Scope: This assessment examines the proposed relaxation of EU ETS heat and fuel benchmarks for 2026–2030, its implications for European industrial competitiveness and decarbonisation, and the decisions affecting investment through 2031.

Executive Summary

Increasing free allocation can reduce industrial compliance costs without, by itself, increasing the ETS emissions cap. Its effectiveness depends on which installations receive support, what investment follows, and which alternative uses of the allowances are displaced.

The official record requires a qualification to the starting premise: the parliamentary procedure retrieved for this assessment records the committee report of 19 October and still identifies Parliament’s first-reading position as pending. The reported plenary approval could not be independently confirmed from an accessible adopted text. Parliamentary endorsement must also be distinguished from final legislation and revised installation allocations. European Parliament

The Commission’s July proposal envisaged approximately 80 million additional allowances; the Council’s September position identified 88 million available allowances plus another 33 million, implying approximately 121 million under its preferred approach. These are different legislative versions, not interchangeable estimates of an enacted settlement. climate.ec.europa.eu

The principal beneficiaries would be eligible heat- and fuel-benchmark sub-installations, rather than European manufacturing uniformly. The decisive uncertainty is whether relief finances industrial transformation or prolongs dependence on production methods whose competitiveness remains vulnerable after 2030.

Undersea Drone Fleets: China and the Global Race for Maritime Persistence

Europe’s Industrial Relief Must Buy More Than Time

Europe’s proposed relaxation of industrial carbon benchmarks will protect competitiveness only if the allowances preserve viable production while financing its replacement with cleaner processes. Otherwise, the EU will have transferred a valuable public resource to incumbent operators while weakening the investment system intended to secure their future. The revision of heat and fuel benchmarks under the EU Emissions Trading System addresses a real mismatch: compliance costs arrive before electricity connections, new equipment and shared infrastructure are ready. Yet free allowances can finance either transformation or delay. The decision therefore concerns more than industrial relief. It determines how Europe divides the value of carbon scarcity between operating support today, investment tomorrow and the public infrastructure needed to make that investment competitive.

Relief changes who pays before it changes what industry produces

Under the EU Emissions Trading System, an additional free allowance reduces the recipient’s need to purchase a compliance asset. It does not establish that production becomes cleaner, that an investment proceeds or that a threatened installation remains open. Those outcomes depend on the constraint facing the operator. Where finance is scarce, relief can help a viable project reach execution. Where the obstacle is an unavailable grid connection, the same relief can keep production operating but cannot remove the obstacle.

The economic distinction matters because free allocation under the EU Emissions Trading System retains a carbon incentive only to the extent that avoiding emissions remains valuable. A company can benefit from retaining an allowance it no longer needs to surrender. But if changing its process also reduces its allocation entitlement, part of that benefit disappears. The investment comparison must therefore examine the cleaner process and the supported incumbent process together. Measuring the additional allocation alone reveals the transfer, not the direction of technological change.

The headline billions conceal competing claims

The Council’s position of 16 September 2026 identifies approximately 88 million available allowances and cites a Commission estimate of around €6 billion in industrial cost savings. That figure describes expected relief for recipients. It is neither a cash appropriation nor sufficient evidence of an equivalent loss to national treasuries. Establishing the public cost requires tracing what would otherwise have happened to the same allowances.

The wider financial stakes are substantial. EU Emissions Trading System auctions raised more than €43 billion in 2025, with approximately €24 billion directly benefiting Member States. In its September negotiating mandate, the Council also proposed using an estimated 33 million conditionality-related allowances for the benchmark adjustment. The existing legislative framework assigns residual allowances from that mechanism to innovation support and national auctioning after the relevant protection against the cross-sectoral adjustment. Redirecting them therefore changes the beneficiaries of a resource that already has alternative uses.

Those uses are industrial policy in their own right. On 19 October 2026, the Commission selected 77 projects across 23 European Economic Area countries for approximately €3.4 billion of Innovation Fund support. The projects entered grant-agreement preparation; selection was not payment or commissioning. The distinction exposes the fiscal choice: immediate relief has a visible recipient, while the cost of reduced investment capacity emerges through fewer projects, delayed contracts or weaker future funding rounds.

An allowance cannot build a grid connection

The EU Emissions Trading System benchmark revision is strongest where it bridges a documented interval between an installation’s present costs and an executable transition. A plant awaiting contracted electricity capacity faces a different problem from a plant with no developed replacement project. Both may benefit from free allocation, but only the former offers a clear account of what the support is buying and when the temporary constraint should end.

The planned IF26 industrial heat auction provides a complementary mechanism. Its published terms connect a fixed premium to direct carbon dioxide emissions abated, making the payment depend on a defined performance outcome. Free allocation supports an operator’s capacity to continue; an abatement premium supports the economics of changing production. Capital grants and shared infrastructure address other parts of the same investment decision. Treating these instruments as interchangeable would leave the binding constraint unresolved.

The Modernisation Fund illustrates why infrastructure finance also has a geographical consequence. Its support for energy networks, efficiency and cleaner energy systems helps eligible Member States improve the conditions in which industrial investment takes place. If public resources shift towards operating relief without accounting for those needs, Europe risks preserving existing assets while leaving their future electricity and infrastructure costs intact. That would protect the current production model more effectively than the next one.

An unchanged cap does not settle the supply question

The Commission’s original benchmark proposal states that the additional allocation has no further implications for its budget because the allowances’ financial value is not attributed to that budget. The statement answers an accounting question. It does not answer whether redirecting the allowances displaces an auction, reduces innovation resources or changes future availability. “No additional Commission budget expenditure” and “no economic opportunity cost” are different conclusions.

The EU Emissions Trading System also separates initial allocation from ultimate use. An allowance can replace a purchase, be sold or remain banked. If free allocation substitutes for an auction in the same period, the initial number of available units need not change. If previously unavailable units become usable, effective supply can increase. The legal origin and timing of the allowances therefore matter more than the word “free”.

The provisional Market Stability Reserve agreement reached on 20 October 2026 adds another constraint to the assessment. By allowing more allowances to remain valid in the reserve rather than be invalidated, it changes potential future availability without itself creating an immediate industrial allocation. The agreement still requires formal adoption. Its interaction with benchmark relief must be assessed against a common counterfactual; otherwise, separate measures can each appear limited while their combined effect on expected scarcity goes unexamined.

Europe must distinguish cleaner production from displaced production

The Commission’s April 2026 assessment attributes the decline in energy-intensive industrial emissions partly to weaker activity and partly to transformation. That distinction should govern the evaluation of the benchmark revision. Lower territorial emissions are not sufficient evidence that Europe’s production system has improved. They can also reflect contraction, while the goods consumed in Europe are manufactured elsewhere.

The Carbon Border Adjustment Mechanism addresses the competitive interface between covered European production and imports, but it cannot resolve every investment constraint inside the EU. A border instrument cannot supply an electricity connection, complete shared infrastructure or finance equipment delivery. Nor does support at an installation establish that the resulting production will be competitive in external markets. The relevant test combines product-level trade exposure with the actual cost and emissions trajectory of the supported plant.

Monitoring under the EU Emissions Trading System should consequently connect physical output, comparable emissions intensity, imports, exports and investment execution. None is decisive alone. Rising imports can have several causes; falling emissions can accompany either efficiency or closure. The policy succeeds when viable European production becomes cleaner and remains competitive. It fails when apparent environmental progress conceals displacement, or when industrial retention depends on recurring concessions without an executable transition.

The next allocation cycle will reveal who bought time—and who used it

Over the next 12–24 months, implementation of the EU Emissions Trading System revision should produce evidence stronger than corporate intentions. Authorities should reconcile actual transfers with the final legal envelope and its alternative destinations. Recipients’ transition claims should be tested against financing closure, equipment orders, construction and credible infrastructure dates. Innovation Fund awards should be followed through contracting and delivery. These records will show whether relief advances investment or merely improves the economics of waiting.

If that scrutiny fails, the cost will fall on manufacturers still awaiting infrastructure, cleaner projects competing for public finance and workers whose plants remain dependent on temporary support. The EU Emissions Trading System can give industry time, but time has value only when the constraint is being removed. Europe’s settlement will be judged by the productive assets it brings into operation, not by the compliance assets it distributes.

