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GS Paper: GS3-13.Infrastructure: Energy, Ports, Roads, Airports, Railways etc:

  • Small transporters hit by compliance burden

    Why in the News

    The road transport industry, which carries nearly 70 per cent of India’s domestic freight, has been described as facing one of the most difficult periods in its history. Operating costs for commercial vehicles have risen sharply over the last few years. Freight rates have stayed largely stagnant over the same period. Vehicle location tracking devices, originally conceived for passenger safety and emergency response, have since been mandated for goods vehicles as well. Faults in integrating those devices with the VAHAN portal have left commercial vehicles stranded for weeks and in some cases months. The contest is between technology driven governance, which promises transparency and enforcement quality, and its implementation cost, which falls hardest on the small operators who have no margin left to absorb it.

    What is a Vehicle Location Tracking Device (VLTD)?

    1. Function: A Vehicle Location Tracking Device (VLTD) is an onboard unit that continuously transmits a vehicle’s position to a State level control centre over a mobile network. It carries emergency buttons that raise an alert to that centre.
    2. Original purpose: The device was conceived for passenger safety and emergency response, so that a distress signal from a bus or a cab could be located and acted on.
    3. Registration linkage: A fitted device must be registered against the vehicle on the VAHAN portal, the Ministry of Road Transport and Highways database that holds every vehicle’s registration record. A vehicle whose device does not map correctly to that record cannot complete its compliance formalities.

    Why has the road freight business turned financially unsustainable?

    1. Costs and earnings have moved apart: The gap between operational expenses and earnings has widened steadily. Freight rates have not tracked the rise in the cost of running a truck.
    2. Fuel dominates the cost sheet: Diesel alone accounts for nearly 60 per cent of a truck’s operating cost. Every rise in the pump price passes almost directly into the operator’s monthly outgo.
    3. Emission compliance added a new input: Operators have had to absorb the cost of AdBlue, the urea solution injected into the exhaust of Bharat Stage VI (BS-VI) vehicles to cut nitrogen oxide emissions. This is a recurring consumable that did not exist in the earlier cost structure.
    4. Every other input has escalated: Tyre prices, insurance premiums, spare parts, engine oil, lubricants, maintenance expenses, finance costs and statutory compliance charges have all risen together. Toll charges continue to rise alongside them.
    5. Margins have gone below cost for some: Many transporters operate on wafer thin margins simply to retain business. Some are running below their actual cost of operations.

    What has the compliance and enforcement layer added?

    1. Documentation load has grown: The burden of documentation, permits, fitness requirements and other regulatory compliances has increased substantially. Each of these carries its own fee, its own renewal cycle and its own downtime.
    2. Electronic challans have drawn allegations of misuse: The electronic challan was introduced to minimise human intervention and improve road safety. A growing number of transporters allege misuse of the system, producing avoidable penalties and harassment.
    3. Tracking devices were extended without a stated case: The VLTD mandate was extended to goods vehicles in the absence of clear operational necessity. A device designed around passenger distress response was applied to freight movement, adding a financial burden with no matching benefit to the operator.
    4. Integration failure converts compliance into downtime: Technical problems in integrating VLTD units with the VAHAN portal have left many commercial vehicles off the road for weeks and in some cases months.
    5. Downtime compounds financially: Each day a truck stays off the road means lost income, continuing loan repayment pressure and severe financial distress for the operator. The loan instalment does not pause because the portal did not accept the device.

    Does technology driven governance deliver transparency or only new hardship?

    1. The intent is not in dispute: Technology driven governance is welcome where it promotes transparency and efficiency. Both the electronic challan and the tracking mandate were framed in exactly those terms.
    2. Implementation is where the cost lands: A mandate is issued centrally and instantly, while its back end integration is completed unevenly across States and vendors. The operator carries the difference as idle capital.
    3. Enforcement quality decides the outcome: Enforcement must remain transparent, accountable and fair, so that genuine operators are not penalised alongside violators. An automated penalty with no accessible appeal converts a safety tool into a revenue tool.
    4. The burden is uniform, the capacity to bear it is not: A compliance charge set as a flat per vehicle amount is trivial for a large fleet and material for a single truck owner. The same rule therefore produces very different pressure across the sector.
    5. Digital mandates need a working failure route: No route exists for an operator whose device is fitted and paid for but not accepted by the database. The vehicle is treated as non compliant even where the failure is on the system side.

    Why are small operators and self-driving truck owners hit hardest?

    1. They absorb every shock directly: Small transport operators and self-driving truck owners are affected the most by these developments. They have no fleet across which to spread a stranded vehicle or a disputed penalty.
    2. The sector is structurally fragmented: Most road freight capacity sits with small, unorganised firms and single truck owners rather than large corporate fleets. Fragmentation leaves no bargaining power against shippers on freight rates.
    3. Finance costs bite first: Vehicle loans are serviced monthly regardless of utilisation. An operator with one or two trucks moves into default faster than a fleet operator with the same days of downtime.
    4. Highway amenities have not followed toll payments: Despite paying substantial toll charges, drivers continue to face a shortage of secure truck parking zones, clean toilets, rest areas and other basic highway amenities.
    5. Tolls are a rising fixed charge: Toll charges require rationalisation, since they now form a large and rising share of the per trip cost on tolled corridors. A rate that is not linked to service delivered is a pure cost addition.

    Challenges to the road freight compliance regime

    1. Freight rates are not cost linked: No mechanism ties freight rates to the actual cost of operating a truck, so input inflation is absorbed rather than passed on. Eg. The rise in diesel, tyre and insurance costs over recent years has not produced a matching rise in contracted freight rates. Fix. Base freight rates on scientific cost calculations that reflect actual operating expenses and are revised on a stated cycle.
    2. Device mandates run ahead of system readiness: A device is made compulsory before the registration database can reliably record it, so compliant operators are penalised for a back end fault. Eg. VLTD to VAHAN integration failures have kept commercial vehicles off the road for weeks and months. Fix. Tie the commencement of any device mandate to a certified integration test, and grant an automatic provisional clearance where the portal fails to accept a fitted device.
    3. Automated enforcement lacks a low cost appeal route: An electronic penalty is issued instantly while contesting it requires time and travel that a single truck owner cannot spare. Eg. Transporters allege misuse of the electronic challan system producing avoidable penalties. Fix. Provide a time bound online adjudication route with photographic evidence disclosure at the point of the challan.
    4. Compliance costs are not scaled to fleet size: Fees, permits and fitness requirements are set per vehicle, so the smallest operator carries the highest cost per rupee of turnover. Eg. Statutory compliance charges have escalated alongside tyre, insurance and finance costs for operators running one or two trucks. Fix. Introduce a graded fee structure and a single consolidated annual compliance filing for operators below a stated fleet threshold.
    5. Toll collection is not linked to service: Toll rates rise on schedule while wayside amenities on the same corridors remain absent. Eg. Drivers on tolled highways face a shortage of secure parking zones, clean toilets and rest areas. Fix. Make a stated wayside amenity standard a condition of toll revision on each stretch, audited before the next revision is notified.
    6. Overloading and safety enforcement fall on the driver, not the shipper: Penalties for overloading attach to the vehicle and the driver, leaving the consignor who loaded it untouched. Eg. Overloaded highways suffer rapid wear and tear while enforcement action is recorded against the transporter. Fix. Extend statutory liability for overloading to the consignor and the loading point operator.

    Conclusion

    The compliance burden on road freight has grown faster than the sector’s ability to pay for it, and the cost has settled on small operators and self-driving truck owners rather than on large fleets. The immediate cause is not the principle of technology driven governance but its implementation, where a mandate takes effect before the system that records it works. A comprehensive review of the road transport ecosystem is the stated demand, resting on three things: freight rates built on scientific cost calculations, rationalised tolls, and a relook at the compliance load. None of the three has been taken up.

    “[2014, GS3, 12 marks] National Urban Transport Policy emphasises on ‘moving people’ instead of ‘moving vehicles. Discuss critically the success of the various strategies of the Government in this regard.”

  • Ethanol blending policy is behind rise in sugar prices, says Opposition

    Ethanol blending policy is behind rise in sugar prices, says Opposition

    Why in the News

    Retail sugar prices reached Rs 62.5 to Rs 64 per kg in Maharashtra and Rs 63 to Rs 64 per kg in Karnataka on 20 August. The corresponding ranges on 1 August were Rs 46.2 to Rs 46.9 and Rs 46.25 to Rs 47 per kg, with Uttar Pradesh at Rs 44.95 to Rs 46.7. Closing stocks for the 2025-26 sugar season are set to fall to a nine-year low on a production shortfall. The ethanol blending programme has been named as the cause of the spike. What is contested is whether diverting cane to fuel drove the price rise, or whether a crop failure larger than the diversion did.

    What is the Ethanol Blended Petrol Programme?

    1. A fuel substitution programme run through sugar mills: The Ethanol Blended Petrol (EBP) Programme requires oil marketing companies to blend ethanol into petrol, and it sources that ethanol partly from sugarcane. It runs under the National Policy on Biofuels, 2018.
    2. Cane can be diverted at three points: Mills may make ethanol from direct sugarcane juice or syrup, from B-heavy molasses, or from C-heavy molasses, each of which sacrifices a different quantity of sugar.
    3. The 20 per cent target was met early: The blending target of 20 per cent ethanol in petrol was achieved ahead of its 2025-26 deadline.
    4. It exists to fix mill finances as much as fuel imports: Diversion gives mills a buyer who pays on delivery, which shortens the cane payment cycle to farmers and cuts crude oil imports at the same time.

    What is sugar recovery?

    1. Recovery is the yield of the crush: Recovery rate is the sugar produced expressed as a percentage of the cane crushed, and it decides how much sugar a given tonnage of cane actually yields.
    2. It is set in the field, not the mill: Recovery depends on sucrose accumulated in the cane stalk, which needs sunlight and aeration in the ripening months, so a waterlogged crop lowers recovery even where tonnage holds up.

    What are B-heavy and C-heavy molasses?

    1. Molasses grades mark how much sugar is left behind: Molasses is the residue after sugar crystals are extracted, and B-heavy molasses is drawn off at an earlier stage than C-heavy molasses, so it retains more fermentable sugar.
    2. The grade decides the sugar sacrificed: One tonne of ethanol from C-heavy molasses costs almost no sugar, B-heavy costs more, and direct juice or syrup costs the most, which is why diversion policy is set grade by grade.

    India’s sugar balance sheet: what do the numbers show?

    Sugar Year (Oct-Sep)Opening StocksDomestic OutputDomestic ConsumptionExportsClosing Stocks
    2016-1772.5202.62244.480.4639.41
    2017-1839.41323.28253.96.32104.71
    2018-19104.71331.6225538143.33
    2019-20143.33273.8525359.4104.78
    2020-21104.78311.22607283.98
    2021-2283.98359.2526211071.23
    2022-2371.233312816457.23
    2023-2457.23319295180.23
    2024-2580.23261.8284850.03
    2025-26*50.03279280841.03

    All figures in lakh tonnes. *Industry estimates. Source: National Federation of Cooperative Sugar Factories Ltd.

    1. The season starts with just over 50 lakh tonnes: Opening stocks for 2025-26 stood at 50.03 lakh tonnes, so total sugar available after adding production works out to about 329 lakh tonnes.
    2. Consumption and exports leave 41 lakh tonnes: Deducting domestic consumption of 280 lakh tonnes and exports of 8 lakh tonnes closes the season at around 41 lakh tonnes.
    3. That is the lowest in nine years: The last time closing stocks were lower was 39.41 lakh tonnes in 2016-17.
    4. A disputed opening figure makes it worse: Some in the industry hold that opening stocks were only 48 lakh tonnes rather than 50.03 lakh tonnes, which would take closing stocks to 39 lakh tonnes, the lowest since 2008-09.
    5. The peak was three seasons of surplus: Closing stocks ran to 143.33 lakh tonnes in 2018-19 and were still 104.78 lakh tonnes in 2019-20, so the current tightness follows a period of overhang, not chronic scarcity.

    Why did production fall so far below projection?

