The CRU published its Interim Review of the Electricity and Gas Retail Markets on 11 May 2026 (reference CRU202667). The report lands in an active policy context, it feeds directly into the National Energy Affordability Taskforce (NEAT) and is intended to inform any government response ahead of the 2026/27 winter period. For Irish facility managers, school principals, and SME owners, the immediate read-out is this: competition in the market is functioning, meaningful savings are available to active buyers, but not everyone is capturing them, and the cost structures that drive your bill are more complex and more fixed than most operators realise.

Why This Review Exists Now

The CRU initiated this interim report ahead of its fuller competition review, which will take several more months and will include a dedicated customer survey. Two triggers accelerated the timeline: developments in the Middle East affecting global energy commodity prices, and the ongoing work of NEAT. The interim report was prepared with input from the Competition and Consumer Protection Commission (CCPC), and both bodies are aligned on its conclusions.

A full review, covering profit margins across customer segments over time, and incorporating direct customer perspectives, is still to come later in 2026. Operators should treat this document as a first read, not a final verdict.

What Makes Up Your Bill, and What You Can’t Control

The most practically useful section of the report for non-domestic operators is the detailed breakdown of electricity tariff components. The CRU calculates a weighted average Estimated Annual Bill (EAB) for a standard urban domestic customer of €1,867 as of March 2026, based on a 4,200 kWh annual consumption on a 24-hour standard tariff. For non-domestic customers, the same cost categories apply, though how they are weighted differs by connection size and usage pattern.

The bill decomposes as follows (figures are for the domestic benchmark; business bills carry the same structure):

Energy cost (wholesale): ~€828, the single largest component at roughly 44% of the total bill. This is what suppliers pay in the wholesale market and pass through to customers, shaped heavily by their hedging strategies.
Distribution Use of System (DUoS): ~€302, covering the standing charge (€86.04 for urban DG1 customers; €125.49 for rural DG2) and a unit rate charge of €216.05. These are CRU-regulated and non-negotiable between suppliers.
Transmission Use of System (TUoS): ~€173, broken into Network Capacity (€32.48), Network Transfer (€18.66), and System Services (€121.73). Regulated, pass-through.
Capacity Charges (CRM): a separate line reflecting Ireland’s Capacity Remuneration Mechanism, which applies during daytime hours (08:00–23:00) only.
Supply costs: ~€172, the portion suppliers can actually influence: operational overhead, customer acquisition, bad debt, wages, and profit margin.
PSO Levy: €17.52 per domestic customer in the current tariff year, funding REFIT, RESS, and the new Small-Scale Renewable Electricity Support Scheme (SRESS).
VAT: 9%, the reduced rate, extended by Budget 2026 to run until 31 December 2030.
Wholesale Market Charges: €6.01 in total, covering the Residual Error Volume Price (€2.10), Currency Adjustment (€0.32), Market Operator Charges (€2.77), and Agent of Last Resort (€0.82).

The critical operational point: network charges, capacity charges, system services, the PSO levy, and VAT are all pass-through costs. No supplier can change them; they are set by CRU regulatory decision and apply identically across the market. The areas where suppliers actually compete, and where an active buyer can extract value, are energy procurement (hedging strategy) and supply cost efficiency.

Competition: Working, But Not for Passive Buyers

The CRU’s headline finding is measured: competition is generating “meaningful rivalry,” particularly in the domestic segment. Switching and tariff renegotiation rates are described as being at their highest ever and compare well to other EU member states. Market concentration has declined across most segments in recent years, which the regulator views as a positive trend.

For SMEs and business operators, however, the picture is less flattering. The report specifically notes there is room for improvement in switching rates in the business sectors. This is the operational implication for facility managers: the domestic market is increasingly competitive because domestic customers are switching. Business customers are switching less, and that passivity is costing money.