Italy’s Carbon-Industrial Exposure After the 2025 Emissions Print: ETS – ETS2 – CBAM – Power Prices and the Hard-to-Abate Base

---

Navigational Index

Pillar I — The Regulatory Settlement and the Allocation Mechanism

• Chapter 1 — What Has Changed: Legislative Status, Benchmark Values and Implementation
• Chapter 2 — Who Receives the Allowances: Efficiency, Eligibility and Distribution
• Chapter 3 — Carbon Leakage and CBAM: Complementarity, Overlap and Remaining Gaps

Pillar II — Industrial Competitiveness and European Economic Geography

• Chapter 4 — Germany and the Benelux: Integrated Industrial Systems and Uneven Relief
• Chapter 5 — Italy and France: Manufacturing Exposure and Investment Choices
• Chapter 6 — The United Kingdom and Non-EU Competitors: Carbon Costs, Trade and Location

Pillar III — Market Integrity, Public Resources and Strategic Choices

• Chapter 7 — Allowance Supply, Carbon Prices, Auction Revenues and Transition Funds
• Chapter 8 — Decarbonisation Pathways and the Integrity of the 2030 Settlement
• Chapter 9 — Policy Options, Monitoring Indicators and Final Strategic Assessment

---

Russia–Brazil: Strategic Reach Meets Structural Limits

Master Abstract

A change in the distribution of carbon costs

The central policy question is whether additional free allowances preserve the productive capacity needed for Europe’s industrial transition while maintaining credible incentives to reduce emissions. An installation can remain legally obliged to surrender allowances for its verified emissions while receiving more of those allowances without payment. Its immediate cash requirement falls, but emissions continue to consume an asset with a market value. Consequently, the measure’s industrial effect is more direct than its environmental effect: it changes the distribution of compliance costs immediately, while its influence on investment and emissions depends on allocation rules, expectations and access to alternatives.

The architecture also matters. The ETS uses 52 product benchmarks and two fallback benchmarks for heat and fuel. Product benchmarks refer to the average performance of the best-performing 10% of relevant installations. Fallback approaches apply where a product benchmark is unavailable. The proposed intervention therefore addresses a particular allocation mechanism; it does not establish a new entitlement for every energy-intensive company. Allocation to industrial installations — European Commission — undated, accessed 22 October 2026. Climate Action

The distributional implication is substantial. Two neighbouring plants can face similar energy prices and international competition yet receive different relief because their production processes fall under different benchmark categories. A country’s manufacturing value added, aggregate industrial emissions or existing total allocation cannot establish its share of the proposed increase.

The baseline is a sharp benchmark reduction

The June benchmark settlement provides the relevant counterfactual. The Dutch Emissions Authority publishes heat and fuel benchmark values of 31.2 and 28.1 allowances per terajoule, respectively, for 2026–2030, approximately 34% below the preceding allocation period. Its explanation also identifies changes that recognise electricity-generated heat and heat integration in activity levels. These provisions matter because the environmental incentive cannot be assessed from the benchmark coefficient alone. Toewijzing gratis emissierechten voor periode 2026–2030 — Nederlandse Emissieautoriteit — July 2026. Nederlandse Emissieautoriteit

The Council’s negotiating mandate envisages indicative average heat and fuel benchmarks of 43.0 and 38.7 allowances/TJ, using its larger allowance envelope. Relative to the published June values, these represent calculated increases of approximately 37.8% and 37.7%. They remain indicative negotiating parameters rather than final coefficients applicable to every installation and year. The same mandate preserves the objective of avoiding a cross-sectoral correction that would reduce allocations elsewhere. Mandate for negotiations with the European Parliament, ST 13134/26 — Council of the European Union — September 2026, recital 2. data.consilium.europa.eu

Relief must therefore be measured against two baselines. Compared with June 2026, allocation would rise. Compared with 2021–2025, the proposed benchmark averages could still represent tightening. Describing the proposal simply as an increase or a reversal obscures that distinction.

The volume increase can be quantified more reliably than national benefits

A Commission presentation accompanying the July package illustrated approximately 330 million fallback-related allowances before adjustment and 410 million afterwards across 2026–2030: an increase of approximately 24.2%, calculated from those published inputs. Its indicative implementation profile concentrated additional support in 2027 to account for 2026, followed by higher allocation in 2028–2030. This is evidence of the Commission proposal’s expected scale and timing; it is not a final distribution schedule for the subsequent 88-million or Council 121-million variants. ETS Review Package: Commission presentation, WK 10833/2026 — Council repository — July 2026, slides 67–69. data.consilium.europa.eu

The retrieved record does not establish a verified division of the increase between heat and fuel, or between Member States. Producing such estimates requires eligible activity levels by sub-installation, benchmark coefficients by year, carbon-leakage and CBAM factors, conditionality adjustments, and the treatment of excluded activities. Applying national manufacturing shares to the aggregate envelope would produce an unsupported allocation model.

There is nevertheless a clear basis for prioritising scrutiny: industrial operations with substantial eligible process-heat or fuel activity, high exposure to internationally traded products, and limited near-term substitution possibilities. Sector names alone remain insufficient because product benchmarks cover important portions of chemicals, paper, glass, metals and mineral products.

Best-performer benchmarking does not restrict relief to the best performers

The top-10% principle determines a reference level; it does not mean that only the most efficient tenth receives allowances. A less efficient installation can receive benchmark-based allocation and purchase allowances for the remaining emissions. Raising the coefficient therefore benefits eligible inefficient installations as well as efficient ones, subject to the other allocation rules.

The economic distinction is between the reward for reducing emissions and the support attached to maintaining eligible activity. If an installation reduces emissions while its allocation remains unchanged, it saves allowances that it can retain or sell. That incentive survives free allocation. If allocation adjusts with activity, however, the system also supports continued production. Under heat- and fuel-based approaches, investment appraisal must additionally consider whether an efficiency improvement changes measured eligible activity and how the applicable efficiency safeguards operate. The French administration’s allocation guidance explicitly distinguishes activity adjustments and decisions concerning energy efficiency for heat and fuel sub-installations. Marchés du carbone — SEQE-UE Installations — French Ministry for Ecological Transition — undated, accessed 22 October 2026. ecologie.gouv.fr

The strategic trade-off follows. Relaxation can correct a benchmark that advances faster than feasible investment in particular processes. It can also weaken the commercial advantage of plants that have already invested. Authorities should distinguish demonstrated technical constraints from commercial preferences for extending existing assets.

CBAM leaves several competitiveness problems unresolved

CBAM entered its definitive regime on 1 January 2026 and covers selected goods in cement, iron and steel, aluminium, fertilisers, electricity and hydrogen. Its protection follows the goods and emissions within its legal scope, rather than all production undertaken by companies in those sectors. Carbon Border Adjustment Mechanism — European Commission — undated, accessed 22 October 2026. Taxation and Customs Union

This creates three different competitive situations. Producers of covered goods selling within the EU receive a border instrument intended to address differences in carbon costs. Producers of uncovered goods retain exposure to imports without equivalent CBAM coverage. European exporters also compete in third-country markets where the EU’s import adjustment does not directly protect their sales. Additional free allocation can address parts of these residual exposures, but it cannot resolve differences in energy prices, financing costs, infrastructure or foreign industrial support.

The relevant legal timelines must remain separate. Fit-for-55 established the phase-out of free allocation for CBAM sectors through 2034. The broader 2026 ETS revision proposes extending the transition to 2038; the Council’s September discussion paper describes that as a proposal. It should not be attributed to the standalone heat-and-fuel adjustment or presented as settled law. ETS 1 Revision: Policy debate, ST 13435/26 — Council of the European Union — September 2026, section a(iv). data.consilium.europa.eu

Germany, Italy, France and the Benelux require different tests

Germany’s assessment should focus on whether relief retains viable industrial activity and the connected demand for suppliers, industrial services and shared utilities. Support to an eligible heat-intensive operation can have consequences beyond its own emissions account. Conversely, large industrial emissions do not necessarily imply a large benefit from this particular revision: a substantial part of an installation’s allocation may follow product benchmarks. The policy test is therefore the allocation increase relative to the plant’s uncovered carbon costs and the investment required to remain competitive.

Italy’s assessment should distinguish the direct position of eligible thermal processes from the wider competitiveness of manufacturing exporters. Where relevant ceramics, food processing, paper or specialised manufacturing activities rely on fallback allocation, relief can improve liquidity. Yet no conclusion about an entire Italian sector follows without separating its product-benchmark and fallback components. The key investment question is whether the additional allocation helps finance efficiency, electrification and process renewal before the next tightening period.

