A utility reports emissions intensity of 0.41 tonnes per megawatt hour and sets a target to halve it. Both numbers are correct. Neither tells an investor whether the company plans to close a coal plant, buy more power on the wholesale market, or build generation, and those three routes to the same number have entirely different balance sheet consequences.
That is why this industry's disclosure topic does something unusual: it puts emissions and resource planning together.
Key points
- The industry topic couples greenhouse gas emissions with energy resource planning, so the generation mix and the transition plan are parts of the same disclosure.
- Scope 1 metrics matter less for a company that buys power than for one that generates it, and many utilities do both.
- The market-based and location-based question looks different from the seller's side: your contractual instruments become your customers' Scope 2.
- Asset retirement is where the transition plan meets the financial statements, and it is the part most first cycles leave to a narrative paragraph.
Emissions and planning in the same topic
Paragraph 32 of IFRS S2 requires an entity to refer to and consider the applicability of the industry-based metrics, which are derived from the SASB Standards and set out in Appendix B. Applying them is not a condition of stating compliance.
For electric utilities and power generators, the relevant topic is greenhouse gas emissions and energy resource planning, as a single topic rather than two.
That pairing is the most useful thing in the industry guidance, and it is easy to miss. In most industries emissions disclosure looks backwards and strategy looks forwards, and they are written by different people. Here they are the same subject. A utility's future emissions are almost entirely determined by what it generates with, and what it generates with is a capital allocation decision made years earlier.
So an intensity figure without the resource plan behind it is an incomplete disclosure, and a transition plan without the generation mix is an assertion.
Generating and buying are different businesses
SASB makes a point that reads as a technicality and is not. Metrics for direct Scope 1 emissions are less relevant to a power company that sources energy rather than generating it.
Take that seriously and the boundary question becomes obvious. A pure generator burns fuel and owns the resulting emissions. A pure retailer buys electricity and resells it, holding almost no Scope 1 at all, while being responsible for the emissions factor its customers apply to their own Scope 2.
Most real companies are somewhere in between, generating part of what they sell and buying the rest. When those are blended into one intensity figure, the number moves for reasons that have nothing to do with the plant. Buy more on the wholesale market in a wet year and your reported intensity improves without a single change to what you own.
Disclose generated and purchased volumes separately, and the figure becomes interpretable. Blend them and it does not.
Market-based accounting, seen from the seller
Location-based and market-based Scope 2 is usually explained from the buyer's side: you either take the grid average or you take the contracts you hold.
A generator sits on the other side of that transaction, and the view is different.
The instruments a utility sells, whether certificates, guarantees of origin or contractual supply, are precisely what its customers use to claim a market-based figure. The utility is manufacturing the evidence for somebody else's disclosure. That places a burden on the seller that has nothing to do with its own emissions: the attribute has to be tracked, retired correctly, and not sold twice.
It also creates a presentation trap. A utility that sells its renewable attributes and keeps the generation must reflect that in its own residual mix. Selling the certificate and also claiming the clean generation is double counting, and it is the kind of error an assurance provider is well placed to find, because the certificate registry is external evidence.
Sold electricity is not use of sold products
One more boundary point, because it is routinely got wrong by analogy with fossil fuels.
An oil and gas producer reports the combustion of what it sells as Scope 3, use of sold products, because the emissions happen later, in someone else's engine. Electricity does not work that way. The emissions from a megawatt hour happened at the point of generation, before it reached the customer. Using it releases nothing further.
So a utility's sold volume becomes its customers' Scope 2, not the utility's category 11. Adding a use-of-sold-products figure for electricity would double count emissions the company has already reported in its own Scope 1.
The metrics are being reworked
Worth knowing before you build a reporting process around the current set. The ISSB has an active standard-setting project on renewable energy in the Electric Utilities & Power Generators industry. It was opened because market feedback and research identified limitations in the existing renewable energy metrics under this topic, and its scope includes new or revised metrics for the energy transition and better international applicability.
This is separate from the review of the nine prioritised industries, which covers extractives and processed foods rather than utilities. Different project, same practical advice: keep the underlying generation and procurement records in a form that survives a change to the metric definitions.
Retirement is the part that reaches the accounts
A transition plan in this industry eventually names an asset and a date. That is where it stops being a sustainability narrative and starts touching the financial statements.
Bringing forward the retirement of a generating asset changes its useful life, which changes depreciation. It may trigger an impairment assessment. It affects decommissioning provisions and the discount unwinding on them. None of that is a climate disclosure question on its own, but all of it has to be consistent with what the climate disclosure says.
The failure mode is a plan that says one thing and a note that assumes another. Sustainability publishes a 2035 closure date while the fixed asset register still depreciates the plant to 2045. Both documents are internally consistent and they contradict each other, and that is exactly the sort of inconsistency a reviewer reading both is looking for.
What a utility has to be able to show
An assurance provider will pick a generating asset and a reporting period, and ask a short list of questions.
What was generated at this asset, from what fuel, on what meter, and does the volume reconcile to settlement data. What factor was applied, from which source and vintage. How much electricity was purchased rather than generated, and how was that separated in the intensity calculation. Which certificates or attributes were sold, and how were they removed from your own residual mix. And where the transition plan names this asset, what date does the fixed asset register use.
Generation volumes are usually the strongest record in the company, because they are settled and invoiced. The weak points are the last two. Attribute sales sit in a trading system that the reporting team may not have access to, and the link between a published retirement date and the accounting assumption is often held by nobody in particular.
Neither is a measurement gap. Both are places where two functions each hold half of a number and no record joins them, which is the recurring shape of a control weakness in climate disclosure.
Common questions
Does an electricity retailer report Scope 1 emissions?
Very little, if it generates nothing. Direct emissions metrics are less relevant to a company that sources power rather than generating it. Its disclosure centres instead on the mix it procures and the factor its customers rely on for their own Scope 2.
Should generated and purchased electricity be reported separately?
Reporting them separately makes the intensity figure interpretable. Blended, the number moves with procurement decisions and hydrology rather than with anything the company did to its plant.
Can a utility sell renewable certificates and still claim the clean generation?
No. If the attribute has been sold, it belongs to the buyer's market-based claim and must be removed from the seller's residual mix. Certificate registries are external evidence, which makes this straightforward to test.
How does a retirement date affect the financial statements?
Through useful life and depreciation, potentially impairment, and decommissioning provisions. A closure date in the transition plan should be consistent with the assumptions in the accounts, and a mismatch between the two is a common review finding.
Where do you stand against IFRS S2?
The readiness diagnostic covers governance, evidence and controls and names the gaps. The IFRS S2 reference sets out the standard itself, and the deadline checker gives the first reporting period for your market.