Physical risk strands assets by breaking them or uninsuring them — our companion guide covers that pathway. Transition risk strands them by arithmetic: a carbon price lands on the cost base, margins compress, and plant designed for a 30-year life stops clearing its hurdle rate in year eight. The forcing event for the next decade is the EU’s Carbon Border Adjustment Mechanism, whose definitive regime began on January 1, 2026 — and whose actual shape is widely misreported. CBAM is not a cliff. It is a ramp with published steps, and planning against the ramp rather than the headline is the difference between an orderly CapEx programme and a disorderly write-down.
CBAM: the ramp is the story
In 2026, almost nothing is charged — and that is precisely the trap. Importers of iron and steel, aluminium, cement, fertilisers, hydrogen and electricity into the EU must be authorised declarants, must measure embedded emissions, and accrue obligations from January 1, 2026. But under the simplification regulation, no certificates are sold during 2026 at all. The verified calendar:
| Date | What happens |
|---|---|
| Jan 1, 2026 | Definitive regime begins; obligations accrue; only 2.5% of embedded emissions are chargeable (the CBAM factor, mirroring 97.5% free ETS allocation) |
| 2026 prices | Certificate price = EU ETS quarterly average: €75.36/t (Q1 2026), €75.28/t (Q2 2026) |
| Feb 1, 2027 | Certificate sales open on the common platform; declarants buy against 2026 imports |
| Sep 30, 2027 | First annual declaration and surrender, covering 2026 imports |
| By 2030 | CBAM factor rises to 48.5% chargeable |
| Jan 1, 2034 | Factor reaches 100%; free allocation for CBAM sectors is gone |
Two consequences follow. First, the 2026 bill is small enough to breed complacency — at the Q2 price and the 2.5% factor, a tonne of blast-furnace steel carries a charge measured in single euros, against a gross figure above €100 at full coverage. The exposure is the curve, not the first step. Second, the binding constraint in 2026 is not money but data: verified embedded-emissions figures from non-EU producers, because default values are deliberately unattractive and the first declaration lands in September 2027. (Our Scope 3 supplier data guide covers the collection mechanics.) The same tightening runs through the EU ETS itself — the cap shrinks annually under the linear reduction factor (4.3% a year through 2027, 4.4% from 2028) — and beyond Europe: China’s national ETS, long confined to power, is extending to steel, cement and aluminium. Carbon cost curves for heavy industry are being rewritten in every major market at once.
What a carbon price does to a balance sheet
The sequence is mechanical: compliance cost compresses margin; compressed margin shortens economic life; shortened life forces the accounting to follow. Depreciation schedules built on 30-to-40-year lives get revised toward regulatory horizons, raising the annual charge. Cash-generating units that no longer clear recoverability tests take impairment charges (the IAS 36 / ASC 360 mechanics are set out in the companion guide). Credit assessments absorb the same facts — rating agencies now model transition vulnerability explicitly — and refinancing arrives on worse terms for unhedged carbon intensity, in a market that increasingly prices the exposure even where no regulator compels it. None of this requires a carbon price of $300. It requires a carbon price that is real, rising on a published schedule, and applied to a cost base that cannot move. Exposure differs sharply by sector:
| Sector | Assets most exposed | Principal triggers | Working horizon |
|---|---|---|---|
| Oil & gas | High-break-even reserves (oil sands, deepwater), unrefined midstream | Demand peak, engine phase-outs, methane regulation, low-cost displacement | 2026–2032 |
| Power & utilities | Unabated coal; gas peakers without capture | Clean-energy mandates, storage cost parity, intensity limits, merit-order displacement | 2026–2030 |
| Steel & metals | Blast furnace–BOF lines without capture | CBAM, green-steel procurement by automakers, scrap-EAF and DRI competition | 2027–2035 |
| Cement & materials | Wet-process kilns, high-clinker lines without capture or SCMs | Green public procurement, carbon costs in building codes, local caps | 2028–2035 |
| Chemicals & refining | Steam crackers, fuel-focused refineries | Circular-economy mandates, heat electrification, falling fuel demand | 2028–2035 |
The horizons are planning judgments, not predictions — but they are the right shape: power and upstream oil face the earliest tests; cement and chemicals get a longer runway because their abatement options are harder, not because their exposure is smaller.
Scenarios: use them as stress tests, not forecasts
The NGFS scenario families — Net Zero 2050 (orderly), Delayed Transition (disorderly), Current Policies (hot house) — are the standard grammar, and their carbon prices are the most misused numbers in the field. Scenario prices are model outputs: they differ by model, region and vintage, and any single band quoted without those qualifiers is decoration. Used properly, the scenarios answer a narrower question: does this CapEx book survive each path? In the orderly path, carbon costs rise early and predictably — transition impairment is structured, and replacement technology enjoys cheap capital. In the delayed path, the same costs arrive after 2030 in compressed form — the write-downs concentrate. In the current-policies path, transition pressure fades and physical risk does the damage instead. A capital plan that only works in one of the three is not a plan; it is a bet, and the board should hear it described that way.
