.

9. Key Credit Strengths and Constraints

Credit strengths

• The credit is supported by an operating portfolio with 1,026MWp capacity, a mix of C&I and discom offtake, and geographic/technology diversification rather than a single asset or customer.
• FY2026 generation, revenue, Adjusted EBITDA and operating cash flow improved, while Q1 FY2027 maintained higher generation and positive operating cash flow.
• Reported plant and grid availability were high in Q1 FY2027, and year-end receivable days improved materially in FY2026.
• The co-issuer/restricted-group and pooled-cash-flow context identified in the domestic CRISIL rationale provides a useful starting point for assessing operating alignment, but current note-level protections and cash-flow linkage require direct documentation.

Credit constraints

• Public financial performance does not establish covenant DSCR, DSRA sufficiency, MCS progress, restricted-payment lock-up or cash actually available within the note waterfall.
• USD debt against INR operating cash flows creates continuing hedging-cost and refinancing sensitivity. Q1 FY2027 option-premium expense and lower reported cash/bank balances demonstrate the cash-flow relevance of that sensitivity.
• C&I expansion adds customer and regulatory/open-access exposure, while remaining discom exposure leaves collections and state-level conditions relevant.
• The residual 2033 refinancing requirement, the current USD outstanding amount, the hedging profile and note-level covenant compliance remain unverified.

10. Downside Scenarios and Monitoring Triggers

The first downside path would be a combined operating and cash-conversion deterioration: lower resource-adjusted generation, curtailment or weaker availability, together with slower collections or adverse C&I/discom economics. The earliest public signals would be renewed growth in receivable days, lower generation without a documented resource explanation, weaker operating cash flow and reduced cash retained after debt service. Project-level resource and curtailment data are needed to distinguish an ordinary weather-driven fluctuation from an asset-performance issue.

A second path is FX and refinancing pressure. INR weakness, high hedge premiums or difficult hedge rollover could absorb cash even while contractual interest remains current. The report does not use a spot-FX level or hedge-premium threshold as a covenant trigger because the hedge book is undisclosed. The material evidence to seek is hedge coverage by payment date, premium schedule, collateral requirements, any MCS deferral and the residual-principal path toward 2033.

A third path is structural leakage or weaker ring-fence effectiveness. Affiliated payments, new intercompany exposures, increased permitted debt, asset transfers or requests to loosen covenant protections could weaken the cash-retention case before a payment default. The available disclosure of common overheads and related-party instruments warrants monitoring but is insufficient to demonstrate leakage. Compliance certificates, restricted-payment evidence, DSRA/MCS balances and waiver/consent notices are required before this risk can be measured.

11. Credit View and Monitoring Focus

On the public evidence available through 30 June 2026, CGRNEG's credit profile remains that of a speculative-grade renewable portfolio project-bond exposure supported by an operating asset base and reported C&I/discom capacity mix, rather than a parent-supported corporate obligation. The direction of the reported operating trend has improved from FY2025 into FY2026 and remained constructive in Q1 FY2027: generation, revenue and management-defined Adjusted EBITDA rose on an annual basis, operating cash flow remained positive, and disclosed note repayments continued. The likelihood of a rapid adverse change in actual debt-service protection cannot be assessed reliably from public operating data alone, because Q1 receivable days rose from the FY2026 year-end, and public information does not confirm the covenant, reserve, hedge and waterfall measures that determine cash retention and residual-refinancing protection.

The central support is the operating portfolio's ability to generate and collect renewable-power revenue. FY2026's generation recovery, improved year-end receivable days and higher operating cash flow are meaningful because they address the physical and working-capital sources of debt service. Q1 FY2027 continued to show higher generation and operating cash flow, although receivables seasonally increased and cash/bank balances declined after servicing and repayment. Those data should be assessed together: neither the Adjusted EBITDA metric nor the reported cash balance proves how much cash sits in the debt-service waterfall, how reserves are funded or whether distributions are locked up.

The central constraints are the USD/INR and hedge-cost exposure, the residual refinancing requirement in 2033, and the limits of public covenant disclosure. Scheduled repayments and lower contractual-principal translations are positive evidence of deleveraging, but they do not confirm MCS progress or a final balloon amount. C&I expansion can diversify customers and collections, while making renewal and open-access economics more important. The appropriate monitoring focus is therefore not a single headline metric: it is the interaction of generation, collections, operating cash flow, hedge cost, disclosed principal repayment, reserve/covenant evidence and any change in ring-fence integrity.

12. Short Summary & Conclusion

CGRNEG is a restricted-group renewable portfolio credit backing US$650 million of senior secured notes due 2033, not a standalone claim on the wider Continuum group. FY2026 and Q1 FY2027 disclosures show higher generation, positive operating cash flow and scheduled debt repayment, which support the operating case. However, DSRA, cash sweep, covenant DSCR, hedge coverage and the residual refinancing profile remain unverified, keeping the bondholder assessment dependent on further note-level evidence.

13. Sources

Primary sources

1. Continuum Green Energy, RG II Operational and Financial Updates, accessed 18 September 2026. Official issuer portal for CGRNEG documents; the page does not display a release date for the reports used.
2. Continuum Restricted Group 2, RG 2 MDA - Q4 FY 2025-26, year ended 31 March 2026. Official PDF. Management discussion and operating/financial review; RG2 scope.
3. Continuum Restricted Group 2, RG 2 Combined Financial Statement - Q4 FY 2025-26, year ended 31 March 2026. Official PDF. Special-purpose combined statements; management-signed 18 May 2026 and auditor-report date 30 May 2026.
4. Continuum Restricted Group 2, RG2 MDA Q1 FY2026-27, quarter ended 30 June 2026. Official PDF. Unaudited RG2 operating and financial update.
5. Continuum Restricted Group 2, RG2 Combined Financial Statements Q1 FY2026-27, quarter ended 30 June 2026. Official PDF. Unaudited special-purpose combined interim condensed statements.
6. India International Exchange, Circular No. 20240627-2, 27 June 2024. Listing terms and ratings at listing.
7. Continuum Restricted Group 2, Special Purpose Combined Financial Statements FY2024-25, year ended 31 March 2025. Official PDF. Comparative financial and operating data.

Rating and contextual sources

8. CRISIL Ratings, Continuum Trinethra Renewables Private Limited rationale, 28 February 2025. Domestic individual-SPV/co-obligor context, not an international note rating.
9. CRISIL Ratings, ratings withdrawn notice, 8 April 2025. Legacy facility/no-dues context.

Unverified and pending items

• Current Moody's and Fitch original rating actions after the 2024 listing.
• Full offering memorandum covenant extraction, compliance certificates, covenant DSCR, actual and required DSRA, MCS due/paid/deferred schedule, restricted-payment status and waiver/consent history.
• Current USD principal, detailed amortisation schedule after 30 June 2026, hedge ratio/tenor/premium/collateral terms, and current market price, yield and spread.
• Project-level resource assumptions, P50/P75/P90 performance, curtailment and compensation, C&I contract maturities, tariff and customer concentration, and offtaker-level receivable ageing.

These limitations affect the confidence of the liquidity, structural-protection and relative-value analysis; they do not negate the reported operating and financial facts above.