France’s assessment should connect temporary relief with industrial transformation programmes. The government’s published industrial decarbonisation framework identifies electrification, carbon capture, low-carbon hydrogen and biomass, alongside coordination at industrial-zone level. Extra allowances could ease the transition while those investments develop, but repeated relief could also reduce the urgency of replacing fossil heat where alternatives are feasible. Transition écologique : une planification pour accélérer la décarbonation des sites industriels — French Ministry of Economy — undated, accessed 22 October 2026. economie.gouv.fr

Belgium and the Netherlands require close examination of the allocation boundaries within interconnected industrial operations. Heat suppliers, heat consumers and installations using different benchmarks may experience different benefits. In the Netherlands, a further interaction arises because the national industrial CO₂ levy uses benchmark-linked dispensation rights, alongside national adjustment factors. EU-level relief therefore cannot automatically be equated with the final change in an installation’s combined carbon burden. Luxembourg likewise requires a separate installation-level assessment rather than an assumed share of a Benelux aggregate. Berekening aantal dispensatierechten — Nederlandse Emissieautoriteit — undated, accessed 22 October 2026. Nederlandse Emissieautoriteit

These are analytical priorities, not a verified ranking of national beneficiaries. A defensible ranking requires the revised allocation tables.

The United Kingdom is a distinct comparator

The United Kingdom operates a separate ETS, and its government’s published overview describes negotiations to link the UK and EU systems. It also records the shift of the next UK free-allocation period to 2027. Those negotiations cannot be treated as a completed link or an automatic exemption from border obligations. UK Emissions Trading Scheme: a policy overview — UK Government — undated, accessed 22 October 2026. GOV.UK

For investment decisions, the relevant comparison is the expected combined burden of carbon pricing, free allocation, border requirements and energy costs over the asset’s operating life. The same logic applies to other non-EU producers. Being outside the EU ETS does not establish that a competitor faces no carbon cost. Nor does the presence of a foreign carbon-pricing system establish an equivalent effective burden. Comparisons must account for coverage, allocation, compensation and the carbon price effectively paid.

A temporary European allocation increase is most consequential where it changes the viability of retaining and renewing a plant. It is less likely to determine location where a persistent energy or infrastructure disadvantage dominates operating economics.

The allowance value is substantial; the fiscal loss is conditional

At assumed prices of €50, €75 and €100 per allowance, an 88-million envelope has a gross market value of €4.4 billion, €6.6 billion and €8.8 billion. These are calculated sensitivities, not current price observations or forecasts. The Council attributes an approximately €6 billion industrial saving to Commission estimates, equivalent arithmetically to approximately €68.18 per allowance for an 88-million envelope. That valuation does not establish realised savings or an identical public-revenue loss. ETS: Council agrees targeted measure to protect energy-intensive sectors from carbon leakage — Council of the European Union — September 2026. Consilium

Three effects must be separated. Allocating allowances that otherwise would have been auctioned changes who receives their initial value. Bringing otherwise unavailable allowances into circulation can change effective supply. Changing expected future policy can influence prices before transfers occur. Consequently, neither “88 million free allowances” nor reduced industrial purchasing establishes a mechanical price decline of any particular size.

The funds introduce an additional opportunity cost. The Innovation Fund is financed through allowance monetisation, so its resources depend partly on carbon prices. The Modernisation Fund also relies on auction proceeds. Direct diversion of units and indirect price effects must be assessed separately; neither fund should be assumed to lose the entire gross value of the industrial package. What is the Innovation Fund? — European Commission — undated, accessed 22 October 2026; Modernisation Fund — European Commission — undated, accessed 22 October 2026. European Commission

Climate integrity depends on investment as well as the cap

The EU’s economy-wide 2030 objective remains a reduction in net greenhouse-gas emissions of at least 55% against 1990. That target is broader than the ETS and cannot be evaluated solely through the allocation of industrial allowances. European Climate Law — European Commission — undated, accessed 22 October 2026. European Commission

An unchanged cap constrains aggregate allowance issuance, but it does not establish that every distributional adjustment is environmentally neutral. Allocation can affect production, banking, investment timing and the political credibility of future scarcity. Relief could accelerate decarbonisation where it preserves financially constrained plants capable of investing, especially when clean electricity, grid connections and process alternatives become available. It could slow it where companies expect repeated relaxation, postpone replacement decisions or commit to further fossil-dependent capital expenditure.

The appropriate assessment therefore combines production retention with emissions intensity and executed investment. Falling European emissions caused by contraction and replacement imports would be a poor industrial outcome. Stable production accompanied by persistent emissions intensity and deferred investment would indicate protection without sufficient transformation.

Key Evidence Table

Indicator	Value/status	Reference date	Definition/scope	Issuer	Exact source
Legislative procedure	Committee report tabled; retrieved record still pending Parliament’s first-reading position	19–22 October 2026	Procedure 2026/0211(COD); does not independently confirm the reported plenary outcome	European Parliament	Legislative Observatory
June heat benchmark	31.2 allowances/TJ	2026–2030	Published baseline before proposed relaxation	Dutch Emissions Authority	Benchmark tables
June fuel benchmark	28.1 allowances/TJ	2026–2030	Published baseline before proposed relaxation	Dutch Emissions Authority	Benchmark tables
Commission proposal	Approximately 80 million additional allowances	July 2026	Original proposed envelope	European Commission	COM(2026) 619 final
Council position	Approximately 88 million plus 33 million	September 2026	Negotiating position; approximately 121 million combined	Council of the EU	ST 13134/26, recital 2
Council indicative averages	Heat 43.0; fuel 38.7 allowances/TJ	September 2026	Indicative period averages under the Council approach	Council of the EU	ST 13134/26, recital 2
CBAM transition extension	2038 proposed, compared with the Fit-for-55 endpoint of 2034	September 2026	Separate broader ETS revision; proposed status	Council Presidency	ST 13435/26, section a(iv)

The baseline, proposal and negotiating figures above describe different legal stages. Their supporting records were opened during this assessment. European Parliament

Calculated valuation sensitivity

Assumed allowance price	Gross value of 88 million allowances	Gross value of 121 million allowances
€50	€4.40 billion	€6.05 billion
€75	€6.60 billion	€9.08 billion
€100	€8.80 billion	€12.10 billion

Calculation: allowance volume × assumed price, rounded to two decimal places. Values are undiscounted illustrative totals across the envelope, not annual benefits, price forecasts or estimates of foregone auction revenue.

Competing Pathways

These pathways can coexist across installations; they are not assigned numerical probabilities.

Pathway	Economic mechanism	Evidence that would support it	Evidence that would weaken it
Relief enables transformation	Lower compliance expenditure releases finance for viable decarbonisation projects	Retained output, executed investment, falling emissions per unit of production	Additional allocation rises while investment repeatedly slips
Relief preserves production but delays renewal	Support improves existing operations more than replacement technologies	Capacity remains active; emissions intensity changes little; fossil-dependent reinvestment continues	Clean-process commissioning and sustained intensity reductions
Relief cannot offset structural disadvantages	Energy, infrastructure or market conditions dominate the allocation benefit	Closures, declining utilisation or relocation despite increased allocation	Renewed EU investment after accounting for other subsidies and market recovery

The decision-relevant comparison is between the value transferred and the change in industrial behaviour. Allocation received is an implementation measure; productive capacity retained and transformed is the intended outcome.