    1. The apex body projected a large crop: The Indian Sugar and Bio-energy Manufacturers Association (ISMA), the association of private sugar mills, estimated gross production for the 2025-26 season at 343.5 lakh tonnes in early November 2025. After 34 lakh tonnes of ethanol diversion, it pegged net output at 309.5 lakh tonnes.
    2. The actual crop came in far smaller: Latest industry estimates put gross production at 309 lakh tonnes and ethanol diversion at 30 lakh tonnes, leaving net output at 279 lakh tonnes. Net output is therefore 30.5 lakh tonnes below the 309.5 lakh tonnes originally projected on a net basis.
    3. Excess rain hit the crop at the wrong time: The cane crop in Maharashtra, Karnataka and Gujarat suffered excess rainfall in September and October last year, with a delayed withdrawal of the southwest monsoon.
    4. Waterlogging cut both tonnage and recovery: Waterlogged fields combined with a lack of sunshine deprived the standing crop of aeration and daylight. That affected cane growth and sucrose accumulation in the stalks, lowering yields and mill recovery.
    5. The two tropical States missed badly: ISMA had projected Maharashtra at 130 lakh tonnes and Karnataka at 63.5 lakh tonnes, and their mills produced only 99.2 lakh tonnes and 47.2 lakh tonnes.
    6. Uttar Pradesh lost output to disease and pest: Factories in the State produced 89.7 lakh tonnes against an earlier estimate of 103.2 lakh tonnes. Red rot fungal disease and the top shoot borer insect pest were the chief causes, and the dominant Co-0238 cane variety has grown increasingly susceptible to both.

    What turned a shortfall into a price spike?

    1. Prices were flat for most of the season: Average ex-factory prices in Maharashtra fell from Rs 38.31 to Rs 36.98 per kg between September 2025 and April 2026, then recovered to Rs 38.23 by June. They rose from July, averaging Rs 41.85 per kg that month.
    2. Declared mill stocks were doubted: Some liquidity-strapped mills had already sold sugar beyond their government-fixed monthly release quotas and had little left. The stocks they declared existed on paper.
    3. A second bad monsoon was priced in early: High rainfall deficiency in June, particularly in Maharashtra and Karnataka, convinced the trade that yields and production would take a hit in the 2026-27 season as well.
    4. Buyers and sellers both moved first: Larger merchants, stockists and bulk industrial consumers began taking positions before July. From August some mills started holding back sales in anticipation of higher prices ahead of the festival season.

    Where does India’s ethanol actually come from?

    1. Sugarcane supplies under a third: Of 810.67 crore litres of ethanol supplied to oil marketing companies for blending between November 2025 and July 2026, only 259.24 crore litres or 32 per cent came from sugarcane-based feedstock.
    2. Direct juice and syrup is the largest cane route: Direct juice or syrup contributed 147.6 crore litres, B-heavy molasses 98.19 crore litres and C-heavy molasses 13.45 crore litres.
    3. Grain supplies the balance: Distilleries using grain-based feedstock supplied 551.43 crore litres or 68 per cent of the total.
    4. Maize leads the grain feedstock: Maize accounted for 288 crore litres, Food Corporation of India rice 207.1 crore litres and broken or damaged foodgrains 56.33 crore litres.

    Is ethanol diversion the cause of the spike or a scapegoat for a crop failure?

    1. The diversion looks large in isolation: Thirty lakh tonnes of sugar went into ethanol in the current season, which is more than two-thirds of the season’s projected closing stock.
    2. The crop failure was larger than the diversion: Gross production before any diversion came in 34.5 lakh tonnes below the initial gross estimate of 343.5 lakh tonnes, so the sugar lost to the weather exceeded the sugar lost to fuel.
    3. Two-thirds of blended ethanol never touched cane: The blending target is being met mainly out of maize and rice, so cutting cane diversion to zero would remove only a third of the programme’s feedstock demand and not a third of the price.
    4. Reversing diversion moves the problem, it does not remove it: Ethanol sales are the payment stream that lets mills clear cane dues on time, so a ban on juice and B-heavy diversion converts a consumer price problem into a farmer arrears problem.

    What has the government done to check sugar prices?

    1. Exports banned on 13 May: All sugar exports were banned until 30 September 2026. It was a precautionary move rather than a response to a confirmed shortage.
    2. Duty-free imports opened this week: Import of up to 10 lakh tonnes of raw sugar at zero duty was allowed until 31 October, against the standard tariff of 100 per cent on the sweetener.
    3. Refiners at Kandla will process the raws: The raw sugar can be processed by companies operating refineries at Gujarat’s Kandla port, such as Shree Renuka Sugars and Shri Dutta India Private Ltd. The refined output can supply the market until Indian mills begin cane crushing from end-October to early November.
    4. Stock limits imposed on 28 July: A stocking limit of 400 tonnes was imposed on all sugar dealers, and no dealer may hold any sugar beyond 30 days of receiving it.
    5. Bulk buyers put under disclosure on 13 August: Mills were directed by letter to furnish details of bulk consumers such as soft drink and confectionery makers and sweetmeat sellers who bought 500 tonnes or more annually, directly or through agents, during the 2025-26 financial year.
    6. A diversion curb is expected next: The government is expected to direct mills not to manufacture ethanol from direct sugarcane juice and B-heavy molasses in the 2026-27 season, on the stated priority of augmenting domestic sugar supply.

    Challenges to the Ethanol Blended Petrol Programme

    1. Grain has crowded out cane as feedstock: Grain-based distilleries now supply more than twice the volume the cane routes do, which shifts the food security question from sugar to cereals. Eg. Food Corporation of India rice was released to distilleries in the current supply year. Fix. Cap grain feedstock at a notified share of annual blending and reserve open market cereal releases for the public distribution system.
    2. Procurement prices have not tracked cane costs: Ethanol procurement prices have stayed largely stagnant as the Fair and Remunerative Price for cane has risen, squeezing distillery margins. Eg. Cane FRP rose from Rs 285 per quintal in 2020-21 to Rs 355 per quintal in 2025-26. Fix. Index the ethanol procurement price for each feedstock route to the notified cane price through a published formula.
    3. Distillation capacity sits underused: Mills built distilleries on the expectation of assured diversion, and capacity idles whenever policy switches back to sugar. Eg. Many mills face underutilised distillation capacity in the current season. Fix. Publish a three-year rolling diversion band so investment decisions are made against a stated range rather than an annual notification.
    4. Higher blends carry a vehicle cost: Ethanol has a lower energy density than petrol, so fuel efficiency falls by roughly 2 to 6 per cent at higher blend levels and older engines face material compatibility issues. Eg. Vehicles manufactured before E20 compliance norms were not certified for the current blend. Fix. Mandate a labelled dual fuel dispensing option at retail outlets so owners of non-compliant vehicles retain a lower blend choice.
    5. Cane ethanol carries a heavy water footprint: Sugarcane is grown largely in water-stressed tropical districts, so cane-based ethanol transfers an irrigation burden to the fuel sector. Eg. Maharashtra and Karnataka face groundwater depletion in the same belts that supply mill cane. Fix. Restrict juice and B-heavy diversion licences to mills that have converted a notified share of their command area to drip irrigation.

    Conclusion

    The sugar price spike is the result of a crop that came in 34.5 lakh tonnes below projection in gross terms, stocks doubted by the trade and positions taken ahead of the festival season, not of ethanol diversion that supplied under a third of blended fuel. The government has answered on the supply side, with an export ban, duty-free raw imports, dealer stock limits and bulk-buyer disclosure. A curb on cane-based ethanol in 2026-27 would trade a consumer price problem for a cane arrears problem. The season will close on the tightest stock position in nine years, and next season’s crop is already being discounted for a deficient June.

    “[2025] Consider the following statements:

    Statement I: Of the two major ethanol producers in the world, i.e., Brazil and the United States of America, the former produces more ethanol than the latter.

    Statement II: Unlike in the United States of America, where corn is the principal feedstock for ethanol production, sugarcane is the principal feedstock for ethanol production in Brazil.

    Which one of the following is correct in respect of the above statements?

    (a) Both Statement I and Statement II are correct and Statement II explains Statement I

    (b) Both Statement I and Statement II are correct but Statement II does not explain Statement I

    (c) Statement I is correct but Statement II is not correct

    (d) Statement I is not correct but Statement II is correct

  • Pakistan factor: Why West Asia war hurt Indian airlines more than foreign ones

    Why in the News

    International air passenger traffic to and from India fell 9.1 per cent year on year in April to June 2026, to 1.72 crore, after the West Asia conflict closed large parts of Gulf airspace. The decline was driven entirely by Indian carriers, whose combined international traffic fell 26.6 per cent. Foreign airlines carried 6 per cent more passengers than a year earlier. India has barred its own carriers from Pakistani airspace since late April 2025, and Pakistan’s reciprocal closure applies only to them. The result is that a shared shock produced an asymmetric outcome, transferring market share on India’s own international routes to airlines that could still fly the short way west.

    How does an airspace ban change an airline’s operating economics?

    1. The right involved: A carrier overflies a third country under the International Air Services Transit Agreement of 1944 or under a bilateral permission, and either can be withdrawn at short notice.
    2. The detour cost: A closure forces a longer track, which adds block hours, fuel burn and crew duty time to every affected departure.
    3. The payload penalty: A longer sector makes the aircraft trade revenue payload for fuel, or forces a technical stop, and either outcome erodes the margin on the route.

    What does the passenger data show?

    1. Total volume: Total international air passenger volume to and from India fell 9.1 per cent year on year in April to June, from 1,89,12,598 to 1,72,00,140, in an analysis of Directorate General of Civil Aviation (DGCA) data.
    2. Indian carriers: Their combined international passenger numbers fell 26.6 per cent, from 87,34,038 to 64,14,896.
    3. Foreign carriers: Their cumulative passenger base rose 6 per cent, from 1,01,78,560 to 1,07,85,244.
    4. Market share shift: Foreign operators expanded their share of India’s international traffic to 62.7 per cent from 53.8 per cent, and domestic carriers dropped to 37.3 per cent from 46.2 per cent.

    Why did the loss fall on Indian carriers alone?

    1. Their biggest market closed: Flights to the United Arab Emirates and other West Asian markets, the largest destinations for Indian airlines, were heavily curtailed.
    2. The damage spread beyond West Asia: Indian carriers were forced to cut flights to destinations well outside the region, under war related financial pressure and the standing ban on flying over Pakistan since late April 2025.
    3. The route economics broke first: Air India and IndiGo curtailed their west bound network because the unavailability of Pakistani airspace made some services financially and operationally unviable to run.
    4. The pressure predated the war: Both leading carriers were already taking longer routes and adding refuelling halts on west bound services from their Delhi hub before the conflict began in late February, and some routes had been suspended outright.

    How did foreign carriers turn the same shock into share?

    1. They kept the short way west: Foreign carriers faced the same surging jet fuel prices, and many held one decisive advantage in the continued availability of Pakistani airspace.
    2. Spare capacity was redeployed: Once the war began, carriers from Europe and other regions west of India increased operations to and from the country using aircraft freed by their own curtailed West Asia flying.

    Which Indian airlines lost most?

    1. IndiGo: Remained the largest Indian carrier on international routes with a 15.4 per cent decline to 33.4 lakh international flyers, and an international market share slipping to 19.4 per cent from 20.9 per cent.
    2. Air India: Fell 27.2 per cent to 19.3 lakh passengers, with its international market share contracting to 11.2 per cent from 14 per cent.
    3. Air India Express: Its footfall halved to 8.34 lakh, since its network is highly concentrated in West Asia, and its share fell to 4.8 per cent from 8.9 per cent.
    4. The Air India group: Combined international traffic fell 36.3 per cent year on year to 27.61 lakh in the quarter.
    5. SpiceJet: Recorded the sharpest percentage fall at 56 per cent, to 1.38 lakh international flyers, with share contracting to 0.8 per cent from 1.7 per cent.
    6. Akasa Air: The only Indian airline to register higher international passenger numbers, growing on a low base through an expanding fleet.

    Challenges to Indian carriers on international routes

    1. Gulf hubs capture the through fare: Foreign carriers connect Indian cities to the West over their own hubs and book the full journey revenue. Eg. Emirates, Qatar Airways and Etihad carry a large share of India to Europe and North America traffic over Dubai, Doha and Abu Dhabi. Fix. Build a domestic transfer hub with matched arrival and departure banks, and price transfer charges to reward connecting traffic.
    2. Wide body fleet shortage: Non stop long haul flying needs aircraft Indian carriers do not have in sufficient number. Eg. Air India’s wide body cabin refit programme has run behind schedule because of queues at overseas retrofit facilities. Fix. Expand domestic maintenance, repair and overhaul capacity so heavy checks and retrofits are not queued abroad.
    3. Fuel taxation: Aviation turbine fuel sits outside the goods and services tax and carries high state value added tax, so the largest cost line is not creditable. Eg. Fuel accounts for about 40 per cent of an Indian airline’s operating cost. Fix. Bring aviation turbine fuel under the goods and services tax with input tax credit for carriers.
    4. Ageing bilateral entitlements: Traffic rights negotiated years ago cap Indian carriers in some markets. The same rights leave foreign carriers entitlements they can deploy at short notice. Eg. India’s bilateral seat entitlement with the United Arab Emirates has been unchanged for over a decade. Fix. Renegotiate bilaterals with entitlement tied to actual utilisation and reciprocal hub access.
    5. Financing and leasing sit offshore: Most aircraft are leased through foreign lessors, so rentals and repossession law lie outside Indian jurisdiction. Eg. The aircraft leasing framework at Gujarat International Finance Tec-City (GIFT City) remains small relative to the fleet on lease. Fix. Deepen the domestic leasing regime and fully operationalise the Protection of Interests in Aircraft Objects Act, 2025 giving effect to the Cape Town Convention.