The CRU’s initial assessment of supplier profit margins does not indicate excess profitability or materially elevated returns sustained across the market. The report is direct that elevated retail prices have been driven primarily by wholesale costs, pass-through charges, network charges, and taxes, not by a broad competition failure.

Savings Are Real, But Only for Active Buyers

The report quantifies the gap between engaged and passive customers clearly. Active domestic customers can save an average of €395 on electricity and €184 on gas by switching or renegotiating their tariff. The report notes these savings can be higher still for customers on the highest standard rates in the market.

For non-domestic operators managing multiple sites, larger consumption profiles, or multi-year contracts, the equivalent savings opportunity is proportionally greater. The CRU flags that a range of different tariff types is now available in the electricity market, including time-of-use, day/night, and standard 24-hour tariffs, and that customers who engage can secure meaningful savings. Those who don’t engage remain on higher rates.

How Hedging Shapes the Prices You See

The report includes a detailed examination of hedging practices, which directly explains why retail prices don’t move in lockstep with wholesale market swings, and why your tariff renewal timing matters.

Suppliers can purchase electricity through several mechanisms: Contracts for Difference (CfDs), including baseload, mid-merit (typically 07:00–23:00), and peak (typically 17:00–21:00) products, Power Purchase Agreements (PPAs) over 10-to-20-year horizons with renewable generators, fuel hedges (gas futures and commodity swaps), and through vertical integration where a supplier’s own generation assets provide a natural internal hedge.

The CRU finds a close correlation between wholesale and retail electricity prices, but with a documented lag. When wholesale prices fall, that reduction does not pass through to retail immediately, because suppliers have already locked in forward prices. The reverse also applies: when wholesale prices spike, hedged suppliers can hold retail prices stable for longer. This lag reflects the risk-management function of hedging, which the CRU notes provides greater price stability for customers even at some cost in premium.

For business energy buyers, this is the mechanism that explains why switching immediately after a wholesale price drop may not deliver anticipated savings, and why the timing of contract renewal relative to a supplier’s hedge book matters more than the spot price on any given day.

Dynamic Tariffs Are Coming

The report briefly flags that dynamic tariffs are among the future market developments expected over the next twelve months. This is relevant for operators who have invested in flexibility assets, battery storage, demand-side management, EV charging infrastructure, or heat pumps, as dynamic pricing creates the conditions to monetise load shifting. Operators planning capital expenditure on building systems should factor this into their assessments now.

The report also notes the continued growth of microgeneration in the Irish market, linking to the SRESS scheme now supported through the PSO levy.

What It Means for Irish Operators

Several direct actions follow from this review for facility managers, school principals, and SME owners:

If you haven’t switched or renegotiated recently, you are almost certainly on a higher tariff than you need to be. The CRU quantifies the savings gap, and the report is explicit that passive customers are not capturing the benefits of competition. The business switching rate specifically is flagged as lagging.
Understand which parts of your bill are fixed before you negotiate. Network charges (DUoS, TUoS), the PSO levy, capacity charges, and VAT are identical for every supplier. Only the energy cost and supply cost elements are genuinely competitive. Knowing this prevents wasted negotiation effort on non-negotiable line items.
Hedging strategy is a supplier differentiator. When comparing offers, ask suppliers about their hedging position and how tariff certainty is structured over the contract term. A supplier with longer hedge cover may offer more price stability; one buying closer to real-time may offer lower rates when wholesale prices are falling.
Watch for dynamic tariff product launches over the next twelve months. If your site has any flexible load, that is the moment to act on a time-of-use or dynamic contract.
The full CRU review, including a customer survey and deeper margin analysis, is still to come. Further regulatory intervention or recommendations may follow later in 2026. Operators with active procurement decisions should monitor CRU publications and NEAT outputs through the winter planning cycle.

The CRU’s interim report does not recommend price controls or structural interventions at this stage. Its conclusion is that the market can work for operators who engage with it. The burden sits with buyers to act.