Principal Gaps and Watch Indicators

Consequential gap or indicator	Record or observation required	Decision significance
Exact parliamentary outcome and final settlement	Adopted plenary text, negotiated agreement and Official Journal publication	Establishes the final envelope, conditions and implementation dates
Heat/fuel and national distribution	Revised Commission allocation decisions and national tables, reconciled by sub-installation	Identifies actual beneficiaries and avoids unsupported country rankings
Counterfactual use of allowances	Reconciliation of free-allocation buffers, auction schedules, conditionality-related units and fund transfers	Separates industrial benefit from foregone public revenue and effective supply changes
Production retention	Physical output, capacity utilisation and verified activity reports	Distinguishes competitiveness gains from support to contracting operations
Emissions performance	Verified emissions divided by comparable physical output	Separates technical improvement from production decline
Investment execution	Final investment decisions, expenditure, construction and commissioning	Tests whether relief supports transformation
Carbon leakage	Product-level imports, exports, production changes and investment location	Tests whether activity is being displaced outside the EU
Market and fund effects	Auction prices and volumes, circulation and banking data, fund monetisation proceeds	Tests supply effects and the financing consequences for transition programmes
CBAM effectiveness	Verified embedded emissions, free-allocation adjustments and compliance findings	Tests whether imported and EU goods face appropriately comparable carbon obligations

A review should be triggered when additional allocation is accompanied by repeated investment delays or continued production decline without measurable improvement in emissions intensity. Such a pattern would warrant examination of eligibility, investment barriers and policy design before a further extension. Conversely, retained output, commissioned clean processes and declining intensity would support the case that temporary protection is facilitating transformation.

Policy Transmission Scheme

The following component separates the three channels authorities must assess. It is qualitative; it contains no modelled price or emissions forecast.

---

Pillar I — The Regulatory Settlement and the Allocation Mechanism

Chapter 1 — What Has Changed: Legislative Status, Benchmark Values and Implementation

The proposed revision changes the amount of carbon-cost protection available to eligible industrial activities, but its practical significance depends on a sequence of legal and administrative decisions. A political agreement on additional allowances does not, by itself, determine an installation’s revised entitlement, the year in which it receives the allowances or the corresponding adjustment applied to competing imports. For governments and industrial operators, the immediate requirement is therefore to distinguish the legislative mandate, the benchmark coefficients and the allocation decisions that turn those coefficients into transferable assets.

The legal change concerns the speed of benchmark tightening

The intervention operates through Article 10a of the ETS Directive. The Commission proposed a derogation allowing the maximum annual reduction rate applied to heat and fuel benchmarks to be lowered sufficiently to use the available allocation envelope without triggering a cross-sectoral correction. Its proposal retains the underlying reference periods and dataset. It also requires subsequent changes to the benchmark implementing regulation and the decisions determining allocation amounts. These implementation steps matter because the legislative amendment establishes the authority to increase allocation; it does not complete the installation-level calculation. See COM(2026) 619 final — European Commission — July 2026, explanatory memorandum and proposed Article 10a(2a). climate.ec.europa.eu

This distinction also defines the limits of the measure. An increase in allocation calculated through fallback benchmarks does not automatically revise product benchmarks, remove the surrender obligation, reimburse all industrial energy costs or establish a general entitlement for manufacturing. The economic effect follows the eligible activities identified within each installation.

The institutional record requires equal precision. The parliamentary procedure retrieved on 22 October records the committee report tabled on 19 October and still displays the status “Awaiting Parliament’s position in 1st reading”. That record may lag parliamentary events; it is not evidence that a scheduled vote failed to occur. However, without an accessible adopted plenary text, the exact parliamentary amendments cannot be treated as independently verified. The controlling distinction remains between a parliamentary position and a final legislative act agreed with the Council. See EU Emissions Trading System: heat and fuel benchmark values for 2026–2030, procedure 2026/0211(COD) — European Parliament — accessed October 2026. European Parliament

Table 1.1 — The decisions between political endorsement and industrial relief

Stage	What it establishes	What remains unresolved at that stage	Decision consequence
Commission legislative proposal	Proposed legal authority, scope and adjustment mechanism	Final wording and allowance envelope	Basis for negotiation
Parliament’s position	Parliament’s preferred amendments or endorsement	Agreement with the Council	Does not alone establish final entitlements
Council negotiating mandate	Member States’ negotiating position	Interinstitutional settlement	Defines the Council’s preferred envelope and safeguards
Final legislative act	Binding amendment and implementation authority	Detailed recalculation where further acts are required	Establishes the legal basis for revised treatment
Revised benchmark implementing act	Applicable benchmark coefficients and temporal treatment	Installation-specific results	Enables consistent recalculation
Revised allocation decisions and national tables	Approved allocation amounts	Annual adjustments, conditions and transfers	Determines the administrative entitlement
Registry transfer	Delivery of allowances to the operator’s account	Subsequent compliance, trading or banking decisions	Makes the asset available to the operator

The sequence reflects the implementation architecture described in COM(2026) 619 final — European Commission — July 2026 and the subsequent steps presented in ETS Review Package: Commission presentation, WK 10833/2026 — Council repository — July 2026, slides 65–69. climate.ec.europa.eu

Two different historical datasets answer two different questions

Benchmark construction and installation allocation use historical information for different purposes. The benchmark asks what emissions performance should define the allocation reference. The historical activity level asks how much eligible activity an installation has undertaken. Confusing the two can produce a technically plausible calculation with the wrong denominator.

For the 2026–2030 update, the benchmark exercise uses performance information for 2021–2022. For incumbents, the default historical activity calculation generally uses the median annual activity over 2019–2023, subject to provisions for installations or sub-installations that did not operate throughout the baseline. The Commission’s installation-level guidance explains the latter calculation in Section 6. See Guidance Document No. 2: Guidance on determining the allocation at installation level — European Commission, DG CLIMA — February 2024, Section 6. climate.ec.europa.eu

Table 1.2 — The principal time references in the allocation calculation

Element	Relevant period or date	Function	Error to avoid
Benchmark performance data	2021–2022	Establishes performance used in updating benchmark values	Treating this as the installation’s full activity baseline
Default incumbent activity baseline	2019–2023	Establishes median eligible activity	Treating the median as current-year output
Allocation period	2026–2030	Defines the period covered by the allocation exercise	Assuming every year must have an identical coefficient or entitlement
Proposed adjustment implementation	From 2027, with treatment of 2026 incorporated into the adjustment	Delivers additional protection while avoiding a separate retrospective transfer exercise	Assuming the policy announcement immediately supplies 2026 liquidity
Annual activity review	Verified activity reporting during implementation	Adjusts allocation where applicable	Treating the initial allocation table as permanently fixed

Sources: Guidance Document No. 2 — European Commission — February 2024; ETS Review Package: Commission presentation — July 2026, slides 63–69. climate.ec.europa.eu

An additional distinction concerns the benchmark update rate. A statutory annual update parameter is not equivalent to an annual percentage reduction in every operator’s final allocation. Final allocation also reflects activity, exposure factors and other adjustments. Nor should the update parameter be read as a conventional compounded investment return. It belongs to the specific benchmark methodology established in the ETS framework.

Timing changes the financial value of the intervention

The original Commission technical presentation illustrated a concentrated adjustment in 2027, incorporating compensation for the lower allocation received in 2026. This creates a financing issue that an aggregate allowance figure cannot capture. A company may need to finance compliance before the additional allocation reaches its account. Its eventual benefit and its immediate cash requirement are therefore different quantities.

Table 1.3 — Original Commission implementation illustration

Parameter	2026	2027	Each year, 2028–2030
Indicative maximum annual benchmark update rate	−2.5%	−1.31%	−1.90%
Heat benchmark	31.2 allowances/TJ	46.0 allowances/TJ	38.6 allowances/TJ
Fuel benchmark	28.1 allowances/TJ	41.4 allowances/TJ	34.8 allowances/TJ
Illustrative fallback-related free allocation	Approximately 68 million	Approximately 100 million	Approximately 81 million annually

Status: Commission illustration of its original proposal, not a final schedule for the subsequent negotiating variants. The presentation gives a period total of approximately 410 million allowances; its rounded annual figures do not sum exactly to that total. Source: ETS Review Package: Commission presentation, WK 10833/2026 — July 2026, slide 68. data.consilium.europa.eu

For investment appraisal, the distinction is consequential. A predictable future transfer can improve expected project returns while leaving a near-term financing gap. A less predictable transfer may have a lower financing value because lenders and corporate investment committees discount uncertain regulatory receipts.

Authorities should consequently monitor three dates separately: the date the operator obtains a legally established entitlement, the date the transfer occurs and the date the compliance expenditure must be financed. A nominally generous settlement can deliver less operational relief if implementation delays force companies to purchase allowances or maintain costly credit facilities in the meantime.

Avoiding the cross-sectoral correction protects other recipients

The cross-sectoral correction factor is a budget-balancing mechanism within free allocation. Where preliminary allocation demand exceeds the available envelope, a correction can reduce entitlements. The targeted revision seeks to prevent increased protection under heat and fuel benchmarks from generating reductions elsewhere.