    Conclusion

    The quarter’s traffic decline was distributed by airspace access rather than by exposure to the war, so Indian carriers absorbed the whole of a shock both sides faced. The share transferred to foreign operators is not automatically reversible, since network presence and slot use tend to persist once established. Recovery depends on the reopening of Pakistani airspace to Indian carriers and on the restoration of West Asian capacity, neither of which is within the sector’s control.

    “[2024, GS3, 15 marks] What is the need for expanding the regional air connectivity in India? In this context, discuss the government’s UDAN Scheme and its achievements.”

  • Indigenous N-reactors top pick for companies in nuclear power expansion

    Why in the News

    The indigenous Pressurised Heavy Water Reactor (PHWR) is emerging as the preferred technology for new entrants into India’s civil nuclear power sector, as the tightly regulated strategic sector opens to private players. Representatives of the National Thermal Power Corporation (NTPC), Adani Atomic Energy and Jindal Steel said at a panel discussion at the BloombergNEF Summit in New Delhi that the existing 700 megawatt electric (MWe) PHWR is the right starting point, given established design standards, a mature domestic supply chain and an existing ecosystem of vendors. The discussion followed the release of the draft rules under the Sustainable Harnessing and Advancement of Nuclear Energy for Transforming India Act, 2025 (SHANTI Act, 2025), about a week earlier. The choice is revealing: entrants are picking the reactor with the least regulatory and supply risk rather than the one that scales fastest, and that reactor alone cannot deliver the 100 gigawatt electric target set for 2047.

    What is a Pressurised Heavy Water Reactor?

    1. Design: A pressurised heavy water reactor uses heavy water as both moderator and coolant, which lets it run on natural uranium without any enrichment step.
    2. Why it suited India: Natural uranium fuelling matched a country with limited enrichment capacity that long stood outside international fuel supply arrangements.
    3. Place in the programme: It is Stage 1 of the three stage nuclear programme designed by Homi Bhabha, producing plutonium 239 as a by product for the fast breeder stage that follows.
    4. The Indian standard unit: The 700 MWe variant is the largest indigenous design in the series.

    What is a Small Modular Reactor?

    1. Definition: A small modular reactor (SMR) is an advanced reactor of up to 300 MWe, built as factory made modules and transported to site for assembly.
    2. Use case: The smaller unit size suits captive industrial power and the replacement of retiring coal units on existing sites.

    Why are private entrants choosing the 700 MWe PHWR?

    1. Design certainty: The 700 MWe design is standard, approved, operational and already carries regulatory clearance, in the assessment of the business head of Adani Atomic Energy.
    2. Supply chain depth: The supply chain for that design in India is almost fully indigenised, at 90 per cent to 95 per cent.
    3. What the sector is short of: The two major constraints named for the sector are the availability of a robust supply chain and the lack of standardised reactor designs, and the 700 MWe unit is the one design that resolves both.
    4. A second entrant agrees: Jindal Steel plans to go with 700 MWe PHWRs in its initial phase for the same reason, moving to other technologies in later phases as clarity emerges on supply chains, regulatory approvals and standardisation.

    What capacity are the new entrants targeting?

    1. The national target: India aims to scale domestic civil nuclear capacity to 100 gigawatt electric (GWe) by 2047.
    2. Corporate targets: NTPC’s capacity target is 30 GWe, the Adani group’s is 10 GWe, and Jindal Steel’s is 18 GWe in the coming years.

    What has opened the sector to private entrants?

    1. Statutory replacement: The SHANTI Act, 2025 supersedes the Atomic Energy Act, 1962 and the Civil Liability for Nuclear Damage Act, 2010.
    2. End of the state monopoly: It permits private and foreign firms to build, own and operate reactors, which no earlier law allowed.
    3. Regulator strengthened: It gives the Atomic Energy Regulatory Board independent statutory status for safety oversight.
    4. Liability rewritten: It removes statutory supplier liability and sets tiered damage caps, with a Nuclear Damage Claims Commission to adjudicate compensation after an incident.
    5. What the Centre keeps: Enrichment, reprocessing and uranium and thorium exploration remain with the Union government.
    6. What the draft rules cover: The rules released in August 2026 set out the framework for private participation, captive generation, licensing, safety oversight and nuclear liability.

    Why will the PHWR alone not deliver 100 GWe?

    1. The stated limit: PHWRs alone will not be sufficient to reach 100 GWe by 2047, in the assessment of the Adani Atomic Energy business head.
    2. The intended sequence: Deploy 700 MWe PHWRs in fleet mode first, follow with pressurised water reactors (PWRs), and bring in small modular reactors at a later point.
    3. Where foreign designs fit: Foreign reactor technologies and SMRs are expected to play a role only at a later stage, once the sector matures.
    4. The phasing is deliberate: Later phases are contingent on clarity around supply chains, regulatory approvals and design standardisation, not on a fixed date.

    What will decide whether imported designs work in India?

    1. Localisation is the condition: Global reactor technologies, including PWRs and SMRs, would need to maximise localisation in India to stay commercially viable.
    2. Cost sets the ceiling: Cost matters a great deal in the Indian market, and any technology has to reach a price the buyer of the electricity will commit to.
    3. The buyer decides: For a project to make commercial sense the consumer has to accept the tariff, which puts affordability ahead of technology preference in the selection.

    Challenges to India’s 100 GWe nuclear target

    1. The heavy component vendor base is shallow: Only a handful of Indian firms can forge and supply large reactor components, so a fleet order queues behind them. Eg. Larsen and Toubro and Bharat Heavy Electricals supply most large forgings and steam generators for the domestic programme. Fix. Qualify a second tier of suppliers through advance purchase commitments tied to the sanctioned fleet order book.
    2. No certified standard design outside the heavy water line: A project without a frozen design spends years in negotiation before construction. Eg. The Jaitapur project with the European Pressurised Reactor has been under negotiation since 2010 without first pour of concrete. Fix. Certify one design per technology class through the regulator before any commercial order is placed.
    3. Tariff acceptance by distribution utilities: Nuclear power has to clear the price a distribution company will sign a purchase agreement at. Eg. Around 42 gigawatts of renewable capacity currently sits without a power purchase agreement on price grounds. Fix. Create a separate payment for firm, dispatchable low carbon power so the grid pays for reliability rather than for energy alone.
    4. Insurance capacity is thin: Liability caps do not create the underwriting capacity a reactor needs. Eg. The India Nuclear Insurance Pool formed in 2015 carries a capacity of ₹1,500 crore. Fix. Expand the pool with reinsurance from global nuclear insurance pools, now that supplier liability has been removed.
    5. Licensed operator manpower: A fleet of reactors needs certified control room staff that only one training system currently produces. Eg. Operator training runs almost entirely through the Department of Atomic Energy’s own training schools. Fix. Accredit private and university training programmes against a regulator certified curriculum and examination.

    Conclusion

    Private entry into nuclear power has reached the point where entrants are naming capacity targets and choosing a reactor, and all three have chosen the indigenous 700 MWe pressurised heavy water reactor over imported designs. The regulatory framework is at the draft rules stage under the SHANTI Act, 2025, released by the Department of Atomic Energy, with comments closing on 4 September 2026. Whether the 100 GWe target is reachable turns on the technologies after the first fleet, and on whether foreign designs localise enough to reach a tariff a distribution utility will sign.

    “[2018, GS3, 15 marks] With growing energy needs should India keep on expanding its nuclear energy programme? Discuss the facts and fears associated with nuclear energy.”

  • The Silver Bullet: Why everyone loves a Metro

    Why in the News

    Around 200 residents of Greater Noida West tied ropes to the last Metro pillar at the Sector 71 intersection in April and pulled, in a protest organised by the Noida Extension Flat Owners Welfare Association to demand a Metro line for an area it calls underserved by public transport. Days earlier the Central government had rejected the proposal for the Noida to Greater Noida West Metro corridor. Meerut became the latest city to get a Metro in February 2026, with an interchange to the Regional Rapid Transit System (RRTS), India’s first semi high speed intercity rail service. The tension the two scenes expose is that demand for a Metro is now generated by politics and property. The ridership, fares and feeder transport that would justify one are generated by city planning that has not happened.

    What is the Metro Rail Policy, 2017?

    1. Purpose: It sets the conditions the Union government applies before it will approve or fund a metro rail project proposed by a state.
    2. Alternatives test: A state must evaluate cheaper options, including buses, bus rapid transit and trams, before committing to a metro, because metro rail is the costliest urban transport mode to build.
    3. Viability emphasis: It places greater weight on the financial viability of a project than earlier practice did.
    4. Appraisal method: It requires appraisal through economic and social cost benefit analysis, treating urban rail as a public project that delivers a public good.

    What is a Detailed Project Report?

    1. Definition: A Detailed Project Report (DPR) is the blueprint that lays out a metro project’s design, its costs, its ridership projection and its financial viability.
    2. Function: It is the document the Union government appraises the proposal against, and the document later audits measure actual performance against.

    How large has India’s Metro network become?

    1. Fourfold growth: The network has gone from around 250 km a decade ago to more than 1,100 km across 26 megacities and Tier 2 cities, with another 900 km under construction.
    2. Rate of sanction: The government is sanctioning 6 km of Metro lines every month.
    3. A young network: More than three fourths of the current network was conceived, constructed and operationalised less than 10 years ago.
    4. Aggregate ridership: Daily ridership across the country has crossed the 1 crore mark and is expected to exceed 1.25 crore in a year or two.
    5. The capacity argument: Some Delhi Metro corridors handle more than 50,000 passengers in the peak hour in the peak direction, and the Ministry of Housing and Urban Affairs calculated in January 2024 that serving that demand by bus would need 715 buses an hour in one direction, roughly one every five seconds.

    Which cities run a Metro, and how do the systems compare?

    1. Kolkata, 1984: The country’s first Metro system, and the only one run by the Indian Railways.
    2. Delhi, 2002: The Delhi Metro Rail Corporation (DMRC) now runs 416 km with an average daily ridership of about 64 lakh, the largest network in the country.
    3. Bengaluru, 2011: Namma Metro runs 96 km, the second largest operating system outside the National Capital Region.
    4. Meerut, 2026: The newest system runs 23 km with an average daily ridership of about 1 lakh, a figure that includes RRTS ridership at the shared station.
    5. The rest of the map: Gurgaon opened in 2013, Chennai in 2015, Hyderabad, Kochi and Lucknow in 2017, Ahmedabad and Nagpur in 2019, Noida in 2019, Kanpur in 2021, Pune in 2022, Navi Mumbai in 2023, Agra in 2024, and Bhopal, Indore and Patna in 2025.

    Why does every city want a Metro?

    1. Density of unserved demand: The Greater Noida West association puts around 10 lakh residents and at least 80 societies in the area it says has no rapid transit.
    2. A visible proof of development: Local administrations and politicians want a Metro network in their constituency to demonstrate development, in the assessment of a rail and Metro consultant and former country head of Bombardier Transportation India.
    3. It has entered the manifesto: In five of the last six state elections, in West Bengal, Tamil Nadu, Kerala, Assam, Bihar and Delhi, at least one major party promised Metro projects, their expansion, or fare concessions.
    4. Party specific claims: The Dravida Munnetra Kazhagam (DMK) claimed credit for bringing Metro Rail service to Chennai. The Bharatiya Janata Party (BJP) in Bihar promised Metro trains in Muzaffarpur, Gaya, Bhagalpur and Darbhanga.

    Why does ridership fall so far short of projection?

    1. The systemic gap: Most Metro systems are meeting just 25 per cent to 35 per cent of their projected ridership, in a 2023 analysis by professors at the Indian Institute of Technology Delhi. Delhi at 47 per cent and Kolkata at 38 per cent fared relatively better.
    2. Bengaluru: Namma Metro was projected to carry 18.54 lakh passengers a day by 2020-21, as recorded by the Standing Committee on Housing and Urban Affairs in a 2022 report, and carries around 10 lakh in 2026.
    3. Kochi: The 28 km system should have reached 5.39 lakh daily riders by now under its DPR and averages around a lakh, with the projection since revised to 1.5 lakh a day, a target the operator hopes to meet in the next 10 months.
    4. Jaipur: Average daily ridership was 51,000 in the inaugural month of June 2015 and stood at 53,000 in June 2026, and the Union Cabinet approved a second phase in April for ₹13,037 crore.
    5. Nagpur: A 2022 Comptroller and Auditor General report found the New Airport station averaged 47 passengers a day over 18 months from the start of commercial operation in March 2019, against 5,474 a day envisaged in the DPR.

