European Utilities & Clean Energy: Tight European gas balances and rising power forwards create growing earnings upside for selected utilities from 2027-28.

Overview

Bernstein examines how a sharp rise in European gas and power prices may affect the earnings of covered European utilities and renewable generators. It expects the immediate effect to be modest because 2026 output is largely hedged, but sees greater upside into 2027-28 as merchant exposure increases and retail contracts are renewed.

Core views

The report links the recent increase in European power prices to a tighter gas market following Middle East-related supply disruption. Since the beginning of August, two-year forward power prices have risen by €15-20/MWh and the German three-year forward by about €10/MWh. The immediate concern is weak European gas storage: inventories were 67% full on 9 September 2026, compared with 80% at the same point in 2025 and 93% in 2024; German storage was only 55%, versus 74% a year earlier. Bernstein's winter balance scenarios show storage falling to 18% by April 2027 under base-case conditions, to 3% with lower LNG flows, and theoretically into deficit under a cold winter combined with lower LNG availability. The report argues that low end-winter inventories could also raise the refill requirement and sustain competition for LNG into summer 2027. The gas-price shock feeds into electricity prices because gas-fired plants often set the marginal power price. Although gas represented only 17.6% of EU generation in 2025, fossil plants set prices in roughly 50% of hours. German one-month power forwards rose 81%, from €86/MWh in February to €155/MWh in September, while three-month forwards more than doubled from €67/MWh to €165/MWh. The transmission varies by market: gas influenced an estimated 75% of Italian day-ahead pricing hours in January-May 2026, compared with 9% in Spain. Bernstein also sees demand support: power demand across France, Germany, Italy, Spain and the UK recovered 1.3% in 2024, rose 0.2% in 2025 and was up 1.2% year on year in the first eight months of 2026. Electrification, data centers, electric vehicles, heat pumps and industrial projects could lift European consumption 7-16% from 2024 by 2030; Bernstein estimates Iberian demand could rise nearly 17% excluding green hydrogen and nearly 20% including it. The earnings impact depends on merchant generation after hedges, PPAs, regulated returns and retail supply offsets. Structural merchant exposure ranges from roughly 20-90% of expected generation for integrated utilities and 25-66% for renewable producers, but retail customer bases and contracts reduce the effective earnings sensitivity. Most utilities have hedged nearly all expected 2026 production, so Bernstein expects limited 2026 upside. As hedging declines, close to 20% of integrated utilities' expected output could benefit in 2027, and by 2028 market-exposed volumes approach structural merchant exposure. A €10/MWh increase in power prices is estimated to add 10.4% to EDP's 2028 net profit, 9.1% to Endesa's, 12.3% to EDPR's and 13.7% to Verbund's; Iberdrola, Enel and Engie show modeled 2028 impacts of 4.9%, 4.7% and 3.4%, respectively. Bernstein identifies EDP, EDPR and Endesa as the clearest beneficiaries over the next two to three years. Renewable-generator sensitivities require more qualification than headline merchant exposure implies. Acciona Energia and Solaria have high theoretical sensitivity, but realized benefit depends on future PPAs, solar capture prices and, for Acciona Energia, planned asset disposals. Bernstein expects Solaria's actual impact to be 40-60% lower than a simple application of a €10/MWh increase to all merchant output because its solar production profile may not capture peak gas-driven prices. Grenergy's merchant exposure is mainly tied to Chilean battery-storage assets; both tradable volumes and spreads may decline as batteries degrade and additional storage enters the system. Verbund's apparent sensitivity may be diluted by low hydro production, which could require it to buy power at high market prices to meet hedges, and by possible windfall-tax extensions. Bernstein also assesses a narrower gas-trading opportunity for Naturgy, Endesa and Engie. It uses Henry Hub-TTF spreads of €62/MWh for 4Q26, €36.5/MWh for 2027 and €12.3/MWh for 2028, while assuming only 1.0-10.0% of Henry Hub-linked volumes and 1.5-5.0% of Algerian or oil-linked supply remain available for trading. The potential is limited near term because capacity may already have been used when spreads initially widened. Naturgy has the greatest modeled net-profit upside, at 7.2% in 2027 and 4.6% in 2028; Engie's potential uplift is 5.5% and 3.5%, subject to limited visibility on procurement and unhedged volumes, while Endesa's is more limited at 2.0% and 1.2%. The report expects this trading window to be most relevant in 4Q26 and 2027 before margins normalize in 2028. Longer term, Bernstein expects LNG tightness through 2027 but a return to surplus from 2028 as projects complete. Middle East disruption is estimated to have removed about 63 MTPA of LNG supply, while delays to Qatar's North Field expansion reduce expected 2026 additions by another 5 MTPA, producing an estimated net 20 MTPA decline in effective 2026 supply. In contrast, existing and under-construction projects could create about 50 MTPA of surplus LNG capacity by 2030. The report therefore treats merchant exposure as potential upside over the coming years, while noting expected gas-price normalization by 2029-30.

Analysis framework

Bernstein first models European gas supply, storage and winter-demand scenarios, then explains how gas costs influence power prices through marginal pricing. It estimates each company's effective merchant generation after hedges, retail offsets, PPAs and regulated volumes, applies power-price sensitivities across 2026-28, and separately models potential gas-trading profits from assumed unhedged volumes and Henry Hub-TTF spreads.

Methodology notes

• Industry AnalysisSupply-demand framework

  European gas and LNG supply-demand scenario analysis

  The report compares LNG availability, winter demand and storage paths to assess how tight gas balances could influence gas and power prices.