This safeguard has an industrial-policy function. Without it, relief to one group could partly be financed through reduced allocations to another group, including installations whose product benchmarks were not the reason for intervention. The Council mandate explicitly maintains the objective of avoiding that redistribution. It also proposes retaining the existing tightening treatment for activities identified by NACE codes 0610, 0620, 1920 and 4950. See Mandate for negotiations with the European Parliament, ST 13134/26 — Council of the European Union — September 2026, recitals 2–5 and proposed Article 10a(2b). data.consilium.europa.eu

Table 1.4 — Activities excluded from the proposed relaxation in the cited texts

NACE code	Activity	Interpretation
0610	Extraction of crude petroleum	Proposed exclusion from the targeted benchmark relaxation
0620	Extraction of natural gas	Proposed exclusion from the targeted benchmark relaxation
1920	Manufacture of refined petroleum products	Existing allocation must be distinguished from eligibility for additional relief
4950	Transport via pipeline	Proposed exclusion follows the activity classification

Source: COM(2026) 619 final — European Commission — July 2026, proposed Article 10a(2b). These exclusions do not mean that the activities receive no free allocation under other applicable rules. climate.ec.europa.eu

Key judgments

The material legal change is a targeted relaxation of benchmark tightening, followed by recalculation and delivery. The strongest implementation safeguard is the requirement to avoid reductions in other recipients’ allocations. The principal operational risk is a gap between the period for which relief is intended and the moment companies can use it.

What would change the assessment

A final settlement that changes sector exclusions, the allowance envelope or the timing of transfers would change the distribution of benefits. An amendment that triggers correction elsewhere would also require reassessing the measure as a redistribution between industrial groups.

Open official record

The decisive records are the adopted parliamentary text, the final interinstitutional settlement, the amended benchmark implementing act and the revised allocation decisions. Their functions are distinct and should remain distinct in official communications and corporate financial planning.

Chapter 2 — Who Receives the Allowances: Efficiency, Eligibility and Distribution

The distribution of additional allowances is determined primarily by the composition of eligible activity within installations. National industrial size and corporate emissions provide context, but neither is an adequate allocation key. The relevant unit is frequently the sub-installation: the accounting boundary through which a particular product, heat flow, fuel use or process-emissions activity receives its allocation treatment.

The sub-installation determines exposure to the revision

An industrial site can contain several allocation categories. The product-benchmark boundary takes precedence where applicable; fallback treatment concerns eligible activities outside those boundaries. An installation that is commercially described as a chemical plant, paper mill or steelworks may therefore combine activities affected by the revision with activities that are not.

The hierarchy prevents companies from receiving multiple allocations for the same activity. It also explains why “energy-intensive industry” is too broad a category for estimating the benefit. The relevant classification follows the allocation rules, rather than a company’s public description of its business. See Guidance Document No. 1: General guidance to the allocation methodology — European Commission, DG CLIMA — 2024 revision, Section 5. The Commission guidance is explanatory and non-binding; the underlying Directive and free-allocation regulations remain controlling. climate.ec.europa.eu

Table 2.1 — Allocation categories and their relationship to the targeted revision

Category	Principal allocation reference	Relationship to the heat/fuel revision	Main distributional issue
Product benchmark	Eligible product output within defined system boundaries	No automatic increase merely because production consumes heat or fuel	Correct identification of included processes
Heat benchmark	Eligible net measurable heat	Directly relevant where the revised treatment applies	Metering, heat origin, destination and exposure status
Fuel benchmark	Eligible energy use outside relevant product and measurable-heat boundaries	Directly relevant where the revised treatment applies	Separation from activities already covered elsewhere
Process-emissions approach	Eligible historical process emissions and applicable factor	Not automatically increased by changing heat or fuel coefficients	Correct separation from combustion emissions
District-heating sub-installation	Eligible heat exported for district heating	Requires its own allocation treatment and conditions	Avoiding confusion with industrial heat allocation

Source: Guidance Document No. 2: Guidance on determining the allocation at installation level — European Commission — February 2024, Sections 2–4. climate.ec.europa.eu

A useful analytical representation is:

Additional allocation = change in the applicable benchmark × eligible activity × applicable exposure and adjustment factors.

This expression is deliberately simplified. It isolates the mechanism rather than replacing the legal calculation. It shows why a higher benchmark coefficient cannot establish the company benefit without the corresponding activity and adjustment data.

Equal activity can produce equal relief for unequal emitters

The efficiency benchmark is not a rule reserving support for efficient installations. Where two eligible installations have identical allocation activity and adjustment factors, an increase in the coefficient can give them the same number of additional allowances despite different actual emissions.

The following calculation demonstrates the distributional mechanism. It assumes 1,000 TJ of eligible heat activity, no CBAM reduction, no conditionality reduction and no other correction. It compares the June coefficient of 31.2 with the Council’s indicative period-average coefficient of 43.0. The latter is used solely as an analytical comparison, not as an enacted annual entitlement.

Table 2.2 — Illustrative distribution of relief between two installations

Indicator	Lower-emitting installation	Higher-emitting installation
Assumed eligible heat activity	1,000 TJ	1,000 TJ
Assumed actual emissions	25,000 tCO₂e	60,000 tCO₂e
Allocation at 31.2 allowances/TJ	31,200	31,200
Allocation at indicative 43.0 allowances/TJ	43,000	43,000
Additional allowances	11,800	11,800
Net position before change: allocation minus emissions	Surplus of 6,200	Shortfall of 28,800
Net position after change	Surplus of 18,000	Shortfall of 17,000
Gross additional asset value at assumed €75/allowance	€885,000	€885,000

Calculated illustration: all installation characteristics and the €75 price are assumptions. Benchmark inputs come from Toewijzing gratis emissierechten voor periode 2026–2030 — Dutch Emissions Authority — July 2026 and ST 13134/26 — Council of the European Union — September 2026, recital 2. www.emissieautoriteit.nl

The example establishes two points. The higher-emitting installation retains a substantial incentive to reduce emissions because it still faces an uncovered requirement. Yet the absolute increase in allocation is not a payment for superior efficiency: both receive the same transfer under the assumptions.

The economic consequences can differ even when the transfer is equal. For the lower-emitting installation, the additional allowances increase an asset surplus. For the higher-emitting installation, they reduce purchasing needs. Whether either firm increases investment depends on its financing constraints, project opportunities and expectations. A uniform allocation rule can therefore produce different behavioural outcomes without discriminating formally between the firms.

This is the central challenge for evaluating effectiveness. Authorities must establish whether the allocation increase changes a decision, rather than assuming that receipt of support demonstrates either necessary protection or wasteful subsidy.

Conditionality provides a separate discipline

The benchmark mechanism and allocation conditionality perform different functions. Benchmarks define the reference quantity. Conditionality can reduce the entitlement where specified requirements are not met.

Ireland’s Environmental Protection Agency identifies a 20% reduction for relevant failures to implement energy-efficiency recommendations, subject to exceptions. It separately identifies the climate-neutrality-plan condition for qualifying product-benchmark sub-installations above the 80th percentile of emissions performance. Its guidance also describes conditional additional allocation for district heating in eligible circumstances. These provisions should not be collapsed into a general assertion that every inefficient plant loses 20%, or that separate conditions automatically produce a cumulative 40% reduction. See Free allocation of emission allowances — Environmental Protection Agency, Ireland — accessed October 2026. Environmental Protection Agency

The policy implication is that expanding the allocation envelope and preserving behavioural conditions are compatible. Conversely, changing the destination of allowances withheld through conditionality does not, by itself, establish that the original non-compliant operator receives them back. Recipient eligibility and the financing source must be examined separately.

Activity adjustment limits the entitlement to a historical production pattern

Initial allocation is not an unconditional annual transfer detached from subsequent operation. Activity-level reporting can lead to adjustment. The Irish authority describes the 15% activity-change threshold, subject to an absolute threshold of 300 allowances relative to the calculated preliminary sub-installation allocation. The purpose is to respond to material changes without treating every small fluctuation as a new allocation exercise. See Free allocation of emission allowances — Environmental Protection Agency, Ireland — implementation guidance for 2026–2030. Environmental Protection Agency

For economic analysis, activity adjustment creates a distinction between emissions reductions through technical improvement and reductions through lower output. The first can preserve production while lowering compliance demand. The second can affect allocation itself. An evaluation based only on annual emissions would miss that difference.