    Why does the Metro not fit the way Indian cities actually travel?

    1. Trip length mismatch: Research at the Transportation Research and Injury Prevention Centre finds the Metro efficient only for commutes beyond 10 km. Most city commutes are shorter than 5 km, and even in Delhi only 15 per cent of trips exceed 10 km and 7 per cent exceed 20 km.
    2. What the short trip costs: For a short journey a passenger has to add the time taken to reach the station, the stops en route and the last mile at the other end, which other modes avoid.
    3. Alignments miss the destinations: The Ahmedabad Metro does not serve SG Highway, the commercial hub holding the city’s offices and malls, nor the university area.
    4. Last mile decides the mode: A commuter with neither home nor office near a station finds public transport more expensive than a personal scooter or a hired cab.

    What in the city’s own design keeps people out of the Metro?

    1. Driving is not priced: Low or non existent parking charges make private vehicle use cheaper than it should be, and poor footpaths make the walk to a station unattractive.
    2. Feeder networks are not built: Last mile connections and integration across modes rarely materialise once a line opens, in the assessment of a Metro consultant, so a passenger reaches the station on his own or not at all.
    3. The city is not shaped to feed the line: The Mumbai Metro struggles to perform because the city was not planned in a way that channels trips into it, in the assessment of a transportation researcher at the Indian Institute of Management Ahmedabad.

    Why are fares high, and who does that exclude?

    1. Fares follow the viability test: Metros are obliged to keep fares high mainly to make both ends meet, a consequence the first Managing Director of DMRC attributes to the emphasis the 2017 policy places on financial viability.
    2. Who is priced out: High fares keep out a section of the population. That section turns to less dependable but cheaper public transport.
    3. The pricing only works on some trips: A Lucknow resident finds the 23 km city Metro worth ₹70 for an airport trip against ₹400 by auto, and uses an auto or two wheeler for every daily commute.

    What do other countries’ networks show about where India stands?

    1. Absolute scale: India at 1,100 km is set to overtake the 1,400 km subway system of the United States, and remains far behind China’s 10,000 km network.
    2. Financing and operating culture: The Delhi Metro was funded by the Japan International Cooperation Agency through flexible loans. It adopted a Japanese operating ethic centred on punctuality and queue discipline, giving Indian cities a template for dignified urban transit.
    3. When to start planning: The developed country model is to begin planning a Metro when a city’s population crosses 10 lakh and to have the system running by the time it reaches 20 lakh, on which basis the Metros in Patna, Jaipur, Bhopal and Lucknow are justified.
    4. Networks are built over generations: Tokyo, Hong Kong and Paris were not built in a day, so a large infrastructure investment has to begin well ahead of the demand it will eventually serve.
    5. Optimism is not an Indian trait: Large infrastructure projects globally overestimate initial projections and underestimate costs, and the shortfall is routinely overlooked on the ground of greater public good.

    Who decides whether a city needs a Metro?

    1. The decision precedes the study: The process typically begins with a state government deciding it wants a Metro, an idea that crystallises quickly and often before any formal study is done.
    2. The assessor is the beneficiary: State governments create a Metro authority and then ask that same body, which stands to run the project, to assess whether the city should build a Metro at all.
    3. What that produced in Jaipur: A 2017 Comptroller and Auditor General report found the city, with a population of 2.3 million, was not eligible for a metro rail project, and concluded that defective planning and hasty decision making introduced a financially unviable Metro system in Jaipur.
    4. Accountability is thin: Queries to the Metro systems in Delhi, Lucknow, Ahmedabad, Hyderabad, Bengaluru, Nagpur, Jaipur and Chennai went unanswered.

    Is the Metro over built, or is it under fed?

    1. For some riders it is the only option: A 21 year old hospital intern living in a central Delhi slum reaches work 17 km away in Noida in 45 minutes by Metro, against a 6 am start at a bus stop to arrive at 9 am, and returns after 9 pm because the Metro feels safe.
    2. The cost of waiting is higher: It is easier and cheaper to build a Metro in a smaller city before it grows and congests, and cities that do not start now will face the situation their larger counterparts already face.
    3. The objection is to the trade off, not the mode: The problem is not that governments promote the Metro but that they do so at the cost of other public transport, so a city must still depend on a reliable road based system alongside it.
    4. The official defence: Ridership projections account for a city’s Master Plan and its future development potential, ridership is significantly influenced by network density and extent, and ridership on many DMRC lines has exceeded the projections made in their DPRs.

    Challenges to metro rail expansion in India

    1. Debt service migrates to the state budget: A corporation borrows against ridership that does not arrive, and repayment then falls on the exchequer. Eg. Kochi Metro Rail has run operating losses since 2017 and depends on continuing state support. Fix. Fund a defined share of operations from a dedicated urban transport levy on fuel and parking rather than from the farebox alone.
    2. No unified metropolitan transport authority: Bus, metro, suburban rail and para transit run as separate agencies with separate fares and no common timetable. Eg. Delhi’s Metro, cluster buses and Delhi Transport Corporation services operated for years without a single ticket. Fix. Constitute statutory Unified Metropolitan Transport Authorities with fare setting and route rationalisation powers, as the National Urban Transport Policy, 2006 envisaged.
    3. The land value the line creates is not captured: Property owners along a corridor capture the price rise that public investment produced. Eg. Land values near Delhi Metro corridors rose sharply with no betterment levy accruing to the operator. Fix. Levy a betterment charge along corridors and grant development rights over station land to the metro corporation.
    4. Fare revision is politically blocked: Costs rise annually and fares are revised only when a government is willing to absorb the reaction. Eg. Delhi Metro fares went unrevised for years after the 2017 revision despite rising energy and staff costs. Fix. Make revision automatic through an indexed formula operated by a statutory Fare Fixation Committee.
    5. Signalling and rolling stock depend on a few suppliers: Core train control technology is supplied by a small set of foreign vendors, which raises cost and lengthens delivery. Eg. Communications based train control systems on Indian metros are supplied largely by three global vendors. Fix. Use the domestic content requirement in metro procurement to qualify Indian signalling suppliers through a guaranteed order pipeline.

    Conclusion

    India is adding metro rail faster than it is adding the ridership, fares and feeder transport that would make the network work, because the demand being satisfied is political and territorial rather than a measured transport demand. Nothing in the record suggests the mode is wrong for the corridors that genuinely carry the volume, and the record does show that the appraisal deciding which corridors those are is conducted by the body that stands to build them. The unresolved question is whether appraisal will be separated from execution, and whether bus and road based transport will be funded alongside the Metro rather than after it.

    “[2014, GS3, 12.5 marks] National Urban Transport Policy emphasises on ‘moving people’ instead of ‘moving vehicles’. Discuss critically the success of the various strategies of the Government in this regard.”

  • Panel to review nuclear liability caps every 5 years

    Why in the News

    Draft rules released by the Department of Atomic Energy on 14 August 2026 require an expert group to review the graded caps on nuclear operators’ civil liability once every five years. The review reaches only the operator’s cap, and leaves untouched the removal of the supplier’s statutory liability that is now the subject of a challenge in the Supreme Court.

    What is the Sustainable Harnessing and Advancing Nuclear Energy for Transitioning India (SHANTI) Act, 2025?

    1. About: The SHANTI Act, 2025 replaces both the Atomic Energy Act, 1962 and the Civil Liability for Nuclear Damage Act, 2010 (CLNDA) in a single unified statute, and is the first comprehensive overhaul of India’s nuclear power regime since independence.
    2. What it opens: The Act allows private entities to own and operate nuclear power plants for the first time, covering construction, transport, storage, import, export and handling of nuclear material, with mandatory authorisation from the Atomic Energy Regulatory Board for every activity.
    3. What it retains for the State: The government keeps an exclusive monopoly over enrichment, isotope separation, spent fuel reprocessing and radioactive waste management, so the fuel cycle remains entirely in the public sector.
    4. What it changed on liability: The Act’s Second Schedule introduced graded liability caps based on the size of a nuclear installation, replacing the earlier flat cap of Rs 1,500 crore under the CLNDA.

    What is an operator’s right of recourse?

    1. About: A right of recourse is the operator’s ability, after paying compensation for nuclear damage, to recover that amount from another party responsible for the incident.
    2. Why it is contested: The scope of this right decides whether the financial consequence of a defective component rests with the plant operator or travels back to the equipment supplier.

    What does Rule 78 of the draft rules provide?

    1. A standing review, not an occasional one: Rule 78 requires the Central government to constitute a group of experts to review the maximum limits of the operator’s civil liability for nuclear damage once every five years.
    2. Composition of the expert group: The group draws from nuclear science and engineering, actuarial science, insurance and law, together with public-interest representatives.
    3. What it can recommend: The group may propose amendments to the Second Schedule of the Act, which is where the graded caps sit.
    4. How this differs from the earlier law: Section 6 of the now-repealed CLNDA also allowed the Centre to periodically review the operator’s liability and notify a higher amount. The draft rules add a defined time period within which that review must happen.

    What are the graded liability caps under the Second Schedule?

    1. Above 3,600 Megawatt-electric (MWe): Operators of reactors above 3,600 MWe face a maximum liability of Rs 3,000 crore. MWe measures the electrical output of a reactor as distinct from its thermal output.
    2. 1,500 MWe to 3,600 MWe: Operators in this band face a cap of Rs 1,500 crore.
    3. 750 MWe to 1,500 MWe: The cap falls to Rs 750 crore.
    4. 150 MWe to 750 MWe: The cap falls to Rs 300 crore.
    5. Up to 150 MWe and other facilities: For reactors up to 150 MWe, for fuel-cycle facilities other than spent-fuel reprocessing plants, and for the transportation of nuclear material, liability is capped at Rs 100 crore.

    How has the operator’s right of recourse against suppliers changed?

    1. The three grounds under the old law: Section 17 of the CLNDA gave the operator a right of recourse where the right was expressly provided for in a written contract, where the incident resulted from an act of the supplier or the supplier’s employee including supply of equipment or material with patent or latent defects or sub-standard services, and where the incident resulted from an act or omission of an individual done with intent to cause nuclear damage.
    2. What survives: The new law retains the contractual ground and the intentional damage ground.
    3. What has been dropped: The supplier defect ground has been omitted, and it was the provision that exposed nuclear equipment vendors to long-term and uncertain liability risk in the event of an accident.
    4. What replaces it: Operators may now seek recourse from suppliers only through what they negotiate into a contract, which moves the question from statute to bargaining power.
    5. What it unblocks: Removing the statutory supplier exposure directly addresses the objection that kept foreign vendors out of Indian projects for over a decade.

    Why is the liability framework being challenged in the Supreme Court?

    1. The grounds pleaded: A petition challenges the Act for allowing private sector and foreign companies to operate nuclear power plants in India, for capping the liability of these operators at what it calls an absurdly low level, and for exempting the supplier from any liability, in violation of the Constitution.
    2. The accountability objection: Opening the sector to private operators while capping their exposure shifts residual risk from the operator to the exchequer and ultimately to victims.
    3. The five-yearly review does not answer it: Rule 78 allows the operator’s cap to be revised upward over time. It creates no mechanism to restore a supplier’s statutory liability, which the Act has removed from the framework entirely.
    4. The competing objective: Liability certainty is the precondition foreign vendors set for entering Indian projects, so the same provision that draws the petition is the one that makes the capacity expansion arithmetic feasible.

    What challenges does India’s civil nuclear liability framework face?

    1. A cap fixed in nominal terms erodes with inflation: A rupee figure written into a Schedule loses real value between revisions, so the five-year cycle sets the pace at which protection decays. Eg. The flat cap under the Civil Liability for Nuclear Damage Act, 2010 stood unrevised from 2010 until the SHANTI Act, 2025 replaced it with graded caps.
    2. Caps far below the actual cost of a severe accident: Graded caps measured in thousands of crores do not approach the cost of a major release. Eg. Cleanup and compensation costs after the 2011 Fukushima accident in Japan ran to tens of trillions of yen, orders of magnitude above any cap in the Second Schedule.
    3. Thin domestic insurance capacity for nuclear risk: Operators must place cover for the capped amount in a market with few underwriters willing to carry nuclear exposure. Eg. The India Nuclear Insurance Pool was created in 2015 precisely because individual insurers would not write the risk alone.
    4. Contractual recourse depends on bargaining power: With the statutory supplier ground removed, a smaller operator negotiating with a global vendor has little leverage to secure recourse in the contract. Eg. Jaitapur negotiations with the French vendor stalled for years over tariff and liability terms even while the statutory provision was in force.
    5. Regulatory independence still being built out: The Atomic Energy Regulatory Board has only now received statutory authority, having previously reported to the Department of Atomic Energy it was meant to regulate. Eg. The SHANTI Act, 2025 grants the Board statutory status for the first time and places its expenditure under the Comptroller and Auditor General.
    6. Claims machinery untested at scale: A dedicated claims commission exists on paper without a demonstrated record of settling mass claims quickly. Eg. The Act establishes a Nuclear Damage Claims Commission with appeals to the Electricity Appellate Tribunal, neither of which has adjudicated a nuclear damage claim.
    7. Public acceptance and siting resistance: Liability caps read as a transfer of risk to communities near installations, which hardens local opposition to siting. Eg. Sustained local protest at Kudankulam in Tamil Nadu delayed commissioning of the first units for years.

