Climate vs. Grid: How El Niño is Forcing a Re-evaluation of Costa Rica’s Renewable Monopoly ⋆ The Costa Rica News

Costa Rica’s electricity story has long been told as a triumph of renewables. But the latest swing of the climate pendulum is stress-testing that narrative. As El Niño tightens its grip and drought conditions deepen, the country’s hydropower-heavy system is being pushed to its limits—just as a bruising political fight erupts over the future of the national grid.

When the rains falter, the lights flicker

Hydropower is the backbone of Costa Rica’s energy matrix, delivering roughly three-quarters of all electricity by 2025 (about 76%). Wind supplied around 12%, geothermal close to 11%, and solar barely a fraction of a percent. Fossil generation—largely used as a contingency—stayed near 1.4%.

That balance works brilliantly in wet years. In dry years, it becomes a gamble. After back-to-back seasons of below-average rainfall in 2024 and 2025, river levels thinned. Forecasts now point to a substantial rainfall deficit—on the order of 30% in the coming rainy season—consistent with a strengthening El Niño in the Pacific. When reservoirs don’t refill, turbines can’t spin at full output, and the country’s enviably green grid becomes startlingly vulnerable.

To bridge the gap, the Costa Rican Electricity Institute (ICE) has scrambled to line up thermal backup and imported generation as a stopgap, prioritizing grid continuity over purity of the energy mix. Blackouts are not expected to be widespread, but the financial consequences are real: running backup plants and buying power on tight markets adds costs that ultimately filter into rates.

A policy fight wrapped in a drought

The strain has revived a long-simmering debate about how Costa Rica should organize and pay for its power system. The administration of President Laura Fernández is pushing a reform package known as the “Harmonization of the National Electric System,” arguing that opening generation, commercialization, and distribution to greater private participation will attract investment, meet rising industrial demand, and help keep prices competitive in a harsher climate era.

Opponents see it differently. Labor groups, academics, and several opposition lawmakers warn that the proposal could amount to a de facto privatization, weakening ICE’s coordinating role and undermining the grid’s solidarity principle—the cross-subsidies that keep service affordable for low-income families and remote communities. They also worry about intensified pressure on local watersheds if market incentives tilt toward short-term gains over long-term stewardship.

The political math is tight. While the government wields a working majority, it lacks the supermajority often needed to sail through structural reforms. The result: a standoff likely to stretch as long as the reservoirs stay low.

Regional tensions narrow the safety margin

Adding complexity, a diplomatic spat has chilled regional energy cooperation. Panama recently announced it would halt electricity sales to Costa Rica after disagreements flared over broader trade issues. Costa Rican officials insist the country can maintain baseline stability without cross-border imports via the Central American interconnection system, but the loss of a regional pressure valve during drought undeniably raises the stakes.

What resilience could look like

Regardless of who controls which rungs of the market, the climate is sending an unmistakable message: hydrologic risk must be diversified. Several practical steps could reduce exposure and stabilize rates over the next decade:

• Lean harder into firm, drought-proof renewables such as geothermal, which can provide 24/7 baseload and is already a national strength.
• Accelerate wind repowering and strategic siting to harvest stronger, more consistent resources, paired with modern forecasting to cut reserves.
• Scale energy storage—batteries for short-duration balancing and pumped hydro where feasible—to smooth variability and protect reservoirs.
• Unleash distributed rooftop solar with smart inverters and time-of-use tariffs, while ensuring fair cost-sharing for grid upkeep.
• Invest in demand response so big users can flex consumption during tight hours, reducing the need for costly peaker plants.
• Protect watersheds with integrated basin management that prioritizes recharge, forest cover, and climate-ready reservoir operations.
• Design market or regulatory mechanisms that preserve social equity—keeping lifeline tariffs and rural service viable—no matter who sells the kilowatt-hours.

Short-term triage also matters. Power-purchase agreements for firm capacity, fuel hedges for backup plants, targeted efficiency campaigns, and transparent drought surcharges can stabilize the system while bigger projects come online.

Beyond the monopoly vs. market binary

The current argument is framed as an all-or-nothing choice: maintain a centralized, publicly led system or swing the doors open to private competition. In reality, many successful grids blend public planning with private capital and innovation—anchored by clear rules, independent oversight, and strong consumer protections.

For Costa Rica, the crucial questions are less ideological than practical: How fast can new firm renewables be built? Who pays for resilience upgrades? How will the costs and benefits be shared across households, industries, and regions? And can reforms, if adopted, lock in climate security and social equity at the same time?

The crossroads

El Niño is not an outlier; it is a preview. As extremes intensify, a system that depends on rainfall for roughly 76% of its electricity must evolve. Whether Costa Rica reinforces its public model or restructures the market, success will be measured by three outcomes: reliable power through multi-year droughts, stable and fair pricing, and protection of the watersheds that make renewables possible in the first place.

The green showcase can endure—but only if resilience becomes as central to policy as renewable ambition once was.