The monitoring question should consequently be framed at constant or comparable output: how much verified emissions performance improved, how eligible activity changed and how those changes affected allocation. Where product mix changes, even a plant-level emissions-per-tonne indicator may require reconciliation.

Heat transfers can separate the emitter from the allocation recipient

Heat accounting adds a further distributional complication. The installation producing the emissions is not necessarily the installation receiving the related allocation. In the Commission’s worked example, an ETS heat consumer receives the allocation associated with eligible heat consumed from another ETS installation, whereas heat supplied to eligible non-ETS consumers can generate allocation for the producer. See Guidance Document No. 2 — European Commission — February 2024, worked example on combined heat and power, Section 7. climate.ec.europa.eu

This separation makes contractual arrangements important. A heat consumer may receive additional allowances while the heat price continues to reflect the supplier’s carbon expenditure. Whether the policy reduces the final production cost then depends partly on the contract: indexation, carbon-cost pass-through, treatment of free allocation and the allocation of efficiency gains.

These are commercial incidence questions, not evidence that the regulatory allocation has been misapplied. They nevertheless determine whether the intended competitiveness benefit reaches the operating activity that policymakers seek to preserve.

National allocation totals provide a baseline, not a benefit forecast

The Commission’s status table of 8 October 2026 provides a concrete implementation baseline for industry and heat production. It distinguishes the allocation authorised in the latest national table from allowances already transferred to operators.

Table 2.3 — Selected national free-allocation positions for 2026

Member State	Latest national allocation table, million allowances	Already transferred, million	Difference, million	Transferred share
Germany	106.32	106.00	0.32	99.7%
Italy	41.68	39.12	2.56	93.9%
France	41.11	26.17	14.94	63.7%
Netherlands	33.12	33.12	0.00	100.0%
Belgium	23.55	23.43	0.12	99.5%
Luxembourg	1.11	0.28	0.83	25.2%

Source and calculation: Free allocation in 2026: situation on 8 October 2026 — European Commission — October 2026. Differences and transferred shares are calculated from the published rounded figures. These totals cover broader allocation than the targeted heat/fuel increase. climate.ec.europa.eu

The table cannot explain the reasons for individual transfer gaps, establish non-compliance or identify the distribution of the proposed increase. A transfer gap is an administrative status observation, not proof of permanently unallocated supply. The additional national benefit requires a different dataset: eligible fallback activity, final coefficients and applicable adjustments by sub-installation.

For Germany, Italy, France and the Benelux, the appropriate comparison is therefore the incremental allocation relative to uncovered costs and viable investment requirements. Allocating the European envelope in proportion to the table above would incorrectly assume that each country has the same mix of product benchmarks, fallback activity, exclusions and conditionality.

Key judgments

The revision’s distribution follows eligible activity more closely than actual emissions. Efficient and inefficient installations can receive equal absolute relief when their eligible activity is equal. Conditionality, activity adjustment and heat-contract arrangements determine whether that relief remains proportionate and reaches the intended industrial operation.

What would change the assessment

Publication of sub-installation-level incremental allocation would permit a defensible national and sectoral distribution. Evidence of substantial allocation growth without corresponding activity, or of contractual arrangements preventing the intended cost relief, would warrant a more critical assessment of incidence and targeting.

Open official record

The principal missing record is a reconciled dataset linking each beneficiary’s additional allocation to its eligible heat/fuel activity, adjustment factors and verified emissions. Corporate or national headline totals cannot substitute for that reconciliation.

Chapter 3 — Carbon Leakage and CBAM: Complementarity, Overlap and Remaining Gaps

Free allocation and CBAM address different parts of the competitiveness problem. Free allocation reduces the carbon expenditure associated with eligible European production. CBAM applies an adjustment to covered imports. Their effectiveness depends on consistent treatment of comparable emissions and products; increasing one instrument without reconciling the other can change both the level of protection and its distribution along supply chains.

The phase-in is benchmark-adjusted, not a simple percentage tariff

The CBAM factor reduces benchmark-based free allocation for covered EU production. Its complement should not be interpreted as a universal percentage of every importer’s emissions that becomes chargeable. Where imported goods have emissions above the applicable benchmark-equivalent adjustment, an obligation can arise on that difference even early in the transition.

The Commission’s August guidance illustrates this with emissions of 1.5 tCO₂ per tonne of goods and a benchmark of 1.1 tCO₂ per tonne. It explains the relationship between EU allocation and the corresponding import adjustment. See Guidance Document No. 4: CBAM calculation of the free allocation adjustment to the number of CBAM certificates to be surrendered — European Commission, DG TAXUD — August 2026, Sections 2.1–2.2. taxation-customs.ec.europa.eu

Table 3.1 — Existing CBAM factor schedule and its correct interpretation

Year	CBAM factor retained in benchmark-based allocation	Reduction from full benchmark-based allocation
2026	97.5%	2.5%
2027	95.0%	5.0%
2028	90.0%	10.0%
2029	77.5%	22.5%
2030	51.5%	48.5%
2031	39.0%	61.0%
2032	26.5%	73.5%
2033	14.0%	86.0%
2034	0.0%	100.0%

Source: Guidance Document No. 1: General guidance to the allocation methodology — European Commission — 2024 revision, Table 8. The third column is calculated as 100% minus the factor; it is not a universal tariff rate on all embedded emissions. climate.ec.europa.eu

The broader proposal to extend the transition to 2038 belongs to a separate legislative track. It must not be silently substituted into this existing schedule. The Council Presidency’s September paper identifies that extension as a proposed change under the wider ETS revision. See ETS 1 Revision: policy debate, ST 13435/26 — Council Presidency — September 2026, section a(iv). data.consilium.europa.eu

A worked example shows why “2.5% CBAM” is misleading

Using the Commission’s illustrative emissions and benchmark inputs, the following calculation assumes identical EU and foreign emissions performance, a correction factor of one, no foreign carbon-price deduction and an assumed carbon price of €75/tCO₂. It simplifies the legal calculation to expose the mechanism.

Table 3.2 — Illustrative carbon exposure per tonne of goods

Year	Emissions	Benchmark-equivalent adjustment: 1.1 × CBAM factor	Residual exposure	Value at assumed €75/tCO₂
2026	1.5000 tCO₂	1.0725 tCO₂	0.4275 tCO₂	€32.06
2028	1.5000 tCO₂	0.9900 tCO₂	0.5100 tCO₂	€38.25
2030	1.5000 tCO₂	0.5665 tCO₂	0.9335 tCO₂	€70.01
2034	1.5000 tCO₂	0.0000 tCO₂	1.5000 tCO₂	€112.50

Calculated illustration: residual exposure equals emissions minus the benchmark-equivalent adjustment. The 2026 exposure is 28.5% of the assumed emissions, despite the 2.5% reduction from full benchmark allocation. This is not an estimate for a real product or consignment. Methodological basis: Guidance Document No. 4 — European Commission — August 2026, Figure 2-1 and allocation-adjustment methodology. taxation-customs.ec.europa.eu

The example changes the strategic interpretation of the transition. CBAM can impose a meaningful obligation on a high-emissions import before free allocation is substantially phased out. Conversely, the protection of an EU producer depends partly on how its emissions compare with those of the competing imported good. The instrument aims to price relevant carbon differences; it does not promise equal total production costs.

A higher benchmark-equivalent adjustment also reduces residual exposure. Where the heat/fuel relaxation affects the allocation treatment embedded in CBAM benchmarks, corresponding import calculations require reconciliation. Increasing EU allocation while leaving the import adjustment unchanged would not preserve the intended correspondence.

Product boundaries complicate the correspondence

An EU installation and an imported product are different accounting objects. An integrated European plant can contain several benchmark categories, while an imported finished material can embody emissions from several precursor stages. The import calculation must therefore translate installation-related concepts into product-level treatment.