    Conclusion

    The five-yearly expert review converts a static Schedule of liability caps into a periodically revisable one, which is a real improvement on a flat figure left unrevised for fifteen years. It does not address the change that drew the litigation, since the supplier’s statutory exposure has been removed rather than capped, and no review clause can restore it. The measure currently stands at the draft rules stage, and the source states no date for the close of the comment window or for notification of the final rules, with the constitutional challenge to the Act pending before the Supreme Court.

    “[2018, GS3, 15] With growing energy needs should India keep on expanding its nuclear energy programme? Discuss the facts and fears associated with nuclear energy.”

  • Transmission Constraints Emerge as the Binding Limit on India’s Renewable Expansion

    Why in the News

    Insufficient transmission lines have emerged as a major obstacle to India’s renewable energy expansion, with many solar projects being curtailed during daylight hours, a rating agency assessment released on 19 August 2026 found. The constraint has shifted the binding limit on India’s energy transition from how fast capacity can be built to how much of it the grid can actually carry, and new project bidding has collapsed in response.

    What is curtailment of renewable power?

    1. Forced reduction of output: Curtailment occurs when a power generator is forced to reduce or stop producing electricity because of oversupply and grid congestion, even though the plant is capable of generating.
    2. Why solar is hit hardest: Solar output peaks in the middle of the day, when several projects on the same corridor feed in simultaneously and demand is not correspondingly high, so the surplus cannot be evacuated.
    3. What it costs the generator: A curtailed unit is generation permanently lost, since sunlight cannot be stored without additional storage capacity, and the fixed cost of the asset continues to accrue against a smaller output.
    4. Scale of the problem: Around 37% of renewable energy capacity at substations affected by curtailment in the northern, western and southern regions operates under short term access arrangements, and this capacity faces 30% to 50% curtailment during the day.

    What is Temporary General Network Access?

    1. Short term use of spare grid capacity: Temporary General Network Access (T-GNA) is a short term arrangement that allows a renewable energy project to use available capacity on the inter-State transmission system, typically for periods ranging from a single time block to about 11 months.
    2. Why it is precarious: T-GNA gives no firm entitlement to evacuate power, so projects operating under it are particularly vulnerable to curtailment, which raises their operational costs and, on prolonged use, reduces the supplier’s revenues.

    What is the inter-State transmission system?

    1. The national transmission backbone: The inter-State transmission system is the network of high voltage lines and substations that carries power across State boundaries, planned centrally and operated as a single national grid, on which access rights are allotted separately from generation approvals.

    What is a Power Purchase Agreement?

    1. The contract that makes a project bankable: A Power Purchase Agreement (PPA) is the long term contract under which a distribution company or intermediary agrees to buy a defined quantity of power from a generator at an agreed tariff, and without a signed PPA a project has no assured revenue stream against which lenders will disburse.

    What is firm and dispatchable renewable energy?

    1. Renewable power with an assured supply obligation: Firm and dispatchable renewable energy (FDRE) is renewable generation contracted with an obligation to supply a specified quantum during specified hours, achieved by combining solar, wind and storage, so that the buyer receives a guaranteed profile rather than whatever the weather delivers.

    What is round the clock renewable power?

    1. Renewable supply across all 24 hours: Round the clock (RTC) power is a contracting structure in which the developer commits to supply renewable energy across every hour of the day at a specified availability, again by combining complementary sources with storage.

    How severe is the curtailment, region by region?

    1. The affected regions: Curtailment at substations has been recorded in the northern, western and southern regions, the three regions carrying the bulk of India’s solar and wind capacity.
    2. Share on temporary access: Around 37% of renewable capacity at affected substations across these three regions operates under T-GNA.
    3. The daily loss: Capacity operating under T-GNA faces 30% to 50% curtailment during daylight hours.
    4. Western region: About 55% of the affected capacity in western India was under T-GNA, and peak curtailment reached 8,617 MW as of 6 August 2026.
    5. Northern region: The corresponding peak curtailment figure for the northern region was 5,573 MW.
    6. What the concentration means: The western region, which hosts the largest solar and wind clusters, is also the region most dependent on temporary access, so the two vulnerabilities compound rather than offset.

    Why has new capacity bidding collapsed even as construction continues?

    1. Construction pipeline remains large: More than 150 GW of renewable projects were under construction as of 30 June 2026.
    2. Awards have fallen sharply: After 40.6 GW was awarded in 2024-25, awards fell to 14.7 GW in 2025-26 and stood at only 4.7 GW through 10 August 2026.
    3. Contracts awarded but not signed: Between 40 GW and 45 GW of capacity with bids already awarded remained without signed PPAs as of April 2026.
    4. Delays in firming PPAs: Delays in converting awarded bids into signed PPAs are identified as an impediment independent of the transmission constraint.
    5. Land acquisition: Land acquisition for both generation sites and transmission corridors continues to stall projects.
    6. Distribution company finances: The financial position of distribution companies limits their willingness to sign long term purchase obligations at all, since a new PPA adds a fixed payment liability to a stressed balance sheet.
    7. The bidding mix is changing: New bidding is shifting toward firm and dispatchable renewable energy and round the clock power, which require storage and therefore carry a higher tariff than plain solar.

    Is the binding constraint on India’s energy transition generation capacity or grid capacity?

    1. The generation side is not the problem: More than 150 GW is under construction and renewable energy including large hydro is projected to account for more than 35% of electricity generation by 2029-30, against 22% in 2024-25.
    2. The evacuation side is: Capacity is being commissioned faster than transmission corridors are being built, which is why up to half of the output of projects on temporary access is being discarded during the hours it is generated.
    3. The market has already priced the constraint: New awards fell from 40.6 GW to 4.7 GW in eighteen months, which is the developer response to a corridor that cannot carry what is already built.
    4. Storage is the second missing input: Timely execution of intra-State and inter-State transmission infrastructure, along with greater storage capacity, is identified as critical to sustaining renewable additions, because a line that is congested at noon is idle at night.
    5. Why this reframes the target: A target expressed in installed capacity measures what has been built, while a target expressed in share of generation measures what actually reaches consumers, and curtailment is precisely the gap between the two.

    How is transmission and renewable infrastructure financed in India?

    Source: Backgrounder, Infrastructure Financing.docx

    1. Why bank lending failed: Commercial banks funded 25 to 30 year infrastructure assets with one to three year deposits, and this asset liability mismatch produced stressed assets crossing Rs 10 lakh crore in Indian banking by 2017.
    2. National Bank for Financing Infrastructure and Development: Established in 2021 under a dedicated Act of Parliament as India’s first dedicated infrastructure development finance institution, providing non recourse long term financing with 20 to 30 year tenors that match infrastructure asset life.
    3. Its scale: As of December 2025 it had sanctioned approximately Rs 3.03 lakh crore and disbursed approximately Rs 1.09 lakh crore.
    4. Partial Credit Enhancement: It partially guarantees bonds issued by infrastructure companies and special purpose vehicles, upgrading their credit rating from BBB to AA or AAA so that insurance companies and pension funds can participate, with the first such facility sanctioned in February 2026.
    5. Sector specific development finance institutions: REC and PFC finance power generation, transmission and distribution by raising long term bonds and lending to State electricity boards and private power companies.
    6. POWERGRID InvIT: The first Infrastructure Investment Trust in the power sector, set up in 2020, with proceeds channelled into new and under construction transmission projects.
    7. How an InvIT recycles capital: The sponsor transfers only the right to collect revenues for a defined concession period and receives upfront capital which it reinvests in new projects, while ownership is never transferred and the asset reverts at the end of the concession.
    8. The SEBI safeguard: SEBI requires a minimum of 80% of InvIT assets to be in completed operational projects, which protects investors from construction risk, and InvITs may raise debt up to 49% of asset value.
    9. Infrastructure Risk Guarantee Fund: Announced in the 2026-27 Budget, it provides partial guarantees to lenders financing infrastructure projects, covering a portion of the loss on default so that lenders extend credit where they previously refused, while the partial cover preserves due diligence incentives.
    10. Sovereign green bonds: Issued by the Government of India since 2022-23 with proceeds ring fenced for renewable energy, clean transport and sustainable water management, establishing a sovereign benchmark for long term green paper.
    11. The recycling logic: The architecture is designed so that the government builds, the asset stabilises and generates revenue, the asset is monetised through an InvIT, and the capital returns to fund the next tranche of the National Infrastructure Pipeline without a fresh budget allocation each cycle.
    12. Monetisation targets: The National Monetisation Pipeline 2.0, announced in February 2026, targets Rs 16.72 lakh crore including private sector investment of Rs 5.8 lakh crore over 2025-26 to 2029-30, nearly three times the first pipeline’s target.

    Challenges to India’s Renewable Energy Expansion

    1. Transmission build lags generation build: A solar park can be commissioned in about a year while a high voltage corridor takes several years, so the two cannot be commissioned in step. e.g. peak curtailment in western India reached 8,617 MW as of 6 August 2026 on capacity that was already generating.
    2. Temporary access gives no firm evacuation right: Projects on T-GNA can be curtailed at the system operator’s discretion, which makes their revenue unpredictable and their debt harder to service. e.g. around 37% of affected capacity across three regions runs on T-GNA and faces 30% to 50% daytime curtailment.
    3. Storage capacity is inadequate to absorb the midday surplus: Without batteries or pumped hydro the same corridor is congested at noon and underused at night. e.g. the shift in new bidding toward firm and dispatchable and round the clock contracts is itself an admission that plain solar without storage no longer clears.
    4. Distribution company finances limit offtake: Loss making distribution utilities avoid signing new long term purchase obligations irrespective of tariff. e.g. 40 GW to 45 GW of awarded capacity remained without signed PPAs as of April 2026.
    5. Right of way and land acquisition for transmission corridors: Transmission lines cross many districts and require sustained land and forest clearances along the whole route. e.g. land acquisition is named alongside transmission constraints as an independent impediment to project completion.
    6. Geographic concentration of resource: Solar and wind resources are concentrated in a few States while demand centres lie elsewhere, so the transition is dependent on long distance evacuation. e.g. the western and northern regions together account for the two largest curtailment figures recorded.
    7. Tariff pressure from cheap early bids: Projects awarded at very low tariffs in earlier competitive rounds have thin margins that curtailment erases entirely. e.g. the collapse of awards from 40.6 GW in 2024-25 to 4.7 GW through August 2026 shows developers withdrawing rather than bidding lower.
    8. Grid stability with high variable renewable share: A grid carrying more than 35% renewable generation needs inertia, frequency response and balancing reserves that thermal plants currently supply. e.g. must run thermal capacity has to be retained and paid for even as it operates at low plant load factors.
    9. Module and cell supply chain dependence: Domestic content requirements raise capital costs while imported modules expose projects to trade policy shocks. e.g. changes in duty on imported solar cells and modules have repeatedly reset project economics after bids were submitted.
    10. Delayed payments to generators: Payment delays by distribution utilities strain developer working capital independently of curtailment. e.g. the late payment surcharge rules had to be framed specifically to enforce a payment discipline that contracts alone did not achieve.

    Conclusion

    India’s renewable programme has moved past the point where generation capacity is the constraint, and the evidence for that is a 150 GW construction pipeline coexisting with up to 50% daytime curtailment on capacity that is already running. The market has responded not by building more but by bidding less, with awards falling from 40.6 GW to 4.7 GW in eighteen months, and by shifting toward firm and dispatchable contracts that price the constraint into the tariff. Whether renewable energy reaches more than 35% of generation by 2029-30 now depends on the execution of intra-State and inter-State transmission lines and on storage capacity, not on the pace of solar commissioning.

    “[2022, GS3, 15 marks] Do you think India will meet 50 percent of its energy needs from renewable energy by 2030 ? Justify your answer. How will the shift of subsidies from fossil fuels to renewables help achieve the above objective? Explain.”

  • New PNG Connections Get a Gas Boost: Extra 200 SCM Allocation

    Why in the News

    From 1 September, eligible City Gas Distributors (CGDs) will receive an additional 200 Standard Cubic Metres (SCM) of cheaper Administered Price Mechanism (APM) gas for every new billed domestic Piped Natural Gas (PNG) connection.