The abatement menu, and how to order from it
Capital allocation committees rank options on a marginal abatement cost curve (MACC): cost per tonne avoided against volume available. The main industrial pathways, with indicative cost ranges as commonly assessed in the literature — treat them as orientation, not quotes:
| Pathway | Readiness | Indicative abatement cost | Reduction potential | Binding prerequisite |
|---|---|---|---|---|
| Green hydrogen (DRI steel, chemical feedstock) | Demonstration–early commercial | ~$120–220/tCO₂e | 85–95% of process emissions | Very cheap renewable power; electrolyser scale; H₂ transport |
| CCUS | Commercial for concentrated streams | ~$70–140/t (concentrated); higher when dilute | 80–90% of point-source emissions | Storage geology; shared CO₂ networks; liability rules |
| High-temperature electrification | Pilot–early commercial | ~$50–130/t | Up to ~100% of process-heat emissions | Grid capacity and reliability; electricity–gas price spread |
| Biomass / alternative fuels | Commercial | ~$40–90/t | 30–60% of thermal emissions | Certified sustainable supply; burner modification |
Below the line sit the negative-cost quick wins — waste-heat recovery, combustion tuning, steam and compressed-air leak programmes, variable-frequency drives — which pay back in cash and should never wait for a strategy process. The deep conversions (BF-BOF to hydrogen-ready DRI, kiln retrofits with capture, electric crackers) are the decisions the ramp actually governs: each has a lead time of years, which is why the 2034 full-coverage date is a present CapEx fact, not a future one.
Internal carbon pricing: the discipline that connects them
A shadow carbon price inside the investment model is what stops a plant that fails at €75/t from being approved at €0. Two design rules matter more than the level. First, anchor the schedule to prices the company already faces: a shadow price set below the EU ETS level (about €75/t in 2026) that CBAM and the ETS already impose is decoration. An illustrative rising schedule — starting near today’s ETS price, stepping up through the late 2020s as the CBAM factor climbs toward 48.5%, and reaching the low hundreds by the mid-2030s at full coverage — mirrors the company’s actual regulatory curve; each business should build its own from its own exposure. Second, distinguish the instruments: a shadow price only steers evaluation (it appears in NPV and hurdle tests, no cash moves), while an internal fee actually charges business units and funds abatement. Most heavy-industry programmes need the shadow price everywhere first; the fee is a later, harder governance step. IFRS S2 already asks companies to disclose whether and how internal carbon pricing is used in decision-making — the practice is becoming reportable, not merely virtuous.
Accounting and disclosure, briefly
The impairment mechanics live in the companion guide; the transition-specific adjustments are three. In value-in-use models: cash inflows fall (volume and margin under carbon cost), cash outflows rise (compliance purchases along the CBAM/ETS ramp), and terminal growth compresses toward zero for exposed assets. One discipline deserves emphasis because it is the standard’s own: IAS 36 requires risk to be reflected in the cash flows or the discount rate — adjusting both for the same transition risk double-counts it, and auditors increasingly probe exactly that. Useful lives and residual values must track the same story (a kiln retired in 2033 is not depreciated to 2055), and CGU boundaries may need redrawing where decarbonisation infrastructure is shared. On disclosure: IFRS S2 requires the CapEx deployed toward climate response and the internal-carbon-price position; ESRS E1 requires the transition plan itself, Taxonomy-aligned CapEx shares, and an analysis of locked-in emissions — whether today’s CapEx commits the company to tomorrow’s carbon costs. California’s regime adds the US layer (see the compliance playbook).
Ninety days, then ongoing
Days 1–30 — stranding audit and shadow price. Screen the PP&E register against the CBAM ramp, ETS exposure and the sector horizons above; adopt a shadow-price policy at every capital gate; re-test depreciation lives on the exposed CGUs. Days 31–60 — MACC and feasibility. Build the asset-level abatement curve; commission engineering feasibility on the top pathways; launch the negative-cost quick wins immediately. Days 61–90 — rationalise and finance. Decide the divest/convert/close list while the assets still have buyers; structure transition finance (ring-fenced transition bonds, sustainability-linked facilities, blended structures for first-of-a-kind plant) against the programme. Ongoing — stress and audit. Re-run the scenario tests quarterly against actual ETS/CBAM prices, fold climate-adjusted impairment into the internal audit cycle, and publish Taxonomy CapEx alignment annually. The deliverable rhythm matters more than any single artefact: transition risk moves on a regulatory calendar, and the finance function has to move on the same one.
Frequently asked questions
When do we actually pay for CBAM certificates?
Obligations accrue from January 1, 2026, but certificate sales open February 1, 2027, and the first surrender — with the first annual declaration — is due September 30, 2027, covering 2026 imports. Only 2.5% of embedded emissions are chargeable in 2026; the factor climbs to 48.5% by 2030 and 100% on January 1, 2034.
Does CBAM apply to a US exporter directly?
No. The authorised declarant — the EU importer — holds the obligation and buys the certificates. The cost and, more immediately, the verified-emissions data demands travel upstream to the producer. A US exporter experiences CBAM as its EU customers’ data requests and price negotiations.
What carbon price should our investment models use?
Not a forecast — a schedule. Anchor to prices already in force where you operate (the EU ETS has priced CBAM certificates at about €75/t through 2026), rise with the published CBAM factor steps, and stress the decision at higher levels under the delayed-transition scenario. A project that only survives at €0 carbon is the finding, whatever schedule you choose.
Is our existing plant automatically impaired once CBAM applies?
No. CBAM exposure is an impairment indicator prompting a test, as with the insurance shock in the companion guide. The outcome depends on the asset’s cash flows under the ramp — pass-through ability, abatement options and remaining life. Efficient producers inside a carbon-intensive sector can gain relative advantage as the factor rises.
Sources: Regulation (EU) 2023/956 (CBAM) as amended by Regulation (EU) 2025/2083 — definitive regime from Jan 1, 2026; certificate sales from Feb 1, 2027; first declaration Sep 30, 2027; CBAM factor 2.5% (2026) → 48.5% (2030) → 100% (2034); European Commission CBAM certificate prices Q1 2026 €75.36/t, Q2 2026 €75.28/t; EU ETS linear reduction factor (Directive (EU) 2023/959); NGFS scenario framework; IAS 36 (incl. the cash-flow/discount-rate double-counting caution) and IFRS S2 / ESRS E1 disclosure requirements. Abatement cost ranges are indicative spans from the published literature, not project estimates.