The distinction is particularly important for steel. The Commission’s steel guidance describes the contribution of precursors and the treatment of scrap generated during processing. An assessment focused only on the final rolling, cutting or machining stage can omit much of the product’s embedded emissions. See Guidance No. 5d: Sector-specific guidance document on iron and steel — European Commission, DG TAXUD — August 2026, worked examples. taxation-customs.ec.europa.eu

Cement presents a different reconciliation problem: its embedded emissions depend heavily on clinker content. The Commission’s cement guidance requires attention to the clinker-to-cement ratio and distinguishes relevant functional units and compositions. Comparing two tonnes of cement without their composition can therefore misstate the relevant emissions comparison. See Guidance No. 5a: Sector-specific guidance document on cement — European Commission, DG TAXUD — August 2026, Section 3.1. taxation-customs.ec.europa.eu

Table 3.3 — Where an apparently comparable product can conceal different carbon treatment

Comparison issue	Information required	Consequence of omission
Integrated versus separate production stages	Precursors and relevant production boundaries	Missing or double-counted embedded emissions
Different steel production routes	Applicable route and precursor data	Inappropriate emissions or allocation comparison
Cement composition	Clinker content and applicable functional unit	Misstated carbon intensity per tonne
Purchased process heat	Heat-related emissions attributed to the product	Understatement of emissions outside the final producer’s own stacks
Electricity consumption	Whether indirect emissions are legally relevant	Inconsistent comparison between sectors
Foreign carbon pricing	Eligible carbon price effectively paid and supporting evidence	Incorrect deduction or overstated import liability

The Commission’s definitive-period methodology distinguishes direct emissions, relevant indirect emissions and precursor contributions. Indirect electricity emissions are not treated identically across all goods; the guidance identifies their relevance for cement, fertilisers and agglomerated iron ores, with specific precursor implications. See Guidance No. 3: CBAM methods for the calculation of emissions embedded in goods — European Commission, DG TAXUD — August 2026, Sections 4.1–4.2. taxation-customs.ec.europa.eu

Carbon-price exposure and payment timing are separate

The Commission publishes quarterly CBAM certificate prices for 2026 and states that weekly prices apply from 2027. Certificate purchases begin through the common central platform from February 2027. Consequently, a 2026 import can create an economic exposure whose cash settlement occurs later.

Table 3.4 — Published CBAM certificate prices available at the assessment date

Quarter of application	Publication date	Price per certificate
Q1 2026	7 April 2026	€75.36
Q2 2026	6 July 2026	€75.28
Q3 2026	5 October 2026	€82.32

Source: Price of CBAM certificates — European Commission, DG TAXUD — accessed October 2026. These are published CBAM reference prices, not contemporaneous exchange quotations or forecasts. Taxation and Customs Union

The distinction matters commercially. Importers may adjust prices, procurement terms or provisions before purchasing certificates. European producers may likewise experience changes in competing offers before the corresponding public revenues are received. The absence of an immediate payment therefore does not establish the absence of a price signal.

It also follows that a temporary comparison between spot EU allowances and a CBAM reference price is not sufficient to establish a lasting competitive advantage. Contract dates, reporting periods, certificate pricing rules and hedging decisions need to be aligned.

The remaining leakage risks are structurally different

The principal residual exposures arise where the legal scope of protection does not match the economic scope of competition.

Table 3.5 — Residual leakage channels and the limits of each instrument

Exposure	What free allocation can address	What CBAM can address	Remaining limitation
Covered EU goods sold in the EU	Reduces eligible domestic compliance expenditure	Applies an adjustment to competing covered imports	Energy, capital and other production costs remain unequal
EU goods exported to third countries	Reduces part of the exporter’s eligible carbon burden	Does not itself adjust sales into foreign markets	Competition remains governed by destination-market conditions
Goods outside CBAM coverage	Supports eligible ETS activities	No direct import adjustment merely because the producer is energy-intensive	Coverage gaps remain
Downstream manufacturers using covered inputs	May support their own eligible ETS activity	Adjusts covered imported inputs and covered downstream goods	Finished-product competition depends on the relevant customs scope
Future investment location	Improves expected EU operating economics	Influences expected competition in the EU market	Infrastructure and long-term policy expectations remain decisive

These channels should not be combined into a single leakage estimate. Export displacement, substitution towards imported downstream products and relocation of future investment can occur through different mechanisms and on different time horizons.

A plant can retain current output while its parent company locates the next investment elsewhere. Conversely, a fall in EU output may reflect demand or technology changes rather than carbon leakage. Attribution requires a counterfactual: what would have happened to production or investment without the carbon-cost difference and without the policy response.

Exemptions require proportionate monitoring

CBAM’s mass threshold reduces administrative obligations for small import volumes. The Commission’s introductory guidance specifies a 50-tonne annual threshold, aggregated across the relevant goods imported by the same importer, with electricity and hydrogen excluded from that exemption. Exceeding the threshold brings the year’s covered imports into the obligation, including earlier imports in that year. The guidance also identifies exemptions associated with participation in, or full linkage to, the EU ETS. See Guidance No. 1: Introduction to CBAM concepts — European Commission, DG TAXUD — August 2026, Section 2.5. taxation-customs.ec.europa.eu

The monitoring priority is not to assume that every exempt importer presents a material leakage risk. It is to identify changes in import organisation or product classification that undermine the intended coverage. Any response should distinguish legitimate use of a legal exemption from artificial fragmentation or inaccurate declarations.

Key judgments

CBAM and free allocation are complementary only when their product boundaries, benchmark adjustments and emissions treatment remain consistent. The early transition does not imply negligible exposure for high-emissions imports. At the same time, CBAM cannot resolve export competition, all downstream exposure or the non-carbon disadvantages affecting European investment.

The heat/fuel revision should therefore be assessed against two separate standards: whether it preserves viable European activity, and whether its interaction with CBAM maintains comparable carbon treatment. Satisfying one standard does not automatically satisfy the other.

What would change the assessment

The assessment would change materially if final legislation altered the CBAM transition schedule, if revised fallback treatment were not consistently reflected in import adjustments, or if product-level evidence demonstrated significant leakage through uncovered downstream goods. Verified changes in foreign emissions performance could also alter the competitive effect without any change in EU legislation.

Open official record

The consequential evidence is a reconciled account of revised EU allocation, corresponding CBAM adjustments, verified product emissions and trade changes at the relevant customs-code level. That record would allow authorities to distinguish successful protection of industrial transformation from a redistribution of carbon costs that leaves the underlying investment problem unresolved.

---

Pillar II — Industrial Competitiveness and European Economic Geography

Chapter 4 — Germany and the Benelux: Integrated Industrial Systems and Uneven Relief

The principal competitiveness effect of the benchmark revision in Germany and the Benelux will depend on whether additional allocation preserves economically viable industrial networks while those networks change their energy and production systems. Support to an individual installation can have consequences beyond its own balance sheet: connected plants may depend on its intermediate products, shared utilities or purchasing demand. Yet protecting an existing network is not sufficient if its underlying operating economics prevent replacement investment. The relevant distinction is between financing the transition of an industrial system and maintaining its current configuration without a credible route to renewal.

Germany: the investment problem extends beyond the compliance account

Germany’s industrial challenge cannot be reduced to the number of allowances companies must purchase. The electricity system provides a measurable example. Bundesnetzagentur reports an average German day-ahead wholesale electricity price of €89.32/MWh in 2025, compared with €78.51/MWh in 2024, an increase of 13.8%. The same year contained 573 hours with negative wholesale prices and 40 hours above €300/MWh. Abundant electricity during some periods therefore coexisted with expensive scarcity periods. Neither the annual average nor the negative-price count alone establishes the electricity cost available to a continuous industrial process. See Bundesnetzagentur publishes 2025 electricity market data — Bundesnetzagentur — January 2026. bundesnetzagentur.de

For an industrial investment committee, this distribution matters because electrification replaces one set of operating exposures with another. A process may reduce direct emissions while increasing dependence on electricity procurement, connection capacity and the ability to operate through expensive hours. Additional free allocation can improve the incumbent operation’s finances, but it does not establish the cost or reliability of electricity for the replacement process.

Table 4.1 — German electricity-market conditions relevant to industrial investment

Indicator	2025 observation	Industrial significance
Average day-ahead wholesale price	€89.32/MWh	Reference for market conditions, not a final industrial tariff
Change from 2024	+13.8%	Operating-cost pressure remained after the energy-crisis peak
Hours with negative prices	573	Creates potential value for flexible consumption
Hours above €300/MWh	40	Exposes insufficiently hedged or inflexible operations
Natural-gas electricity generation	60.6 TWh; +6.4%	Gas remained relevant to the electricity supply system

Source: Bundesnetzagentur publishes 2025 electricity market data — January 2026. Prices are wholesale observations; generation figures do not establish the marginal price-setting fuel in every hour.