    APM Natural Gas

    • Administered Price Mechanism (APM): Domestic gas from nomination fields of national oil companies, priced by the government.
    • Generally cheaper than imported Liquefied Natural Gas (LNG).
    • Piped Natural Gas (PNG) and Compressed Natural Gas (CNG) receive priority allocation.
    • Price is linked to the Indian crude basket, with a floor and ceiling.

    City Gas Distribution

    • City Gas Distribution (CGD): Pipeline network supplying gas to households, industries, commercial users and vehicles.
    • Geographical areas are awarded through competitive bidding by the Petroleum and Natural Gas Regulatory Board (PNGRB).

    Piped Natural Gas

    • Piped Natural Gas (PNG): Natural gas supplied directly through pipelines and metered like a utility.
    • Provides an alternative to Liquefied Petroleum Gas (LPG) cylinders for households.

    New Incentive

    • 200 SCM of APM gas for every incremental billed domestic PNG connection.
    • Effective 1 September.
    • Aims to reduce LNG sourcing costs and accelerate household PNG adoption.
    • Benefit is linked to actual billed connections, not merely network expansion.

    Key Challenges

    • Right-of-way and road-cutting permissions
    • High household connection costs
    • Competition from subsidised LPG
    • Limited domestic APM gas availability
    • Volatile imported LNG prices
    • Natural gas remains outside Goods and Services Tax (GST)
    • Low viability in remote and low-demand areas

    Foundational Context: The Natural Gas Sector in India

    1. Share in the energy mix: Natural gas accounts for roughly 6 percent of India’s primary energy mix, against a stated national target of raising it to 15 percent by 2030.
    2. Import dependence: India imports about half of its natural gas requirement in the form of liquefied natural gas, delivered through regasification terminals on the west and east coasts.
    3. Two price regimes: Domestically produced gas from nomination fields is sold at the administered price, while gas from deepwater, ultra deepwater and high pressure high temperature fields and imported gas are sold at market linked prices.
    4. Allocation priority: Domestic piped natural gas for households and compressed natural gas for transport hold first priority in the allocation of administered price gas.
    5. Network build out: Successive bidding rounds by the sector regulator have authorised city gas distribution networks covering the overwhelming majority of India’s population across more than 300 geographical areas.
    6. National gas grid: Trunk transmission pipelines are being extended into the eastern and north eastern regions to create a single national gas grid with a unified tariff.

    Statutory Framework Governing the Gas Sector

    1. Petroleum and Natural Gas Regulatory Board Act, 2006: Establishes the sector regulator and gives it authority over downstream refining, processing, storage, transportation, distribution and marketing of petroleum products and natural gas.
    2. Section 16 of the Petroleum and Natural Gas Regulatory Board Act, 2006: Provides for authorisation of entities to lay, build, operate or expand city gas distribution networks.
    3. Section 32 of the Petroleum and Natural Gas Regulatory Board Act, 2006: Provides that appeals against the regulator’s decisions lie to the Appellate Tribunal for Electricity, with a statutory disposal timeline of 90 days.
    4. Oilfields (Regulation and Development) Act, 1948: Governs the regulation of oilfields and the grant of mining leases for petroleum and natural gas.
    5. Petroleum and Natural Gas Rules, 1959: Prescribe the terms for grant of exploration licences and mining leases for petroleum and natural gas.
    6. Petroleum Act, 1934 and the Petroleum Rules, 2002: Govern the import, transport, storage and production of petroleum and the safety conditions attached to them.

    Back2Basics: Petroleum and Natural Gas Regulatory Board (PNGRB)

    1. Governing Act: The Petroleum and Natural Gas Regulatory Board Act, 2006.
    2. Established: Constituted in 2007 under that Act, functioning under the Ministry of Petroleum and Natural Gas.
    3. Jurisdiction: Regulates downstream activities only, covering refining, processing, storage, transportation, distribution, marketing and sale of petroleum products and natural gas.
    4. Exclusion from its remit: It does not regulate upstream exploration or production, which falls to the Directorate General of Hydrocarbons and the Ministry directly.
    5. Core functions: Protecting consumer interest, ensuring competitive markets for gas, authorising city gas distribution networks and pipelines, and fixing transportation tariffs.
    6. First instance adjudication: The Board is the first instance forum for disputes on tariffs, access and authorisation.
    7. Appellate forum: Appeals lie to the Appellate Tribunal for Electricity (APTEL) under Section 32 of the Act.

    Government Initiatives

    1. City Gas Distribution bidding rounds: Successive rounds conducted by the regulator to authorise distributors for new geographical areas, with minimum work programme commitments on domestic connections, compressed natural gas stations and pipeline length.
    2. Pradhan Mantri Urja Ganga: The Jagdishpur to Haldia and Bokaro to Dhamra pipeline project extending the gas grid to eastern India.
    3. North East Gas Grid: A capital grant supported trunk pipeline network connecting the eight north eastern States to the national gas grid.
    4. Sustainable Alternative Towards Affordable Transportation (SATAT): Promotes compressed biogas production and its sale through the existing fuel retail network as a substitute for compressed natural gas.
    5. Unified tariff for natural gas pipelines: A zonal tariff structure that lowers the delivered cost of gas for consumers located far from the source, aiding the eastern and southern build out.
    6. Hydrocarbon Exploration and Licensing Policy and Open Acreage Licensing Policy: Provide a uniform licence for all hydrocarbons and allow bidders to carve out their own exploration blocks, aimed at raising domestic production.

    Key Facts about India’s Gas Sector

    1. Nodal ministry: The Ministry of Petroleum and Natural Gas.
    2. Regulator: The Petroleum and Natural Gas Regulatory Board, constituted in 2007.
    3. Upstream technical arm: The Directorate General of Hydrocarbons, which oversees exploration and production.
    4. Administered price basis: Since April 2023 the administered price has been set at a fixed percentage of the Indian crude basket price, subject to a floor and a ceiling, following the recommendations of the Kirit Parikh Committee.
    5. Gas in the primary energy mix: About 6 percent, against the target of 15 percent by 2030.
    6. Compressed natural gas and domestic piped gas: Both receive 100 percent of their requirement from administered price gas under the priority allocation policy.

    “[2019] Consider the following statements:
    1. Petroleum and Natural Gas Regulatory Board (PNGRB) is the first regulatory body set up by the Government of India.
    2. One of the tasks of PNGRB is to ensure competitive markets for gas.
    3. Appeals against the decisions of PNGRB go before the Appellate Tribunals for Electricity.
    Which of the statements given above are correct?
    (a) 1 and 2 only
    (b) 2 and 3 only
    (c) 1 and 3 only
    (d) Neither 1 nor 2

  • Vizhinjam International Seaport begins full-scale EXIM operations

    Why in the News

    Kerala’s Vizhinjam International Seaport began full scale export and import operations, moving India’s first dedicated deepwater transshipment terminal from handling mother ship calls to regular cargo work. The shift tests whether a domestic deepwater port can pull back the transshipment cargo that Colombo, Singapore and Salalah have historically handled for India.

    What is the Vizhinjam International Seaport?

    1. About: Vizhinjam is India’s first dedicated deepwater container transshipment port, located near Thiruvananthapuram on the southern tip of Kerala.
    2. Ownership model: It is developed on the landlord port model, with the Government of Kerala owning the asset and a private concessionaire building and operating the terminal.
    3. Concession: The concession agreement was signed in August 2015 for a period of 40 years, with provision for extension.
    4. Status in law: It is a non major port under the Government of Kerala, unlike the twelve major ports administered by the Union government.
    5. Automation: It is India’s first port to use a fully automated container handling system with remotely operated ship to shore cranes.
    6. Operational milestones: The first mother ship called in July 2024, commercial operations began in December 2024, and the port was formally dedicated in May 2025.

    What is transshipment?

    1. About: Transshipment is the transfer of containers from one vessel to another at an intermediate port before they reach their final destination.
    2. Why it exists: Very large mainline vessels call only at a few deep draft hubs, and smaller feeder vessels then distribute the boxes to shallower regional ports.
    3. The commercial value: The hub port earns handling charges twice on the same container, once on discharge from the mother vessel and once on loading to the feeder.

    What is natural draft and why does it matter?

    1. About: Draft is the depth of water a vessel needs beneath its keel, and natural draft is the depth a harbour has without dredging.
    2. Vizhinjam’s advantage: The site has a natural depth of about 20 metres close to the shore, deep enough to take the largest container vessels in service.
    3. The cost effect: A naturally deep harbour avoids the recurring capital and maintenance dredging bill that shallow Indian ports carry every year.
    4. The sedimentation factor: The site has minimal littoral drift, so the channel does not silt up at the rate seen at river mouth ports.

    What is Viability Gap Funding?

    1. About: Viability Gap Funding is a one time or deferred grant given by the government to a public private partnership project that is economically justified but not commercially viable on its own.
    2. Use here: Central and State assistance under this route covered part of the capital cost of the first phase of the port.

    Why has India depended on foreign transshipment hubs?

    1. Scale of leakage: A large majority of India’s transshipment containers have historically been handled outside the country.
    2. The dominant hub: Colombo in Sri Lanka has handled the single largest share of India’s transshipped boxes, aided by its position on the same shipping lane.
    3. Other hubs: Singapore and Salalah in Oman handle much of the remainder, along with Port Klang in Malaysia.
    4. The reason: Indian ports lacked the natural draft and the crane capacity to receive the largest mainline vessels, so mother ships called at neighbouring hubs instead.
    5. The cost: Routing a container through a foreign hub adds an extra handling charge and transit time on every box, and the associated revenue leaves the country.
    6. The strategic exposure: Dependence on a foreign port for the movement of national trade is a vulnerability during a diplomatic or economic dispute.

    What makes the Vizhinjam site suitable for a hub?

    1. Proximity to the shipping lane: The port lies about 10 nautical miles from the international east and west shipping route linking the Suez Canal to the Strait of Malacca.
    2. Minimal deviation cost: A short deviation from the mainline route means a mother ship loses little time by calling, which is the decisive commercial factor for a hub.
    3. Deep water close to shore: The natural draft of about 20 metres is available near the coast, which shortens the approach channel.
    4. Low maintenance dredging: Limited sedimentation keeps the recurring dredging requirement low compared with other Indian container ports.
    5. Southern position: Its location at the southern tip of the peninsula makes it the natural first and last Indian call on the route.

    What does the move to full scale export and import operations add?

    1. From transshipment to trade: The port moves from handling mother ship calls and transfers to handling India’s own export and import containers.
    2. Direct connectivity for shippers: Exporters in Kerala and neighbouring States can load on a mainline vessel without an intermediate feeder leg through a foreign hub.
    3. Time and cost saving: Removing a feeder leg cuts transit days and one round of handling charges from the door to door cost.
    4. Revenue retention: Handling charges, customs revenue and ancillary services are retained domestically rather than paid to a foreign hub operator.
    5. Feeder network effect: Regular export and import volume gives the port a base load that makes it more attractive for shipping lines to add services.
    6. Economic linkage: Full operations activate customs, warehousing, logistics and bunkering activity in the port’s hinterland.

    Challenges to the Vizhinjam International Seaport

    1. Hinterland connectivity: A hub needs rail and road links to move export and import cargo inland at scale. e.g. the dedicated rail link and the road connectivity to the national highway network for Vizhinjam are still being completed.
    2. Competition from an established hub: Shipping lines change hub calls only when the switch is commercially compelling. e.g. Colombo has long established feeder networks, bunkering and repair services that a new port must match.
    3. Fisher community livelihood: Port construction alters the coastline and affects traditional fishing grounds. e.g. the Vizhinjam project faced sustained protests by the local fishing community over shoreline erosion and loss of fishing access.
    4. Coastal erosion and shoreline change: Breakwaters interrupt the natural movement of sand along the coast. e.g. erosion at nearby Kerala coastal settlements has been attributed by residents to the breakwater and has required protective works.
    5. Concentration risk in a single operator: Container handling capacity concentrated with one private group reduces competitive pressure on tariffs. e.g. a single group already operates a large share of India’s private container terminal capacity.
    6. Cyclone and monsoon exposure: The Arabian Sea coast faces intensifying cyclonic activity that halts port operations. e.g. Cyclone Ockhi in 2017 caused heavy loss of life among fishers off the Kerala and Tamil Nadu coast.
    7. Capacity ramp up risk: Later phases depend on demand materialising at the pace assumed in the concession. e.g. the full build capacity target depends on winning transshipment volume currently committed to competing hubs.

    Conclusion

    India has for decades paid a foreign hub to handle its own transshipment containers, and Vizhinjam is the first Indian facility with the natural draft and route position to change that. The port has now moved from the transshipment calls it began with in December 2024 to full scale export and import operations from 18 August 2026, which gives it a domestic cargo base alongside transfer volumes. The next milestone is the completion of the later development phases and the dedicated rail and road connectivity that will decide whether the hinterland can feed the quay.

