The decision by the Joint Electricity Regulatory Commission to approve an average electricity tariff hike of 6.83% has sent shockwaves through the economic fabric of Jammu & Kashmir. Promoted by officials as a mild adjustment, the 6.83% figure is deeply misleading for the commercial, trade, and industrial sectors, where the effective tariff increase on primary energy charges hits between 9.5% and nearly 10%. For commercial entities—ranging from micro-enterprises, artisans, and shopkeepers to manufacturing units and hospitality ventures—this structural inflation arrives at a time when local purchasing power is depressed and operational costs are surging. It forces the law-abiding business community to continuously finance systemic inefficiencies and structural default gaps created elsewhere.
The fundamental paradox of Jammu & Kashmir’s energy crisis lies in the deep imbalance between state-owned assets and central-sector dominance. While the region possesses an estimated hydel potential exceeding 20,000 MW, it currently harnesses only a small fraction. The state sector, through the Jammu and Kashmir State Power Development Corporation, operates roughly 1,197 MW across projects such as Baglihar Stage I and II, Upper Sindh, and Lower Jhelum. In contrast, central sector entities like National Hydroelectric Power Corporation control major operational power stations including Salal (690 MW), Uri-I and II (720 MW), and Dulhasti (390 MW).
A critical vulnerability in this structure is the royalty framework governing these central projects. Under historical agreements, Jammu and Kashmir receives a flat 12% free power as royalty from central units, with the remaining 88% flowing directly into the National Grid. This static 12% royalty leaves Jammu and Kashmir far below the standard royalty realization achieved by other hydro-rich Himalayan states across India. States like Himachal Pradesh operate under tiered royalty agreements that yield 12% for the first 12 years, increasing to 18% for the next 18 years, and escalating to 30% for the final decade of a project’s lifecycle. Furthermore, following recent legal affirmations, states like Himachal receive up to 18% contractual free power from major hydel installations after debt servicing. By contrast, Jammu and Kashmir remains bound to an unrevised flat 12% royalty despite central projects operating for decades past their debt-amortization periods, leaving the region far short of parity with national standards.
Because run-of-the-river hydro generation surges during summer and plummets during peak winter months when river discharge drops dramatically, Jammu and Kashmir is trapped in a financially disastrous cycle. During summer, the region transfers its seasonal surplus energy—from both state units via banking and central stations—into the National Grid at low summer market prices ranging from ₹2.50 to ₹3.50 per unit. Come winter, when local peak load demand surges to between 3,700 MW and 3,900 MW, Jammu and Kashmir is forced to buy back thermal and market grid energy from national traders at inflated spot prices ranging from ₹6.00 to over ₹10.00 per unit. Despite decades of operation where initial capital debt and construction costs of major projects have long been amortized and recovered, the core assets remain vested with central entities while the region pays astronomical sums to buy back power generated by its own rivers.
This structural reality explains why the 6.83% tariff hike fails to meaningfully curtail the power sector’s deficit. The regulatory commission established the annual revenue requirement for the distribution companies at ₹10,275.72 Crore, while revenue under pre-revised tariffs sat at ₹7,352.87 Crore, leaving a massive operational gap of ₹2,922.85 Crore. The 6.83% tariff hike yields approximately ₹502 Crore, which retains only 17.1% of this immediate revenue deficit. The remaining 82.9%, amounting to ₹2,420.78 Crore, must still be covered by direct grant-in-aid subsidies from the government budget. The hike damages local trade without resolving the core structural deficit, primarily because power purchase costs account for over 85% of total department expenditure. Penalizing paying business consumers simply cannot bridge these macro-level operational losses.
A major flaw in current revenue recovery mechanisms is the massive accumulation of unpaid commercial arrears, which stand at over ₹3,700 Crore across Jammu and Kashmir. While recent government amnesty schemes offered complete interest and surcharge waivers exclusively to domestic consumers, the commercial sector remains trapped under compounding interest penalties and late-payment surcharges that frequently make up 40% to 50% of total billed balances. Hyper-inflated paper debt discourages settlements and stalls recovery in endless litigation. If the Power Development Department were to implement a One-Time Commercial Amnesty Scheme—waiving non-viable interest and penalty surcharges—commercial establishments would gain a realistic pathway to settle their baseline principal. This single measure would immediately unlock hundreds of crores in direct liquidity for the distribution utilities, clear stalled disputes, and generate vastly more revenue than the annual ₹502 Crore yielded by the tariff increase.
Looking ahead, electricity demand in Jammu and Kashmir is growing at an annual compound rate of 6%, with peak demand projected to rise from 3,980 MW (22,000 Million Units) in 2026–27 to over 5,044 MW (27,800 Million Units) by 2030–31. To meet this growth, several major hydroelectric projects are under execution in the Chenab basin, including Pakal Dul (1,000 MW), Kiru (624 MW), Ratle (850 MW), Kwar (540 MW), Dulhasti Stage-II (260 MW), Uri-I Stage-II (240 MW), and Sawalkote (1,856 MW). However, even after commissioning these upcoming projects, Jammu and Kashmir’s structural winter deficit will persist. Because winter river flows reduce hydel availability by 75% to 80%, several thousand megawatts of installed capacity will still yield only a fraction of power during peak cold months. Furthermore, because key upcoming projects are structured as 51:49 Joint Ventures with central sector entities, Jammu and Kashmir will not retain 100% of the generated power, leaving the majority share to be fed into the National Grid and bought back at determined power purchase rates. Addressing Jammu and Kashmir’s power crisis requires a fundamental shift: renegotiating central project royalty terms to align with national standards, enacting commercial debt amnesties to recover principal liquidity, securing fixed winter thermal power allocations to hedge against spot market spikes, and transitioning future power development toward full state ownership.
