Electricity is a CBAM sector in its own right, but the rules here only bite if you physically move power across a wire into the EU grid — not if you simply use electricity to manufacture something else.

In this article:

• Why electricity is the one CBAM sector with its own, simpler rulebook
• The most common point of confusion: electricity as a good vs. electricity as an input
• How the emission factor is calculated, and why defaults are the norm, not the exception
• The five strict tests you’d need to pass to use actual emissions data instead
• A worked example that lands just under the qualifying threshold
• Who this genuinely affects — and who it doesn’t

Quick refresher for anyone new to this series: CBAM is the EU’s mechanism for making imported goods pay a carbon cost comparable to what EU factories already pay under the EU Emissions Trading System. Importers of covered goods buy CBAM certificates tied to embedded emissions, with real financial obligations underway from 2026. Full mechanics are in the first post in this series.

This post is different from the others in this series, and I want to say that plainly up front. Electricity is one of CBAM’s six sectors, but it’s the narrowest by far — it applies to a specific, physically-constrained transaction most businesses reading this blog will never do. If you’re an energy trader, grid operator, or utility with cross-border power flows, this is for you. If you simply buy electricity off the grid to run a factory, this post mostly isn’t — and here’s why.

The Distinction Everyone Gets Wrong First

CBAM deals with electricity in two completely different ways, and conflating them is the single most common mistake I see.

Indirect emissions is the concept used in every other CBAM sector — steel, aluminium, cement, fertilisers, hydrogen. It covers the electricity a factory consumes to make a covered good, no matter where that electricity came from. If you’re an EU importer of Indian steel, the power used to run the electric-arc furnace that made it counts toward that steel’s embedded emissions. We cover this in our sector-by-sector CBAM requirements overview.

This post is about something else: electricity as a CBAM good in its own right — power that physically crosses the EU border as a commodity, generated outside the EU and fed directly onto the EU grid through an interconnector. It’s listed in Annex II of the CBAM Regulation alongside the other five sectors, but it works nothing like them.

The practical difference: indirect-emissions rules apply globally, to any manufacturer anywhere. The direct-import rules covered here apply only where power can physically flow across a wire into the EU — which rules out almost everywhere except the EU’s immediate neighbours. And because the good here is electricity, there’s no indirect-emissions layer to calculate on top — only direct emissions from generating the power count, which simplifies the math considerably.

The Core Formula

The calculation for imported electricity is deliberately simple:

Em_el = E_el × EF_el

• Em_el = emissions related to the electricity, in tonnes of CO2
• E_el = the volume of electricity produced or imported, in megawatt-hours (MWh)
• EF_el = the emission factor applied, in tonnes CO2 per MWh

That’s it — volume times a factor. The question that matters is where that factor comes from, and that’s where electricity departs sharply from every other sector.

Why Defaults Come First Here — and Actual Data Is the Exception

Across the rest of CBAM, the system nudges everyone toward real, verified data and treats standardized defaults as a fallback of last resort. Electricity flips that logic entirely. The EU’s own guidance describes using a default value as the rule, and using actual, installation-specific emissions as “the exception.”

There’s a practical reason for the reversal. A steel mill or cement kiln is a fixed installation with a traceable production process — you can meter its fuel and attribute emissions to a batch of product. Electricity on an interconnected grid doesn’t work that way: once power from a coal plant, a gas plant, and a hydro dam all feed onto the same wires, there’s no physical way to trace which electrons crossing into the EU came from which source. A default-first system acknowledges that reality instead of pretending otherwise.

The emission factor is determined in a strict order of preference:

1. A country- or region-specific default value, set by the Commission using IEA data. The Commission can set these per country, per group of countries, or even for a region within one country — power markets don’t always follow national borders.
2. An EU-wide default value, used only if no country-specific figure exists yet.
3. An alternative (lower) default value, if a country submits credible evidence — by 30 June of a given year — that its actual emission factor is lower than the standard default. If accepted, the figure updates, based on a five-year weighted average across that country’s fossil generators.
4. Actual, installation-specific emissions — only if the exporting installation clears five simultaneous tests. This is the option most traders will never reach.

The Five Tests for Using Actual Data

To use real emissions instead of a default, an authorised CBAM declarant needs all five of the following to hold at once — not most, all.

A trader can use actual emissions data only if every one of five tests passes; missing any one sends the calculation back to default values.