    Ports and Maritime Sector in India

    1. About: India’s port system handles the overwhelming share of the country’s external trade, moving bulk, break bulk, liquid and containerised cargo.
    2. Trade dependence: Around 95 per cent of India’s trade by volume and about 70 per cent by value moves through sea ports.
    3. Port structure: India has 12 major ports administered by the Union government and around 200 notified non major ports under State governments.
    4. Coastline: India has a coastline of about 11,098 kilometres across nine coastal States and four Union Territories, with an exclusive economic zone of about 2.37 million square kilometres.
    5. Location advantage: The peninsula sits astride the east and west shipping lane connecting the Suez Canal to the Strait of Malacca, through which a large share of world trade passes.
    6. Structural weakness: Indian ports have historically lacked deep draft berths, so mainline vessels called at foreign hubs and Indian ports were served by feeders.
    7. Institutional structure: The Ministry of Ports, Shipping and Waterways administers the sector, with State Maritime Boards governing non major ports.

    Constitutional Framework Governing Ports

    1. Entry 27 of the Union List: Covers ports declared by or under law made by Parliament to be major ports, including their delimitation and the powers of port authorities there.
    2. Entry 25 of the Union List: Covers maritime shipping and navigation, and provision of education and training for the merchant marine.
    3. Entry 31 of the Concurrent List: Covers ports other than those declared to be major ports, the basis of State jurisdiction over ports such as Vizhinjam.
    4. Entry 32 of the Concurrent List: Covers shipping and navigation on inland waterways as regards mechanically propelled vessels.
    5. Article 297: Vests in the Union all lands, minerals and other things of value underlying the territorial waters, continental shelf and exclusive economic zone.
    6. Entry 41 of the Union List: Covers trade and commerce with foreign countries and import and export across customs frontiers.

    Laws and Rules Governing Ports and Shipping

    1. Indian Ports Act, 1908: The long standing statute governing port limits, port dues, pilotage and safety of shipping at ports.
    2. Indian Ports Act, 2025: Enacted to replace the 1908 statute, updating port administration, State Maritime Boards, pollution control and dispute resolution.
    3. Major Port Authorities Act, 2021: Replaced the Major Port Trusts Act, 1963 and gave the twelve major ports autonomy in tariff setting and land management through Port Authority Boards.
    4. Tariff autonomy: The Act removed tariff fixation from the Tariff Authority for Major Ports for new projects, allowing market based rates.
    5. Merchant Shipping Act, 1958: Governs registration of Indian vessels, seafarer welfare, safety and marine pollution obligations.
    6. Customs Act, 1962: Governs clearance of imported and exported goods and the designation of customs ports and bonded warehouses.
    7. Marine Aids to Navigation Act, 2021: Replaced the Lighthouse Act, 1927 and modernised the framework for navigational aids and vessel traffic services.
    8. Coastal Regulation Zone Notification, 2019: Issued under the Environment (Protection) Act, 1986, regulating construction and port development along the coast.
    9. Inland Vessels Act, 2021: Provides a uniform national regime for registration and safe operation of inland vessels, relevant to port hinterland movement by waterway.

    Back2Basics: Sagarmala Programme

    1. Administering ministry: Ministry of Ports, Shipping and Waterways.
    2. Launch year: Approved in 2015 as the flagship programme for port led development.
    3. Aim: To reduce the logistics cost of export and import and domestic cargo by using India’s coastline and inland waterways more intensively.
    4. The four pillars: Port modernisation and new port development, port connectivity enhancement, port linked industrialisation, and coastal community development.
    5. Targeted beneficiaries: Exporters and importers, coastal shipping operators, port linked industrial clusters and coastal communities including fishers.
    6. Design feature: Projects are implemented by ports, State governments, central ministries and special purpose vehicles, with the Sagarmala Development Company providing funding support.
    7. Coastal community component: Funds fishing harbours, fish landing centres and skill development for coastal populations.

    Government Initiatives in the Maritime Sector

    1. Maritime India Vision 2030: Sets out the ten year blueprint for port capacity, connectivity, shipbuilding and inland waterways.
    2. Maritime Amrit Kaal Vision 2047: Extends the roadmap to 2047 with targets for port capacity, transshipment share and green shipping.
    3. PM Gati Shakti National Master Plan: Integrates port, rail, road and waterway projects on a common geographic platform to remove last mile connectivity gaps.
    4. Harit Sagar Green Port Guidelines: Set targets for reducing carbon intensity at ports, including shore power and alternative fuel bunkering.
    5. Maritime Development Fund: Announced to provide long term low cost finance for shipbuilding, ship acquisition and port infrastructure.
    6. Shipbuilding Financial Assistance Policy: Provides assistance to Indian shipyards to compete with subsidised foreign shipbuilders.
    7. Cabotage relaxation: Allows foreign flagged vessels to carry transshipment containers between Indian ports, a measure intended to make Indian hub ports viable.
    8. Jalvahak Scheme and National Waterways development: Encourages cargo movement on inland waterways to reduce road congestion to and from ports.

    Key Facts about Vizhinjam and India’s Ports

    1. First of its kind: Vizhinjam is India’s first dedicated deepwater container transshipment port and its first semi automated container terminal.
    2. Location: Thiruvananthapuram district, Kerala, on the Arabian Sea coast near the southern tip of the Indian peninsula.
    3. Natural draft: About 20 metres close to shore, among the deepest at any Indian port.
    4. Distance from the shipping lane: About 10 nautical miles from the international east and west shipping route.
    5. Concession model: Landlord model public private partnership with the Government of Kerala, signed in 2015 for 40 years.
    6. Major ports: India’s twelve major ports include Deendayal (Kandla), Mumbai, Jawaharlal Nehru, Mormugao, New Mangalore, Cochin, Chennai, Kamarajar (Ennore), V.O. Chidambaranar (Tuticorin), Visakhapatnam, Paradip and Syama Prasad Mookerjee (Kolkata).
    7. Busiest container port: Jawaharlal Nehru Port in Maharashtra handles the largest container volume among Indian ports.
    8. Newest major port: Vadhavan in Maharashtra was approved as a deepwater major port to add mainline capacity on the west coast.

    Challenges in India’s Port and Maritime Sector

    1. Transshipment leakage: A large share of India’s container transshipment is still handled at foreign hubs. e.g. Colombo has historically handled the biggest single share of India’s transshipped boxes.
    2. Hinterland connectivity gaps: Rail and road links to ports lag behind quay side capacity. e.g. dedicated freight corridor connectivity reached some ports years after their capacity expansion was complete.
    3. Low draft at legacy ports: Older river and estuary ports cannot take the largest vessels without continuous dredging. e.g. Kolkata port requires sustained maintenance dredging on the Hooghly to keep its channel usable.
    4. Turnaround time and dwell time: Container dwell time at Indian ports remains higher than at competing hubs. e.g. Indian container dwell time has been benchmarked unfavourably against Singapore and Colombo in trade facilitation assessments.
    5. Small national fleet: Indian flagged tonnage carries only a small share of the country’s own trade, so freight payments go abroad. e.g. Indian ships carry a small fraction of India’s export and import cargo, with the rest on foreign flagged vessels.
    6. Weak shipbuilding base: India holds a marginal share of global shipbuilding orders. e.g. global shipbuilding is dominated by China, South Korea and Japan, which together hold the overwhelming majority of the order book.
    7. Coastal environment and livelihood conflict: Port expansion collides with fishing livelihoods and coastal ecology. e.g. the Vizhinjam project saw prolonged protests over erosion and loss of fishing grounds.
    8. Climate and disaster exposure: Ports are exposed to cyclones, storm surge and sea level rise. e.g. Cyclone Fani and Cyclone Amphan forced extended shutdowns at east coast ports.

    Way Forward

    1. Complete port connectivity projects on schedule: Finish the dedicated rail spur and highway links so hinterland cargo can reach the quay without road congestion.
    2. Consolidate transshipment volume: Use cabotage relaxation, competitive tariffs and customs facilitation to make an Indian hub call cheaper than a Colombo call.
    3. Invest in feeder shipping capacity: Build an Indian flagged feeder fleet so the distribution leg of transshipment is also domestically earned.
    4. Institutionalise coastal community compensation: Provide time bound rehabilitation, alternative livelihood and shoreline protection commitments as part of every port concession.
    5. Monitor shoreline change scientifically: Mandate independent long term shoreline and sediment monitoring around breakwaters, with published results.
    6. Diversify operators: Encourage more than one terminal operator across the national container network to keep tariffs competitive.
    7. Green the port: Deploy shore power, alternative fuel bunkering and electrified handling equipment in line with the green port guidelines.
    8. Digitise clearance: Extend single window clearance and port community systems to cut dwell time to the levels prevailing at competing hubs.

    Matching Previous Year Question

    “[2026] In what way(s) does the Vizhinjam International Seaport represent a structural shift in India’s maritime trade and logistics policy?
    1. By functioning exclusively as a domestic cargo hub to reduce reliance on coastal shipping and eliminate the need for foreign collaborations.
    2. By focusing primarily on passenger cruise tourism and heritage shipping to increase Kerala’s profile as a maritime heritage destination.
    3. By leveraging its natural deep draft and strategic location to reduce dependence on foreign trans-shipment ports, enhance revenue retention, and reposition India in regional maritime trade.
    Select the answer using the code given below:
    (a) 1 only
    (b) 1 and 2
    (c) 2 and 3
    (d) 3 only
    Answer: (d)”

  • CERC lets RE developers retain grid connectivity despite project delays

    Why in the News

    The Central Electricity Regulatory Commission (CERC), the central power sector regulator, replaced the automatic revocation of grid connectivity for delayed renewable energy projects with a compensation based mechanism. Developers who miss project milestones can now retain transmission access by paying a daily charge, which converts a binary penalty into a priced extension. At least 5.3 gigawatts (GW) of renewable capacity was facing revocation up to October for failure to achieve the commercial operation date.

    What is grid connectivity under the General Network Access Regulations?

    1. About: Grid connectivity is the regulatory right of a generating station to connect to and inject power into the inter State transmission system.
    2. Why it is scarce: Transmission corridors are built years in advance at public cost, and granting connectivity to one project blocks that corridor capacity for every other applicant.
    3. The milestone conditions: A developer holding connectivity must submit land ownership documents, achieve financial closure, and commission the project by its stated date.
    4. The earlier consequence: Failure on any of these three milestones led to automatic revocation of connectivity and forfeiture of the associated bank guarantees.
    5. Governing instrument: These milestones sit under the General Network Access Regulations, which govern access to the inter State transmission network.

    Who is the Central Transmission Utility of India Limited (CTUIL)?

    1. About: CTUIL is the central transmission utility, carved out of Power Grid Corporation of India Limited, which plans the inter State transmission system and grants connectivity and general network access.
    2. Role here: CTUIL issues the notices of revocation to developers who miss milestones, and its data records the capacity at risk.

    What is financial closure?

    1. About: Financial closure is the stage at which all financing agreements for a project are signed and the conditions precedent to the first drawdown of funds are satisfied.
    2. Why it is a milestone: A project without financial closure has no committed money to build with, so it is treated as unlikely to use the connectivity it holds.

    What is the commercial operation date?

    1. About: The commercial operation date is the date from which a generating unit is declared ready to supply power commercially after successful trial operation.
    2. Regulatory use: It is the point from which tariffs, transmission charges and contractual obligations of a project become operative.

    What are Monthly Transmission Charges under the Sharing Regulations, 2020?

    1. About: Monthly Transmission Charges are the pooled cost of the inter State transmission system, recovered from all users in proportion to their use.
    2. Governing instrument: The Sharing of Inter State Transmission Charges and Losses Regulations, 2020 set the formula by which this pooled cost is allocated among users.

    Why did the regulator have to intervene?

    1. Scale of the problem: CTUIL data showed at least 5.3 GW of renewable energy capacity was expected to face connectivity revocation up to October for failure to achieve the commercial operation date.
    2. Developers approached the Commission: Several developers who had received notices from CTUIL sought additional time to achieve the milestones.
    3. Stage of the affected projects: The Commission recorded that entities seeking time are at various stages of implementation, including some at an advanced stage.
    4. Case by case disposal: The Commission had already disposed of several such cases individually, granting additional time on payment of compensation.
    5. Need for uniformity: The order records an immediate requirement to handle such cases uniformly rather than through separate individual rulings.

    What does the new compensation mechanism provide?

