Tripura — Energy Transition Snapshot
Generated 1 May 2026Carbon intensity (recent ~48h)
Generation mix (latest)
Peak deficit history (%)
Overview
Tripura is a small, landlocked state in India's North-East Region (NER) grid zone, sharing borders with Bangladesh on three sides. Its generation mix is dominated by gas-based thermal capacity—a legacy of the state's association with the Tripura gas fields—with negligible recorded renewable energy penetration at the latest hourly slice (0.0% RE share as of 2026-05-01). The headline number that defines Tripura's current energy posture is its carbon intensity: 818.2 gCO2/kWh averaged over the recent ~48h window, one of the highest possible signatures for a gas-heavy fleet with near-zero RE contribution. Peak supply reliability, however, appears stable: the p95 peak deficit stands at 0.0% as of 2026-04-23, indicating that demand is being met at the peak percentile within the POSOCO dataset window. The state is small in absolute consumption terms relative to mainland counterparts, and real-time demand telemetry is not available through the current Atlas feed, limiting granular load analysis.
Demand & Supply
Tripura's current generation mix, as captured across the recent ~48h window ending 2026-05-01, shows 0.0% RE share—meaning the entire metered generation slice is attributable to thermal sources, predominantly gas. This is consistent with the state's installed capacity profile centred on NEEPCO and ONGC-backed gas plants. The fuel-mix dataset covers 3 slices within the chart series, and no hydro or solar contribution is recorded in the available window. Real-time demand in MW is not available: the Atlas SLDC telemetry feed is not yet integrated for Tripura, so absolute load figures cannot be anchored here. What can be stated is that the p95 peak deficit over the POSOCO PSP daily series (23 data points) is 0.0%, indicating no recorded peak shortage at the 95th percentile threshold in the tracked window through 2026-04-23. This is a positive reliability signal for a NER state where grid connectivity constraints historically created supply gaps. The recent ~48h RE share window delta is -1.84 pp, meaning RE's already negligible contribution declined further across the window—though with RE at 0.0% at period-end, this delta likely reflects a brief period of marginal renewable dispatch followed by complete withdrawal rather than a structurally meaningful directional shift.
RE & Transition
Tripura's RE transition posture is, by the available metrics, effectively at a starting point. RE share at the latest hourly slice is 0.0% (2026-05-01), and the recent ~48h window delta is -1.84 pp, meaning even the small prior RE contribution that existed at the window's opening (approximately 1.84 pp) has been extinguished by period-end. The average carbon intensity of 818.2 gCO2/kWh over the ~48h window reflects a generation fleet running entirely on fossil fuel—consistent with a gas-dominant dispatch profile. For context, the national grid average carbon intensity typically sits in the 600–700 gCO2/kWh range; Tripura's 818.2 gCO2/kWh places it at the high end. Two critical data points needed to assess transition trajectory are not yet available: multi-year demand CAGR is absent because the Atlas platform does not yet expose a long-term aggregator (only ~48h real-time), and RPO compliance data is not yet integrated (IEA-58). Without these, it is not possible to assess whether Tripura is on a credible RE ramp path or falling behind its obligated RE procurement targets. Open-access charge data is also unavailable, removing a key proxy for RE procurement cost signals.
DISCOM Health
The available metrics provide a limited but coherent picture of Tripura's DISCOM health. On the reliability dimension, the p95 peak deficit is 0.0% (POSOCO PSP, through 2026-04-23), suggesting the utility is meeting peak demand obligations without recorded shortage at that percentile level—a reasonable baseline for a small NER state. However, three structural health indicators are absent from the current data build: AT&C losses are not yet integrated (UDAY dataset, IEA-57), meaning the utility's technical and commercial loss profile—historically elevated in NER states—cannot be quantified here. The residential tariff endpoint requires an API key not yet provisioned (tools-api), so tariff adequacy and cross-subsidy structure cannot be assessed. Open-access charge stacks (CSS, wheeling, transmission, losses at HT voltage) are also unavailable for Tripura, removing the standard proxy for cost-of-power signalling and OA economics. The IEX DAM price feed for the NER zone is currently empty, further limiting price benchmarking. In aggregate, the DISCOM health section must be treated as incomplete pending IEA-57 integration and API key provisioning.
Outlook
Over a 1–3 year horizon, Tripura's energy posture presents a narrow but clear set of priorities derivable from available data. The 818.2 gCO2/kWh carbon intensity and 0.0% RE share as of the latest slice define the baseline: any RE capacity addition—solar, small hydro, or wind—will produce immediate carbon intensity reduction from a near-zero RE starting point, making marginal abatement cost calculations relatively favourable. The 0.0% p95 peak deficit is a constructive signal for grid-scale RE integration, as it suggests current infrastructure is not under peak stress, reducing the urgency of storage or backup firming investment in the near term. Critical uncertainties that constrain a more precise outlook: demand growth trajectory is unknown (CAGR data not yet integrated), RPO compliance baseline is absent (IEA-58), and AT&C loss levels—which directly affect DISCOM investment capacity—are not yet available (IEA-57). For investors and policy advisors, the priority data requirements before committing to Tripura-specific energy positions are: AT&C loss quantification, RPO compliance gap assessment, and IEX NER zone DAM price restoration to establish power cost benchmarks. The state's NER geography and gas infrastructure legacy are structural parameters; the transition path depends on policy variables not yet visible in the current dataset.
Data gaps in this brief
- Transmission ATC: Atlas endpoint not yet integrated (see IEA-56).
- DISCOM AT&C losses (UDAY): Atlas endpoint not yet integrated (see IEA-57).
- RPO compliance: state RE policy dataset not yet integrated (see IEA-58).
- Subsidies / incentives: state catalogue not yet integrated (see IEA-59).
- Residential tariff: Atlas tariff endpoint requires X-API-Key not yet provisioned for tools-api.
- Multi-year demand CAGR: Atlas does not yet expose a long-term aggregator (only ~48h realtime).
- IEX DAM price: upstream IEX area-prices feed currently empty.
- Transmission ATC: Atlas endpoint not yet integrated (IEA-56).
- DISCOM AT&C losses (UDAY): Atlas endpoint not yet integrated (IEA-57).
- RPO compliance: state RE policy dataset not yet integrated (IEA-58).
- Subsidies / incentives: state catalogue not yet integrated (IEA-59).
- Multi-year demand CAGR: Atlas does not yet expose a long-term aggregator (only ~48h real-time).
- IEX DAM price: upstream IEX NER area-prices feed currently empty.