GAIL (India) Ltd (GAILF) (Q1 FY2027) Earnings Call Highlights: Record Profit Surge on LPG ...

Negative Points

• GAIL (India) Ltd ( GAILF )'s gas marketing volumes were impacted by force majeure declared by PLL, affecting Qatar volumes and seven other cargoes, requiring the company to source eight spot cargoes to meet demand.

• The elevated marketing spreads from favorable index movements (Henry Hub and JCC nine-month linked) are expected to be largely short-term, with benefits likely to normalize as averages converge.

• The polymer business incurred a loss of INR130 crores in Q1 FY27 due to feedstock diversification towards the priority sector, although the plant is expected to reach breakeven during FY27.

• LPG transmission volumes declined by around 3% quarter-over-quarter due to disruptions in LPG imports caused by the West Asia crisis.

• The company's gas marketing guidance for FY26-'27 remains at INR4,500 crores PBT, implying a steep decline in quarterly run rate from Q1's performance, reflecting uncertainty and potential normalization.

• Petrochemical profitability is sensitive to gas costs; with a landed gas price of $10.54 per MMBtu, the segment is still loss-making, and profitability depends on achieving a $13-$14 landed price.

• The company faces potential cost increases from new projects, with depreciation expected to rise by around INR312 crores annually for the PDH-PP plant and interest costs by approximately INR440 crores per year.

Q & A Highlights

Q: The gas marketing segment delivered a strong PBT of INR3,353 crores in Q1, yet the full-year guidance remains at INR4,500 crores. Is this excessive prudence, or is there a significant normalization expected as the JCC three-month linkage converges with the nine-month average? A: Satish Sinha, CFO, explained that the exceptional Q1 performance was driven by an abnormal jump in Brent index numbers, creating a one-off arbitrage between the nine-month JCC-linked sourcing and three-month dated Brent-linked sales. He stated this benefit is largely short-term and will normalize as the averages converge, though the final outcome depends on the level of dated Brent in the coming months. The company will review and revise guidance if required after subsequent quarters.

Q: Given the strong LPG prices and production increase, will the LHC segment's PBT of INR772 crores sustain for the rest of the year? A: The CFO noted that the average LPG price during Q1 was around INR90,796 per metric tonne, but prices have already softened in the current quarter. While the segment benefited from a 20% production increase due to additional new well gas allocation (0.597 MMSCMD), the profitability is expected to decrease as LPG prices cool off from the elevated levels seen during the West Asia crisis.

Q: Can you provide more detail on the drivers of transmission volume growth and the demand outlook beyond FY27, given the government's push to derisk from LPG? A: The CFO cited PNGRB's projection that total gas demand will increase from ~200 MMSCMD to 297 MMSCMD by 2030. The growth will come from CGD (growing 10-12% annually, from 45-46 to 80-85 MMSCMD), fertilizer (10-12 MMSCMD growth), power (from 25-26 to 35 MMSCMD), and industrial segments including steel, aluminum, and long-haul LNG trucks. The company has not revised its volume projections and relies on PNGRB's published figures.

Q: What is the current status of the petrochemical business, and at what gas price will the Pata facility reach breakeven? A: The CFO stated that the average landed gas price for petrochemicals was $10.54 per MMBtu in Q1, and the segment incurred a loss of INR130 crores. The plant is now running at 100% capacity and is expected to reach breakeven during FY27. He indicated that at a landed price of $13-14 per MMBtu and a selling price of around INR130,000 per metric tonne, the plant would achieve no profit and no loss. The company is actively pursuing a shift from natural gas to ethane as feedstock for long-term sustainable margins.

Q: With the recent PNGRB withdrawal of Clause 5A on unbundling, what is the role of the independent Transport System Operator (TSO)? A: The CFO clarified that PNGRB has withdrawn Clause 5A from their regulations, meaning there is no longer an obligation for unbundling entities engaged in both gas transmission and gas marketing. The TSO will now focus on monitoring third-party open access quantities, as pipelines are required to provide 25% capacity to third parties.

Q: What percentage of the Henry Hub-linked LNG portfolio is open for arbitrage, and will the high margins from the cross-index differential sustain? A: A company representative explained that of the 21 MMSCMD Henry Hub portfolio, roughly half or slightly less is contracted back-to-back, another 20% goes for internal consumption at the Pata petrochemical complex, and the remaining 25-30% is available for sale on Brent-linked contracts. While the current differential is favorable, the company hedges and locks margins on this cross-index basis. However, with Pata now fully operational at 100% load, less volume will be available for arbitrage.

Q: How has the West Asia crisis impacted GAIL's long-term market share in gas marketing, and can the company close the gap between marketing and transmission volumes? A: Management noted that the crisis has highlighted India's over-dependence on Middle Eastern LPG, while the natural gas portfolio is more diversified. This has boosted the government's push for more PNG connections and industrial customers switching from LPG to natural gas. The company expects this to improve marketing volumes over time, though CGD growth has been a factor in the historical gap. The transmission network will continue to benefit from volume growth in the CGD sector.

Q: What is the timeline for the commissioning of the GMPL PTA plant and the PDH-PP plant, and when will they contribute to EBITDA? A: The CFO stated that the 1,250 KTA PTA plant at GMPL is in an advanced stage of commissioning and should start production shortly. The 500 KTA PDH-PP plant is scheduled for commissioning by June '27, but may take an additional six to seven months, potentially completing by December '27. The company has not booked profits for FY27-28 for these projects.

Q: Can you provide guidance on depreciation and interest run rates given the commissioning of new projects? A: The CFO indicated that depreciation will be around INR3,200-3,300 crores annually based on the reviewed life of pipelines (40 years) and petrochemicals. The PDH-PP plant, with a total cost of around INR11,256 crores, will add approximately INR312 crores in annual depreciation. Total finance cost for Q1 was around INR310 crores, translating to roughly INR1,200-1,300 crores annually. The PDH-PP plant's debt of around INR6,000 crores will add approximately INR440 crores in annual interest costs.

Q: With the summer season demand cooling off, will gas transmission volumes decline from the Q1 level of 122.36 MMSCMD? A: The CFO maintained the FY27 transmission volume guidance of around 123 MMSCMD, which accounts for seasonal variations. Power sector consumption typically peaks in August-September and December-January. The guidance assumes the current geopolitical situation continues, and the company will update if material changes warrant a revision.

For the complete transcript of the earnings call, please refer to the full earnings call transcript .