    1. Core change: Projects that miss key implementation deadlines retain grid connectivity and receive additional time, instead of facing automatic revocation of transmission access.
    2. Charge for land and financial closure: Developers pay Rs 1,000 per megawatt per day to obtain extra time for land documents and financial closure.
    3. Charge for delayed commissioning: Developers pay Rs 3,000 per megawatt per day for delays in starting commercial operations.
    4. Graded escalation: Compensation is levied by the specific milestone sought, with rates generally increasing over time to push early compliance.
    5. Reasons made irrelevant: The order allows additional time on payment of compensation irrespective of the reasons for the delay.
    6. The stated justification: The Commission recorded that such entities have been holding on to connectivity, described as a scarce resource, which is why the extension is priced.

    What must a developer show to qualify for an extension?

    1. Timing condition: An entity must demonstrate project progress at least 15 working days before the original milestone deadline.
    2. Land threshold for the first two milestones: For land documentation and financial closure, the developer must furnish land documents for at least 20 per cent of the required land.
    3. Land threshold for commissioning: For an extension of the commercial operation date, the developer must furnish land documents for 50 per cent to 75 per cent of the required land, depending on the project type.
    4. Extension lengths: Developers can get up to three additional months for land requirements, six months for financial closure and up to 12 months to commission the project.
    5. Consequence of a second failure: Projects that still miss the extended deadlines risk losing both grid connectivity and the associated bank guarantees.

    Where does the compensation money go?

    1. Full pass through for commissioning delay: 100 per cent of the compensation collected for delays in commercial operations is used to reduce Monthly Transmission Charges for other users.
    2. Half pass through for the other two milestones: 50 per cent of the compensation collected for additional time on land documents and financial closure is applied the same way.
    3. The governing regulation: This reduction operates under the Sharing Regulations, 2020.
    4. The economic logic: The cost of an idle transmission corridor is otherwise socialised across all users, and the charge shifts part of that cost back to the developer causing the delay.
    5. What it does not do: The transfer compensates users financially and does not release the blocked corridor capacity for another project.

    Does pricing the delay protect the grid or entrench the hoarding of a scarce resource?

    1. The case for pricing: Revoking connectivity from a project at an advanced stage destroys sunk investment and returns the corridor to a queue that may take years to reallocate.
    2. The case against: A developer who can pay the daily charge can retain a corridor for up to a further twelve months, which keeps a scarce resource locked with the least prepared applicant.
    3. The design compromise: The land thresholds of 20 per cent and 50 to 75 per cent exist to separate genuinely progressing projects from speculative applications.
    4. The unaddressed gap: Compensation is payable irrespective of the reason for delay, so a developer delayed by a land dispute and one delayed by inaction are treated identically.
    5. The underlying constraint: The real bottleneck is that transmission capacity is built ahead of generation, and neither revocation nor compensation adds a single new corridor.

    Challenges to renewable energy grid connectivity in India

    1. Transmission lagging generation: Renewable capacity is commissioned faster than the evacuation lines that must carry it. e.g. wind and solar capacity in Rajasthan and Gujarat has repeatedly outpaced the completion of the associated Green Energy Corridor lines.
    2. Land aggregation delay: Utility scale solar and wind need large contiguous parcels assembled from many private owners. e.g. projects in Rajasthan have stalled over common land and grazing land claims that block the required land documentation.
    3. Curtailment risk: Even connected projects are backed down when the grid cannot absorb their output. e.g. wind generators in Tamil Nadu have faced curtailment during high wind season for want of evacuation capacity.
    4. Weak counterparty balance sheets: Distribution companies delay payment, which raises the cost of financial closure for developers. e.g. accumulated distribution company dues to generators ran into tens of thousands of crores before the late payment surcharge rules were tightened.
    5. Storage deficit: Solar output peaks at midday while demand peaks after sunset, so firm supply needs storage that remains costly. e.g. battery energy storage tenders have repeatedly been undersubscribed or repriced upward.
    6. Module and cell supply concentration: Domestic content requirements collide with the concentration of cell manufacturing abroad. e.g. approved list of models and manufacturers requirements have forced project timeline extensions when domestic module supply fell short.
    7. Speculative bidding: Aggressive tariff bids won without the ability to execute lock up corridors and tender capacity. e.g. several record low solar tariff bids were followed by unsigned power purchase agreements and stalled projects.

    Conclusion

    Grid connectivity is a scarce public asset built ahead of demand, and the regulator has moved from confiscating it on default to pricing its continued use. The order gives projects at an advanced stage a route to survive a missed milestone, and it transfers part of the cost of the delay from all transmission users back to the delaying developer. The mechanism is now in force with rates of Rs 1,000 and Rs 3,000 per megawatt per day and defined land thresholds. The next milestone is the treatment of the 5.3 GW facing revocation up to October, which will show whether the compensation route clears the backlog or extends it.

    Renewable Energy Sector in India

    1. About: The renewable energy sector covers solar, wind, small hydro, biomass, waste to energy and, in policy terms, large hydro and nuclear are counted within the wider non fossil category.
    2. Scale: India ranks among the top five countries globally in installed renewable energy capacity, and is placed in the top four in both solar and wind capacity.
    3. Milestone achieved: Non fossil sources crossed 50 per cent of India’s total installed electricity generation capacity in 2025, ahead of the timeline pledged under the Paris Agreement.
    4. Stated target: India has committed to 500 GW of non fossil fuel based installed capacity by 2030 and to net zero emissions by 2070.
    5. Geographic concentration: Rajasthan, Gujarat, Karnataka, Tamil Nadu and Andhra Pradesh account for the bulk of installed solar and wind capacity.
    6. Structural feature: Renewable generation is variable and location bound, which makes transmission planning and storage central to the sector rather than incidental.
    7. Institutional structure: The Ministry of New and Renewable Energy frames policy, SECI acts as the central nodal agency for tenders, and CERC regulates inter State transmission and tariffs.

    Statutory Framework Governing Electricity and Grid Access

    1. Entry 38 of the Concurrent List: Places electricity in the concurrent domain, so both Parliament and State legislatures can legislate on it.
    2. Section 79 of the Electricity Act, 2003: Sets out the functions of the Central Electricity Regulatory Commission, including regulation of inter State transmission.
    3. Section 38 of the Electricity Act, 2003: Provides for the Central Transmission Utility and its duty to provide non discriminatory open access.
    4. Section 61 of the Electricity Act, 2003: Lays down the principles the regulator must follow while determining tariffs.
    5. Section 86 of the Electricity Act, 2003: Gives State Electricity Regulatory Commissions the power to fix renewable purchase obligations.
    6. Section 63 of the Electricity Act, 2003: Allows adoption of tariffs discovered through a transparent competitive bidding process.

    Laws and Rules Governing Renewable Energy and Transmission

    1. Electricity Act, 2003: The parent statute governing generation, transmission, distribution, trading and use of electricity.
    2. Open access provision: Sections 39, 40 and 42 create the right of non discriminatory open access to transmission and distribution networks.
    3. Energy Conservation Act, 2001: Provides for energy efficiency standards and designated consumers.
    4. Energy Conservation (Amendment) Act, 2022: Introduced the carbon credit trading scheme and a renewable consumption obligation for designated consumers.
    5. CERC (Connectivity and General Network Access to the inter State Transmission System) Regulations, 2022: Govern grant, milestones and revocation of connectivity, the framework this order operates under.
    6. CERC (Sharing of Inter State Transmission Charges and Losses) Regulations, 2020: Set the method for pooling and allocating transmission charges among users.
    7. Electricity (Promoting Renewable Energy Through Green Energy Open Access) Rules, 2022: Allow consumers above a threshold to buy renewable power directly through open access.
    8. Electricity (Late Payment Surcharge and Related Matters) Rules, 2022: Impose a graded surcharge on distribution company dues to generators and restrict access on default.
    9. Electricity (Rights of Consumers) Rules, 2020: Set service standards including timelines for new connections and metering.

    Back2Basics: Central Electricity Regulatory Commission (CERC)

    1. Governing Act: Constituted under the Electricity Regulatory Commissions Act, 1998 and now functions under the Electricity Act, 2003.
    2. Year established: 1998.
    3. Headquarters: New Delhi.
    4. Composition: A Chairperson and up to three other Members, with the Chairperson of the Central Electricity Authority as an ex officio Member.
    5. Jurisdiction: Regulates tariffs of central generating stations, inter State transmission, inter State trading licences and the national grid.
    6. Mandate: Sets grid standards, regulates the power market, adjudicates disputes among inter State licensees and generating companies, and advises the Union government on tariff policy.
    7. Appeal route: Its orders are appealable to the Appellate Tribunal for Electricity and thereafter to the Supreme Court on a question of law.

    Government Initiatives in the Renewable Energy Sector

    1. PM Surya Ghar Muft Bijli Yojana: Provides central financial assistance for rooftop solar installations on residential houses, targeting one crore households.
    2. PM KUSUM: Supports solarisation of agricultural pumps and installation of decentralised solar plants on barren farmland for farmers.
    3. National Green Hydrogen Mission: Aims to build green hydrogen production capacity and associated electrolyser manufacturing, with incentives under the SIGHT programme.
    4. Green Energy Corridor: Funds dedicated transmission infrastructure to evacuate renewable power from generation rich States to demand centres.
    5. Waiver of inter State transmission charges: Exempts qualifying renewable and storage projects from inter State transmission charges for a defined period to improve project viability.
    6. PLI National Programme on High Efficiency Solar Photovoltaic Modules: Supports integrated domestic manufacturing of polysilicon, ingots, wafers, cells and modules.
    7. Solar Park and Ultra Mega Solar Power Projects Scheme: Provides pre acquired land and ready evacuation infrastructure to reduce developer risk.
    8. Viability Gap Funding for Battery Energy Storage Systems: Supports grid scale storage to address the evening peak and firm up variable renewable supply.

    Key Facts about India’s Renewable Energy Sector

    1. Nodal ministry: Ministry of New and Renewable Energy, the only dedicated renewable energy ministry of its kind when created.
    2. Non fossil milestone: India reached the 50 per cent non fossil installed capacity mark five years ahead of its Paris Agreement commitment.
    3. International Solar Alliance: Headquartered at Gurugram in India, jointly initiated by India and France in 2015.
    4. Largest solar parks: Bhadla in Rajasthan and Pavagada in Karnataka are among the largest solar parks in the world.
    5. Hybrid policy: India was among the first to notify a dedicated wind solar hybrid policy to improve capacity utilisation of a single grid connection.
    6. Renewable purchase obligation: State regulators fix a minimum share of renewable power that obligated entities must buy each year.
    7. Nodal tender agency: Solar Energy Corporation of India Limited conducts the largest share of central renewable capacity auctions.

    Challenges in India’s Renewable Energy Sector

    1. Grid integration and stability: High variable renewable penetration strains frequency and voltage management. e.g. States with high solar share face a steep evening ramp when solar output drops and demand peaks.
    2. Distribution company finances: Weak buyers delay payments and refuse to sign power purchase agreements at discovered tariffs. e.g. thousands of megawatts of auctioned capacity remained without signed agreements for want of buyers.
    3. Land and environmental conflict: Large projects compete with grazing land, wildlife habitat and community rights. e.g. transmission lines in the Thar region were litigated over Great Indian Bustard mortality.
    4. Manufacturing import dependence: Cells, wafers and polysilicon remain concentrated in a few countries. e.g. India continues to import a large share of solar cells despite module capacity expansion.
    5. Storage cost: Firm and dispatchable renewable supply needs storage that is still expensive at scale. e.g. round the clock renewable tenders have discovered tariffs well above plain solar tariffs.
    6. Skilled workforce and operation and maintenance: Remote plants need trained technicians for module cleaning, inverter servicing and blade repair. e.g. offshore wind, newly tendered off Gujarat and Tamil Nadu, has almost no domestic trained workforce.
    7. Recycling and waste: End of life modules and batteries carry a hazardous waste burden not yet planned for. e.g. India has no large scale commercial solar module recycling capacity.

    Way Forward

    1. Plan transmission ahead of generation: Commission evacuation corridors on a fixed lead over auctioned capacity so connectivity ceases to be the binding constraint.
    2. Tighten entry screening: Raise land and financial readiness thresholds at the connectivity application stage rather than only at the extension stage.
    3. Differentiate causes of delay: Provide a lower compensation rate for delays caused by force majeure or by transmission side readiness, and a higher rate for developer inaction.
    4. Scale storage procurement: Expand viability gap funding and mandate storage linked capacity in new renewable tenders to smooth the evening peak.
    5. Fix the buyer side: Enforce payment security mechanisms and time bound signing of power purchase agreements after auction.
    6. Build domestic supply chains: Extend manufacturing support upstream to wafers, polysilicon and battery grade materials.
    7. Create a module and battery recycling framework: Notify extended producer responsibility for solar modules and grid batteries before the first large retirement wave.

    Matching Previous Year Question

    “[2022, GS3, 15 marks] Do you think India will meet 50 percent of its energy needs from renewable energy by 2030 ? Justify your answer. How will the shift of subsidies from fossil fuels to renewables help achieve the above objective? Explain.”