# 1. Financial Performance ## A. Key Figures * **Profit Before Tax (PBT):** **₹805 Cr** Q3 FY26 (+28% YoY) · **₹805 Cr** Adjusted (+46% YoY) * **One-off Gains (PBT Level):** **₹270 Cr** UNOSUGEN Regulatory Benefit · **₹41 Cr** DISCOM Segment * **Renewables Capex:** **₹1,750 Cr** Q3 FY26 · **₹3,100 Cr** 9M YTD * **Leverage Ratios (Mar-25):** **0.40** Net Debt-to-Equity · **1.41** Net Debt-to-EBITDA ## B. Revenue & Profitability * **Adjusted Earnings Growth:** Bottom-line performance showed robust double-digit growth when normalized for the prior year's cable business sale and current regulatory windfalls. * **Regulatory & Tax Tailwinds:** Earnings were significantly bolstered by a substantial non-recurring regulatory benefit from the UNOSUGEN project and lower tax expenses due to favorable exemptions. * **Segment Drivers:** DISCOM EBITDA grew by a fifth despite lower volumes, supported by higher ROE and one-off gains; however, merchant power sales saw a **₹75 Cr** contraction. * **Contractual Transitions:** Profitability was impacted by the conclusion of the NVVN contract in Q2, resulting in zero income from this stream during the current quarter. ## C. Balance Sheet & Leverage * **Conservative Capital Structure:** The group remains strategically under-leveraged compared to aggressive industry peers, providing significant headroom for future funding. * **Interest Savings:** Profitability benefited from reduced finance costs following proactive debt pre-repayments, partially offsetting higher depreciation and miscellaneous expenses. ## D. Capital Expenditure * **Renewables Acceleration:** Capex momentum intensified in Q3, with the segment accounting for the majority of the **₹5,140 Cr** total 9M investment across the portfolio. * **Diversified Pipeline:** Significant capital allocation is being directed toward License/Franchise (**₹1,100 Cr**), Coal (**₹400 Cr**), and Pumped Storage (**₹300 Cr**) to support long-term energy transition. * **Transmission & Licensing:** Infrastructure spend included **₹240 Cr** for transmission, while parallel licensing investment remains contingent on pending regulatory approvals. --- # 2. Generation & Capacity ## A. Key Figures * **Aggregate Installed Capacity:** **5 GW** Total · **2.7 GW** Gas · **~2 GW** Renewable · **362 MW** Coal * **Project Pipeline:** **4 GW** Renewable · **3 GW** Pumped Storage · **1.6 GW** Coal * **Financial Contribution:** **+₹163 Cr** Thermal · **+₹24 Cr** Renewable · **+₹75 Cr** Merchant/LNG ## B. Renewable Energy Strategy & Pipeline * **Aggressive Portfolio Scaling:** Total renewable pipeline reached significant scale following a **500 MW** quarterly increase, demonstrating the ability to rapidly capture market opportunities. * **Execution Focus:** Management is prioritizing a **1.2 to 1.5 GW** near-term pipeline (primarily wind and hybrid) despite industry-wide transmission and execution headwinds. * **C&I Market Positioning:** Maintaining an opportunistic stance in the Commercial and Industrial segment, contingent on favorable commercial terms. * **Technical Specification:** Clarified that capacity figures for upcoming projects are measured at the **DC level (MW peak)** rather than AC. ## C. Thermal & Gas Projects * **Regulatory & Merchant Gains:** Thermal profitability surged due to favorable regulatory orders and strong merchant power/LNG sales, though gains were tempered by **₹35 Cr** in forex-related expenses. * **New Thermal Infrastructure:** Secured a Power Supply Agreement for a major thermal project, with critical machinery and plant contracts already awarded to ensure commencement. ## D. Pumped Storage & Long-term Assets * **Pumped Storage Timeline:** The PSP project is on track for an **October 2028** commercial operation date, with major execution contracts already finalized to de-risk the timeline. * **Transmission Expansion:** Diversifying the utility portfolio with two active transmission projects at **Khavda and Solapur**. --- # 3. Distribution & Franchise ## A. Key Figures * **Distribution Contribution:** **INR 106 Cr** increase in segment earnings * **Regulatory/One-off Gains:** **INR 41 Cr** from favorable regulatory orders * **AT&C Losses (SMK Circle):** **~20%** current level ## B. License Area Performance * **Volume Headwinds:** Preliminary data shows a year-over-year decline in units sold across key areas, specifically Ahmedabad and Surat. * **Subdued Industrial Growth:** The D&H region underperformed its historical **3% to 4%** growth range, reflecting inconsistent demand across consumer segments. ## C. Asset Capitalization & Profitability * **Decoupled Returns:** Profitability remains resilient despite volume fluctuations, as returns are structurally driven by asset capitalization and tariff regulations rather than unit sales. * **Yield Drivers:** Earnings growth was bolstered by improved T&D efficiency in franchises and higher ROE/ROCE following asset capitalization. ## D. Franchise Operations & Outlook * **Contractual Continuity:** Management is actively negotiating with MSEDCL for the extension of the Bhiwandi franchise beyond its **January 2027** expiry. * **Path to Breakeven:** Significant loss reduction in the SMK circle positions the unit to achieve financial breakeven by **FY 2026-27**. --- # 4. Operational Metrics & Supply ## A. Key Figures * **JERA LNG Contract:** **0.27 MMTPA** 10-year volume (2027–2037) · **25%** of total fuel requirement * **Demand Outlook:** **5% to 6%** projected growth for next year ## B. Power Demand Trends * **Cyclical Softness:** Recent flat demand is characterized as a temporary aberration resulting from an extended monsoon and a high year-on-year base. * **Procurement Catalysts:** While large-scale gas tenders are absent, management anticipates short-term procurement from discoms to meet upcoming summer demand peaks. ## C. Fuel & LNG Sourcing * **Strategic De-risking:** Long-term agreement with JERA secures a significant portion of gas-based fuel needs with pricing indexed to **Brent crude**. ## D. Infrastructure & Execution * **Connectivity Status:** Project readiness is largely secured through a combination of existing commissioned substations and ongoing augmentation of new facilities. * **Execution Headwinds:** Partial commissioning achieved at the MSEDCL project, though full completion faces delays attributed to non-transmission factors. --- # 5. Regulatory & Contractual Framework ## A. Key Figures * **Target ROCE:** **15.5%** Maximum allowable rate (vs. **14%** base) * **Regulatory Assets:** **₹3,000 Cr** Combined for Ahmedabad and Surat operations * **One-off Regulatory Gains:** **₹270 Cr** EBITDA/PBT impact from UNOSUGEN order · **₹41 Cr** Carrying cost recovery in distribution ## B. Multi-Year Tariff (MYT) Evolution * **Structural Shift to ROCE:** The regulatory framework for Gujarat distribution and AMGEN thermal assets has transitioned from a Return on Equity (ROE) to a Return on Capital Employed (ROCE) model. * **Prospective Application:** The new ROCE methodology applies strictly to capitalizations occurring **after April 2025**, while legacy assets remain under the updated ROE model. * **Performance-Linked Upside:** The framework allows for a potential **150 basis point delta** above the base rate, contingent upon meeting stringent operational milestones. ## C. Operational Incentives & Milestones * **Efficiency Benchmarks:** Incremental returns are tied to specific regulatory parameters, including **AT&C loss reduction** and reliability indices like **SAIDI and SAIFI**. * **Tiered Gains:** Management expects to capture incremental gains in **25 to 50 basis point** slabs as normative performance levels are achieved annually. * **Capital Discipline:** New projects are targeted with a debt-to-equity profile of **70:30 to 75:25** to optimize returns as the project pipeline matures. ## D. Asset Recovery & Franchise Status * **Recurring Regulatory Income:** Carrying costs on regulatory assets are recognized only post-approval; management views these as recurring business model features rather than extraordinary items. * **Franchise Renewal Risk:** The Bhiwandi distribution contract lacks an automatic extension clause, requiring **mutual agreement** with MSEDCL for the optional **5-year** term extension. --- # 6. Risks & Operational Factors ## A. Transmission & Infrastructure Constraints * **Project Timeline Risks:** Potential extensions for Pumped Storage Project (PSP) Scheduled Commercial Operation Dates (SCOD) are being evaluated due to critical gaps in transmission capacity and substation readiness. * **Strategic Project Calibration:** Management is actively synchronizing renewable project implementation with infrastructure availability to mitigate unreimbursed indirect costs. * **Specific Project Delays:** The SECI XII project is facing significant evacuation infrastructure hurdles, pushing the expected commissioning timeline to **FY 2027**. * **Regulatory Relief:** The company is formally seeking SCOD extensions for select Renewable Energy (RE) projects citing external infrastructure deficits. ## B. Execution & Land Management * **Resource Acquisition:** Land acquisition is currently not viewed as a primary bottleneck for upcoming projects, despite broader industry-wide Right of Way (ROW) challenges. ## C. Industrial & Regional Demand Drivers * **Sectoral Volatility:** Demand in Surat is facing headwinds from a cyclical slowdown in the **diamond and textile industries**. * **Weather-Related Variance:** Consumption declines in Ahmedabad were attributed to lower residential and commercial cooling requirements during a favorable winter season. --- # 7. Guidance & Outlook ## A. Key Figures * **Renewable Commissioning Target:** **1.2 to 1.5 GW** FY26 projection · **1.2 to 1.5 GW** FY27 projection * **Long-term Portfolio Goal:** **10 GW** total renewable aspiration * **Projected Demand Growth:** **6.5% to 7%** aligned with long-term GDP ## B. Capacity Commissioning Targets * **Near-Term Scaling:** Management confirms a robust commissioning pace for the next two fiscal years, despite characterizing **FY 2026** as a relatively softer year compared to long-term projections. * **Execution Confidence:** The company maintains high conviction in its ability to implement significant annual capacity additions while adhering to strict **internal threshold IRR requirements**. ## C. Future Capex & Demand * **Investment Intensity:** While specific annual targets were withheld, the company expects to sustain the **elevated capex run rate** established in the third quarter. * **Macro Alignment:** Long-term power demand expectations remain anchored to national economic growth, dismissing a **temporary slowdown** observed in late January as a non-structural trend.