Romande Energie 2025 slides: EBITDA jumps 25%, eyes net-zero future

Romande Energie reported a strong 2025 turnaround, with adjusted EBITDA up 25% to CHF 152 million, EBIT more than doubling to CHF 48 million, and net profit surging 208% to CHF 80 million. Management also outlined 2030 targets for CHF 170-190 million of adjusted EBITDA and CHF 160-200 million of annual capex, while proposing a CHF 1.44 per share dividend. The results were supported by efficiency gains and Alpiq earnings, though hydro output was hurt by weather-related headwinds.

Analysis

The real signal here is not utility earnings momentum; it’s the emergence of a regulated platform that is quietly monetizing the electrification buildout ahead of the obvious volume inflection. The mix shift toward grid, smart metering, thermal networks, and digital services lowers earnings cyclicality and increases the share of value coming from quasi-infrastructure returns rather than commodity-like generation, which should command a better multiple if execution stays clean.

Second-order beneficiaries are the equipment and service vendors that sit inside the capex envelope: grid automation, metering, data-center/IT modernization, district-heating infrastructure, and distributed solar/heat-pump ecosystems. The slower-moving competitive risk is that peers with weaker balance sheets may be forced into more expensive financing to keep pace with the same transition, widening the quality gap across European regional utilities.

The main risk is that the market extrapolates a one-year rebound into a smooth multi-year compounding story. Hydrology, power price normalization, and a lower allowed return environment can all cap upside quickly; the business has enough moving parts that a few basis points of WACC or a poor weather year can offset much of the operational improvement. I’d also flag that the equity story may already be partially de-risked by the dividend profile, so upside likely comes from multiple expansion only if digital and property revenue visibly accelerate over the next 12-24 months.

Contrarian view: consensus will likely focus on the ESG/renewables angle and miss that the higher-quality trade is the grid and services layer, not generation. The transition creates a better scarcity asset in regulated distribution and recurring service contracts than in merchant power, so the best expression is not beta to the whole utility sector but selective ownership of the parts of the value chain with pricing power and capex visibility.

Key Decisions for Investors

• Long REHN on a 6-12 month horizon if it trades near current payout-supported valuation; treat it as a low-volatility quality compounder, but only with 10-15% upside from multiple re-rating if execution on digital/property becomes visible.
• Prefer a pair trade: long European regulated grid/service names versus short merchant-heavy utilities for 6-18 months; the thesis is lower earnings volatility and superior reinvestment visibility as electrification capex broadens.
• Add exposure to grid automation and smart-meter supply chain equities on pullbacks over the next 3-9 months; the operating leverage is in the vendors, not the utility, and order books should track the capex cycle.
• For existing utility sleeves, overweight companies with district-heating, heat-pump, and customer-services exposure; avoid pure generation beta where weather and power-price normalization can erase the rebound.
• If REHN rallies on dividend yield compression, use strength to trim and rotate into names with clearer 2030 capex visibility; risk/reward shifts from fundamental rerating to income only once the market prices the transition story.