
HPCL PAT up by 18% YoY for Q4 FY25 to INR 3,355 Crore
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Hindustan Petroleum Corporation Limited (HPCL) has reported a strong operational performance for the fourth quarter and full year ended March 31, 2025. In the January-March quarter, HPCL's refineries recorded the highest-ever quarterly throughput at 6.74 million metric tonnes (MMT). A key milestone for the quarter was the commencement of operations at HPCL's LNG regassification terminal in Chhara, Gujarat, signaling progress in the company's broader energy diversification strategy.
The company posted a 18 per cent year-on-year increase in standalone profit after tax (PAT) at INR 3,355 crore, up from INR 2,843 crore in the same quarter last year. Consolidated PAT stood at INR 3,415 crore, compared to INR 2,709 crore in Q4 FY24. Revenue from operations came in slightly lower at INR 1,18,334 crore, compared to INR 1,21,533 crore a year ago, but the gross refining margin (GRM) improved to $8.44 per barrel from $6.95.
On an annual basis, in FY25, the company achieved its annual refinery throughput at 25.27 MMT. The Visakh Refinery, which had undergone capacity expansion, processed over 15 MMT of crude oil, while the Mumbai Refinery set a new record with nearly 10 MMT of crude processing. HPCL also posted annual sales of 49.82 MMT, with domestic sales growing at 5.5 per cent.
Despite these operational highs, annual profitability took a hit. Revenue for the year edged up to INR 4,66,346 crore from INR 4,61,638 crore, but the average GRM dropped to $5.74 per barrel, down from $9.08 in FY24. This contributed to a fall in annual PAT to INR 7,365 crore from INR 14,694 crore last year. Consolidated PAT also declined to INR 6,736 crore, from INR 16,015 crore.

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Because the fluid is heavier, it creates fractures at lower surface pressure, making the process more efficient and controlled. This approach is similar to methods used for disposing of nuclear waste. Once the fracture network is established, the high-density fluid is circulated out and replaced with water, which is then cycled to extract heat, as described above. 4. What reservoir characteristics does the Sage method need to be viable, such as depth, temperature, overpressure, natural fracture permeability? How extensive are these potential locations in the USA? For comparison, hot, dry rock permeabilities in Los Alamos and Project Forge have extremely low permeabilities. Conventional geothermal requires a rare combination of three things: hot subsurface temperatures, naturally occurring water (an aquifer), and enough natural permeability to allow the water to flow. These conditions typically only exist near volcanic zones, such as those along the Ring of Fire. Sage's pressure geothermal approach removes two of those constraints. We don't rely on natural permeability or existing water – we create our own artificial reservoir and cycle water through it to extract heat. We specifically target low-permeability rock (< 50 millidarcies), temperatures of 170°C, and avoid natural faults and fractures. As a result, our method opens up vast new areas for geothermal development. In the U.S. Lower 48 alone, conservative estimates are 13 terawatts of geothermal potential down to 6 km (20,000 feet). Depths to reach 180C Anderson, Parker, et al. 5. A two-well pair provides almost continuous electricity for 24 hours. Can the supply of a few MW be made fully dispatchable for days or weeks at a time? Yes. Geothermal power generation is available regardless of weather conditions. Like all geothermal systems, Sage's technology experiences gradual thermal decline, about 10% over 5 years, as heat is extracted from the rock. What makes Sage different is our ability to refracture the same well into untouched hot rock every five years, restoring heat flow without having to drill a new well(s). 6. The fracture network is always operated between frac opening and frac extension pressure, and in each well, the fracture network is inflated for 12 hours before flow is reversed into the other well. You quote water loss is less than 2%. Is this loss per cycle? Yes, the < 2% water loss is per cycle as measured in the field and is primarily due to evaporation and leak-off into the formation. For geothermal power generation, we expect water losses to be even lower because the system operates as a closed-loop cycle with minimal evaporation. This is a major advantage over traditional EGS systems, where water losses are reported between 10-30%. Cindy Taff, CEO and co-founder of Sage. Sage 7. How does your cost per MWh compare with other next-generation geothermal methods, and with solar PV plus grid battery storage (BESS)? How does your mechanical energy storage cost per MWh compare with grid battery storage (BESS)? Pressure geothermal is expected to deliver significantly lower costs per MWh than other next-generation geothermal approaches. Closed-loop systems face higher drilling costs due to complex directional drilling and longer wellbores. EGS technologies lose efficiency from high parasitic pumping loads, venting pressure at surface, and 10-30% water losses. When paired with solar, Sage's energy storage delivers a blended LCOE of $60-70/MWh for 24/7 generation, comparable with solar plus batteries without tax credits. Sage's mechanical storage is not intended to compete with lithium-ion for < 5-hour durations, but will outperform batteries for durations > 5 hours. 8. What advantages does the Sage method have over other methods such as twin-well EGS (Enhanced Geothermal Systems) or closed-loop systems? Compared to EGS, Sage's approach avoids the need for sophisticated high-temperature directional drilling technologies as the wellbore alignment and spacing are not critical, and it doesn't require connecting two wells with a fracture network. It also minimizes water loss (< 2% per cycle) and delivers 25-50% more net power output, resulting in a lower cost per MWh. Compared to closed-loop systems, Sage can access a large heat transfer area in less than a day through fracturing, versus months of precision drilling required to construct long well loops. This reduces both drilling risk and cost. 9. What is the commercial stage/position of Sage's various technologies? Sage's energy storage technology has reached Technology Readiness Level (TRL-8), with a 3MW commercial facility built, tested, and ready to start operations in Q4 2025 after the grid interconnection is complete. Sage's geothermal power generation is at a TRL-7, with its first commercial plant planned for 2026/2027 as part of Phase I for a Meta data center east of the Rockies. 10. Do you foresee Sage applications of individual well-pairs (a few MW) providing a bridge to other massive energy supplies? And what is the potential, and cost, of many well-pairs scaled to the needs of data centers or electrical grids (hundreds of MW)? Sage's geothermal technology is scalable by drilling multiple wells from a single pad, much like unconventional oil and gas. For projects > 100 MW, such as Meta, we anticipate costs between $60-100/MWh, depending on the location and therefore the geothermal resource depth. Sage's unique subsurface approach, which relies on fractures connected to a single wellbore, will increase our access to superhot geothermal resources as compared to EGS and Closed Loop, as wellbore alignment and spacing are not critical, eliminating the need for sophisticated high-temperature directional drilling equipment. Deeper and hotter geothermal can deliver a 10-fold increase in net power generation, which enables further cost reductions 11. I've heard that Sage can buy electricity when production is plentiful, convert it to pressure similar to conventional pumped storage hydropower and later sell it back to the grid when needed. Is this system operational, and will it be cheaper than grid-scale batteries whose cost is falling? Sage has completed its first commercial 3MW energy storage system at the San Miguel Electric Cooperative in Christine, Texas, with operations starting in Q4 2025 once grid interconnection is complete. 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