May 07, 2026
Sri Lanka’s Looming Energy Crisis- Peak Demand Poised to Outstrip Maximum Supply Around 2028
Sri Lanka stands at the threshold of a structural energy challenge. According to the Ceylon Electricity Board’s (CEB) Long-Term Generation Expansion Plan (LTGEP) 2025–2044, night-time peak demand was forecast to reach approximately 3,101 MW and day-time peak 3,190 MW by 2028 — levels that would test the limits of the country’s generation and transmission infrastructure. Yet real-world data shows the timeline accelerating: the system already recorded an all-time high peak of 3,089 MW in March 2026, driven by post-crisis economic recovery, surging air-conditioning use, industrial growth, and the rapid adoption of electric vehicles (EVs). Without urgent intervention, peak demand risks outgrowing reliable peak supply capacity by 2028, leading to higher tariffs, increased curtailment of renewables, and potential reliability issues.
Rapid Growth in Peak Demand
Electricity demand in Sri Lanka has historically grown at 4–5% annually, but recent trends show acceleration in both energy consumption and peak loads. Key drivers include:
- Economic rebound and rising living standards.
- Electrification of transport (EVs adding evening charging loads).
- Commercial and industrial expansion.
- A shifting daily load curve: daytime peaks are now surpassing traditional evening/night peaks on many days, largely due to commercial activity and rooftop solar self-consumption flattening midday net demand.
LTGEP Peak Demand Projections (MW)
| Year | Day Peak (MW) | Night Peak (MW) | Growth Rate (approx.) |
|---|---|---|---|
| 2025 | 2,727 | 2,696 | 5.3% |
| 2026 | 2,872 | 2,824 | 5.3% |
| 2027 | 3,027 | 2,959 | 5.4% |
| 2028 | 3,190 | 3,101 | 5.4% |
| 2029 | 3,362 | 3,250 | 5.4% |
| 2030 | 3,548 | 3,411 | 5.5% |
Source: CEB LTGEP 2025–2044 (Base Case). Day peak already overtaking night peak in many scenarios.
Rooftop solar (now exceeding 1,700–2,000 MW embedded capacity) has helped reduce net daytime load but has done little to ease the evening/night peak, when solar generation drops to zero and the system relies heavily on dispatchable thermal and hydro resources.
Supply-Side Constraints and the “Firm Capacity” Gap
Total installed capacity stands at around 5,194 MW (end-2023), with a growing share from renewables (hydro, wind, solar). The LTGEP targets 70% renewable energy by 2030 through massive additions: ~5,335 MW of new renewables between 2025–2034 alone (primarily solar and wind). However, firm/peaking capacity — the amount of reliable power available during critical evening/night peaks — is far lower due to:
- Seasonality of hydro (major source of firm power).
- Intermittency of variable renewables (solar contributes ~0 MW at night; wind is weather-dependent).
- Retirements of older thermal plants and delays in new gas-fired or storage projects.
Without sufficient flexible capacity, the system risks energy shortfalls during dry seasons or high-demand periods, pushing reliance on expensive imported fuels and raising generation costs.
Transmission Grid Maxing Out: The Silent Bottleneck
Even if generation capacity is added on paper, the transmission and distribution grid is rapidly becoming the binding constraint. Key issues include:
- Congestion on 132 kV and 220 kV lines, especially between renewable-rich areas (North, North-West, East) and major load centres (Western Province/Colombo).
- Substation transformer limits (many grid substations capped at ~25–31.5 MVA per unit), restricting new connections.
- Lagging infrastructure upgrades: many planned large-scale RE projects under the GREAT programme (2025–2030) are front-loaded, while critical transmission reinforcements are scheduled later.
- High non-synchronous penetration (solar/wind) reduces system inertia, increasing vulnerability to faults.
Result: frequent curtailment of renewables during high-generation/low-demand periods (e.g., sunny weekends), wasted clean energy, and inability to deliver power reliably during peaks. Experts warn that without parallel transmission development, new generation cannot be fully evacuated, effectively capping usable supply.
The 2028 Crisis Risk
If current trends continue:
- Peak demand could exceed reliable firm supply during evening hours.
- Increased dependence on costly thermal peaking plants → sharp tariff hikes.
- Higher risk of load shedding or brownouts, especially in dry hydrological years.
- Economic ripple effects: disrupted manufacturing, tourism, and household affordability.
The LTGEP itself highlights contingency risks — delays in projects, fuel restrictions, or higher-than-expected demand could create capacity deficits as early as the late 2020s.
Potential Solutions: BESS and Distributed Grids
Fortunately, viable technical solutions exist and are already being prioritised.
1. Battery Energy Storage Systems (BESS) — The Immediate Peak-Shifter
BESS can store surplus daytime solar energy and discharge it during the critical 6–10 pm evening peak, directly addressing the “duck curve.”
- Grid services: frequency regulation, voltage support, inertia — essential for high-renewable grids.
- CEB plans: ~900 MW cumulative BESS targeted in LTGEP; recent tenders for 160 MW/640 MWh (including multiple 10 MW/40 MWh units) and larger projects (up to 650 MW scale) accelerated to 2028–2029 timelines.
- Hybrid solar + BESS projects are being fast-tracked.
Early deployment could shave hundreds of MW off evening peaks and reduce curtailment.
2. Distributed Grid and Decentralised Energy Resources (DER)
Moving from a centralised “big generation → long transmission” model to a smarter, distributed system:
- Rooftop solar paired with behind-the-meter batteries.
- Community microgrids and Distribution Control Centres (DCCs) for real-time visibility and control of DER.
- Time-of-Use (ToU) tariffs, demand response, and smart metering to incentivise peak shaving and load shifting.
- Benefits: reduces transmission congestion, improves resilience, lowers losses, and empowers consumers/prosumers.
Complementary measures include pumped-storage hydro (600 MW planned), urgent transmission upgrades (new lines, reconductoring, eventual 400 kV backbone), energy efficiency programmes, and policy support for private investment in storage and distributed solutions.
Conclusion: Time to Act Is Now
Sri Lanka’s renewable-energy ambitions — 70% RE by 2030 and carbon neutrality by 2050 — are bold and necessary. However, success depends on solving the intertwined challenges of peak supply, transmission bottlenecks, and grid flexibility. By prioritising BESS deployment and accelerating the transition to a modern, distributed grid, the country can avert a 2028 crisis, lower long-term costs, enhance energy security, and turn its abundant solar and wind resources into a true economic advantage.
The next 2–3 years will be decisive. Timely implementation of the LTGEP’s grid-support interventions is not optional — it is essential for keeping the lights on and the economy growing.