Here’s what each test actually requires:

• A direct Power Purchase Agreement (PPA) between the authorised CBAM declarant and the specific electricity producer — not a generic “we buy from Country X” arrangement. If an intermediary is involved, it must be structured as one single contract linking all three parties, not a chain of separate deals.
• Grid connection without congestion. The installation must either connect directly to the EU transmission system, or the declarant must document — hourly, from the transmission operator — that there was no physical network congestion on the path to the EU at export time.
• A hard emissions cap: 550 grammes of CO2 per kWh. A ceiling on the producing installation’s carbon intensity, not a target. Emit more than that from fossil sources and actual-data treatment is off the table regardless of how good the rest of the paperwork is.
• Firm, hourly-matched interconnector nomination. The claimed volume must be firmly nominated to allocated interconnector capacity by every responsible transmission operator in the origin, transit, and destination countries, with nominated capacity and metered production matching within a window no longer than one hour — an extraordinarily tight bar compared to the annual reconciliation most manufactured-goods CBAM reporting uses.
• Monthly verified reporting, with an accredited verifier receiving at least monthly interim reports showing all four of the above are being met on an ongoing basis, not just at the point of one shipment.

Clearing all five at once, continuously, is a serious operational commitment — smart metering, verifier contracts, real-time TSO coordination, airtight paperwork. It’s why the Commission built the system to expect defaults as the normal case.

A Worked Example: How Close the 550 g/kWh Line Really Is

The official guidance walks through a hybrid installation with two generating blocks feeding the same connection: an older coal-fired baseload unit, and a newer natural-gas combined-heat-and-power (CHP) unit — a plant producing electricity and useful heat from the same fuel, where only the electricity-attributable share of emissions counts toward the power sold.

Converted to the units the cap is written in, that blended installation lands at 545 grammes of CO2 per kWh — just under the 550 g/kWh threshold. It’s a good illustration of how close to the line a real mixed-generation plant can sit, and how a small shift in dispatch mix or fuel efficiency could tip an otherwise-qualifying plant back onto default values entirely. For anyone on the trading or origination side of one of these deals, that 5-gramme margin is the difference between a verified actual-emissions calculation and a blanket default.

Who This Actually Affects

Here’s the part that matters most for most readers: electricity, unlike a manufactured good, cannot be shipped across an ocean. It can only physically flow from a grid that’s electrically wired into the EU’s transmission system. That single fact defines this sector’s real-world scope more than anything in the regulation’s text.

The EU’s guidance doesn’t publish an explicit list of relevant exporting countries, but the physical requirements make the universe self-evident and narrow. Direct interconnection to the EU’s synchronous grid (ENTSO-E), or a scheduled cross-border exchange arrangement, is a prerequisite just to attempt the actual-data tests — and even default-value imports only make commercial sense where power genuinely flows.

Where this is genuinely relevant: the Western Balkans / Energy Community countries (Serbia, Bosnia and Herzegovina, North Macedonia, Montenegro, Albania), long integrated into the European grid; Ukraine and Moldova, synchronised with the Continental European grid since 2022; Norway and Switzerland, which also carry a separate EFTA-linked carve-out from CBAM more broadly (covered in our intro post); and the United Kingdom and Turkey, both directly interconnected into the EU grid.

Where it is not relevant, and I want to be direct about this: if your business operates in the United States, India, the Middle East, or Japan, the electricity-as-a-good provisions in this post essentially do not apply to you — there’s no physical wire connecting those grids to Europe’s. That’s genuinely different from our sector posts on CBAM’s impact on US, Indian, or Middle East businesses, where indirect-emissions rules on electricity used in manufacturing apply globally regardless of geography. Don’t let this post’s title suggest CBAM has newly reached into distant power markets — it hasn’t. What has reached those markets is the indirect-emissions treatment of electricity used to make steel, aluminium, fertiliser, and hydrogen, a wholly separate topic from this one.

One Rule Change to Watch

A proposal the European Commission put forward in December 2025 to amend the CBAM Regulation — expanding scope to certain downstream goods and adding anti-circumvention measures — includes proposed changes specifically to how electricity is treated under CBAM. That process is still ongoing, and current sector guidance doesn’t yet reflect it. If you’re genuinely affected by this sector, treat the current rulebook as a moving target, not a fixed one — we’ll update this post as the amended rules take shape.

How Sprih Helps

Electricity is a narrow slice of CBAM, but for the traders, utilities, and grid operators it does apply to, it’s an unusually demanding one — hourly-matched interconnector data, monthly verifier reporting, and PPA paperwork stacked on top of a hard 550 g/kWh cutoff that a plant can slip past with almost no warning. Getting this right means treating it as a live data pipeline, not a once-a-year filing exercise.

That’s consistent with how we think about CBAM generally at Sprih. Our SustainSense platform indexes sustainability and emissions data across more than 120,000 companies and 400,000 reports, giving teams a faster way to find and organize the supplier- and installation-level data that CBAM calculations depend on. We’re also building CBAM-specific tooling to help importers and their upstream partners calculate and manage embedded-emissions data directly, rather than defaulting to conservative fallback values by default.

Whether your CBAM exposure runs through a factory’s supply chain or through a cross-border power contract, the underlying challenge is the same: turning scattered emissions data into something you can act on with confidence. Sprih is an AI-native sustainability intelligence company helping enterprises turn climate and compliance data into competitive advantage.