• Industry AnalysisUpstream-Midstream-Downstream Transmission

  Gas-to-power marginal-pricing transmission

  It explains that higher gas costs can lift wholesale power prices when gas-fired plants set the marginal electricity price.

• Industry AnalysisVolume-price decomposition

  Merchant-volume and power-price sensitivity analysis

  The report separates the share of generation exposed to market prices from the price change, then estimates resulting net-profit effects.

Asset mapping & comparison

Structured mapping from thesis to named assets (strengths, weaknesses, peers, risks).

• EDP

  Identified as one of the best-positioned utilities for a higher-for-longer power-price environment.

  Strengths

  Modeled 2028 net-profit sensitivity of 10.4% for each €10/MWh power-price increase.

  Weaknesses

  Near-term benefit limited by hedging.

  Comparison

  Alongside EDPR and Endesa, Bernstein sees the clearest 2028 upside.

  Risks

  Realized benefit depends on future price levels and hedge roll-off.

• EDP Renovaveis (EDPR)

  Identified as a leading beneficiary of higher power prices.

  Strengths

  Modeled 2028 net-profit sensitivity of 12.3% per €10/MWh power-price increase.

  Weaknesses

  Hedging strategy resembles integrated utilities for volumes placed with EDP; US generation is generally unhedged.

  Comparison

  Included with EDP and Endesa among the strongest prospective beneficiaries.

  Risks

  PPA arrangements and generation exposure affect realized sensitivity.

• Endesa

  Identified as a leading power-price beneficiary and a potential gas-trading beneficiary.

  Strengths

  Modeled 2028 power-price sensitivity of 9.1%; strategic plan assumes Spanish demand growth of 3% annually over 2025-30.

  Weaknesses

  Gas-trading upside is constrained by lower available volumes.

  Comparison

  Modeled gas-trading upside is below Naturgy and Engie.

  Risks

  Higher-price benefit depends on hedging, available gas volumes and power-price persistence.

• Verbund

  Has meaningful power-price sensitivity but with material offsets.

  Strengths

  Modeled 2028 net-profit sensitivity of 13.7% per €10/MWh power-price increase.

  Weaknesses

  Low hydro output may force power buybacks at elevated prices; taxation may dilute gains.

  Comparison

  Its headline sensitivity is high, but Bernstein considers the outcome less attractive than for EDP, EDPR and Endesa.

  Risks

  Hydro generation uncertainty and potential windfall-tax extension.

• Solaria

  A renewable producer with high theoretical merchant sensitivity.

  Strengths

  High reported merchant exposure and modeled sensitivity.

  Weaknesses

  Solar capture prices and daylight production patterns limit pass-through from wholesale price increases.

  Comparison

  Bernstein expects the actual effect to be 40-60% below a simple merchant-output calculation.

  Risks

  New PPAs, solar capture prices and broader battery deployment.

• Naturgy

  The report identifies the greatest incremental gas-trading upside among the three analyzed traders.

  Strengths

  Potential net-profit uplift of 7.2% in 2027 and 4.6% in 2028 under modeled assumptions.

  Weaknesses

  Only limited volumes are assumed available in 2026.

  Comparison

  Greater modeled gas-trading upside than Endesa and Engie.

  Risks

  Available unhedged volumes and volatile Henry Hub-TTF spreads.

Key data

• European gas storage67% full on 9 September 2026Versus 80% in 2025 and 93% in 2024; Germany was at 55% versus 74% a year earlier.
• Base-case April 2027 storage18%Bernstein scenario assuming historical-peak LNG imports and winter 2024/25 demand.
• German one-month power forward€155/MWhUp 81% from €86/MWh between February and September 2026.
• European power-demand change+1.2% YoYFirst eight months of 2026 across the five largest European power markets.
• European demand growth to 20307-16% versus 2024Upper end equates to about 2.4% CAGR.
• EDP 2028 power-price sensitivity+10.4% net profit per €10/MWhBernstein estimate.
• Naturgy gas-trading upside+7.2% net profit in 2027; +4.6% in 2028Based on assumed available volumes and Henry Hub-TTF spreads.

Impact & implications

The report views higher power prices as a growing earnings opportunity rather than a broad sector-wide benefit. Hedges restrict 2026 exposure, while companies with higher effective merchant exposure and favorable contractual positions could see larger gains as 2027-28 hedges and retail contracts reset. Longer-term LNG supply additions may moderate the gas and power-price support from 2028 onward.

Risks

• A warm or well-supplied winter, stronger LNG inflows, or eventual LNG oversupply could weaken gas and power prices.
• Most 2026 generation is already hedged, limiting near-term earnings sensitivity.
• Verbund faces hydro-generation shortfall and taxation risks that can dilute apparent power-price upside.
• Solar capture prices, new PPAs and Acciona Energia asset disposals may materially alter renewable-generator outcomes.
• Gas-trading upside depends on uncertain unhedged volumes and highly volatile Henry Hub-TTF spreads.

What to watch

• European gas-storage withdrawals and end-winter 2027 inventory levels.
• LNG import flows, Asian competition for cargoes and continued disruption through the Strait of Hormuz.
• The pace at which 2027-28 utility hedges roll off and retail contracts are repriced.
• European power-demand recovery, particularly Iberian industrial and data-center demand.
• Solar capture prices, PPA renewals, hydro output, windfall-tax developments and gas-trading volume availability.