The commercial importance of operating costs is illustrated by ArcelorMittal’s June 2025 decision not to proceed with its previously announced DRI–EAF conversion plans in Bremen and Eisenhüttenstadt. The company stated that the projects could not advance despite an agreement involving €1.3 billion of German financial assistance, citing the policy, energy and market environment. It indicated that subsequent work would focus on detailed planning for electric-arc furnaces under conditions supporting a viable business case. This is a documented corporate decision and an interested-party explanation of its causes, not an independent estimate of the subsidy required. See ArcelorMittal Europe urges faster implementation of Steel and Metals Action Plan — ArcelorMittal — June 2025. ArcelorMittal

The analytical implication is that capital support and operating-cost protection are complementary only when the transformed plant can sell its output at a sustainable margin. A grant can reduce construction expenditure without closing the recurring difference between electricity, hydrogen or feedstock costs and the revenue obtainable from the final product. Benchmark relief should therefore be evaluated against the operating economics of both the existing and replacement assets.

Integrated chemical sites create benefits and vulnerabilities across plants

BASF’s reporting identifies Ludwigshafen and Antwerp within its integrated production network, alongside sites in North America and Asia. The company describes the linking of plants and multistage value chains as a source of resource efficiency and operational coordination. Its 2025 report also records the expansion of the Zhanjiang complex in China, with steam-cracker commissioning beginning in December 2025 and specification-compliant products supplied to downstream plants in early January 2026. See Sites and Business Environment — BASF Report 2025 — February 2026. BASF Report 2025

Integration can increase the value of retaining an upstream operation because other plants may depend on its outputs or utility services. It can also make restructuring more complex: closing one unit may require changes to energy balances, intermediate-product sourcing and the utilisation of connected assets. These effects need engineering and commercial evidence; they cannot be inferred from an installation’s emissions alone.

The same integration does not eliminate international competition for capital. BASF’s published investment plan envisages approximately €13 billion of capital expenditure over 2026–2029, following approximately €4 billion in 2025 and an anticipated €3 billion in 2026. The company identifies regional market growth as a reason for its Asian investments. Those figures concern group capital allocation, not the amount available for European decarbonisation. See Investments — BASF — February 2026. basf.com

For policymakers, the relevant counterfactual is consequently not always the immediate closure of a European plant. It can be the gradual allocation of replacement capacity, research-linked production or the next generation of equipment elsewhere. Relief that preserves current utilisation but fails to attract renewal may delay industrial contraction rather than prevent it.

The Netherlands: manufacturing growth can conceal chemical weakness

Dutch data demonstrate why a national manufacturing headline is an unreliable guide to the need for heat- and fuel-related relief. Statistics Netherlands reports 12.0% year-on-year manufacturing growth in August 2026, but the chemical industry contracted 4.1%. Machinery output increased 45.1%, while rubber and plastics fell 3.0%. These are volume measures for different branches within the same national industrial economy. See Manufacturing output in August 12 percent higher, year on year — Statistics Netherlands — October 2026. CBS

Table 4.2 — Divergence within Dutch manufacturing

Branch	August 2026 output change against August 2025
Manufacturing, total	+12.0%
Machinery	+45.1%
Transport equipment	+8.3%
Metal products	+1.9%
Food products	+0.9%
Rubber and plastic products	−3.0%
Chemical products	−4.1%

Definition: calendar-adjusted production volumes. Source: Statistics Netherlands — October 2026.

The policy implication is to target the explanation of weakness, rather than extrapolate from the national cycle. A chemical installation can face depressed margins within an economy experiencing strong manufacturing growth. Conversely, national growth does not establish that additional allocation is unnecessary, just as chemical contraction does not establish that carbon costs caused it.

Rotterdam introduces an infrastructure dimension. Porthos describes planned storage of approximately 2.5 million tonnes of CO₂ annually, totalling approximately 37 million tonnes over the project’s operating period. Its revised schedule states that the system is not expected to become operational before the second half of 2027, replacing the previous expectation of a start by the end of 2026. See Project — Porthos — accessed October 2026 and Schedule for the Porthos CO₂ transport and storage project revised — Porthos — April 2026. Porthos

This is a concrete case in which temporary protection can bridge an infrastructure dependency. The bridge should nevertheless be tied to the revised project sequence. Completion of transport and storage infrastructure does not automatically mean every industrial capture unit is ready, connected and operating at its planned rate. Authorities need to monitor the entire chain before treating nominal storage capacity as realised industrial abatement.

Belgium: renewal and pressure coexist within the Antwerp cluster

Port of Antwerp-Bruges reports 200.9 million tonnes of maritime throughput in the first nine months of 2026, down 0.8% year on year. Chemical throughput fell 1.1%, liquid bulk 3.4% and steel throughput 17.5%. These are logistics observations, not measures of Belgian industrial production; the port also identifies trade-policy and operational influences. See Throughput data Q1–Q3 2026 — Port of Antwerp-Bruges — October 2026. newsroom.portofantwerpbruges.com

At the same time, INEOS reported continued construction of Project ONE in July 2026, with approximately 2,500 workers on site and a targeted cracker start in the second half of 2027. This is evidence of physical investment activity alongside industrial pressure, rather than evidence of either universal decline or a completed recovery. See INEOS Project ONE modules escape Strait of Hormuz to reach Antwerp — INEOS — July 2026. ineos.com

The distributional question is therefore intertemporal as well as sectoral. Additional protection for existing operations can preserve demand, utilities and skills around new investments. It can also maintain competing capacity that weakens the commercial return on more efficient replacement assets. A credible Belgian assessment should examine how relief affects the cluster’s renewal, including the balance between existing production, new capacity and market demand.

Luxembourg: existing electrification changes the competitiveness problem

Luxembourg’s steel example illustrates why industrial transformation cannot be evaluated solely by the direct-emissions burden. ArcelorMittal’s 2023 announcement for Belval described a €67 million electric-arc-furnace investment, with approximately €15 million in state support, replacing an existing electric furnace and improving the integration of Luxembourg steelmaking and rolling operations. That announcement establishes the investment decision and intended configuration; it does not independently establish the plant’s current operating performance. See ArcelorMittal invests 67 million euros in a new electric arc furnace at its Belval site — ArcelorMittal — June 2023. ArcelorMittal

For an already electrified production route, competitiveness depends heavily on electricity, scrap quality, productivity and the market for finished products. Thermal operations elsewhere on the site can remain relevant, but increased fallback allocation is not a comprehensive response to those costs. The correct assessment compares the benefit with the cost structure of the actual production route.

National support can amplify differences within a harmonised ETS

The Clean Industrial Deal State Aid Framework permits measures covering electricity costs, industrial decarbonisation, clean-technology manufacturing and investment risk reduction. It applies from 25 June 2025 to 31 December 2030. The framework authorises categories of support; it does not ensure that every Member State finances equivalent measures. See Clean Industrial Deal State Aid Framework — European Commission — accessed October 2026. Competition Policy

The resulting analytical risk is to attribute a plant’s improved position entirely to EU allocation when it also receives national electricity relief, capital support or infrastructure access.

Table 4.3 — The competitiveness package that must be assessed at plant level

Component	Economic function	Risk of misinterpretation
Additional free allocation	Improves eligible carbon-cost position	Treating it as compensation for every operating disadvantage
Electricity-cost support	Changes the effective electricity bill	Comparing gross tariffs in one country with supported tariffs in another
Capital assistance	Reduces investment expenditure	Assuming it also closes recurring operating losses
Infrastructure access	Enables electricity, hydrogen or CO₂ services	Treating planned capacity as available service
Long-term procurement	Reduces selected price and supply risks	Ignoring contractual obligations and residual exposure
Demand and product premiums	Supports revenue from transformed production	Counting announced purchasing interest as contracted sales

This is an analytical comparison framework, not a statement that every installation receives every instrument.

Key judgments

Germany’s central challenge is to combine industrial retention with credible operating conditions for replacement investment. The Netherlands demonstrates that national manufacturing growth can coexist with weakness in the activities most relevant to relief. Belgium’s position depends on coordinating existing industrial networks with substantial new investment, while Luxembourg’s steel exposure illustrates the limits of addressing electrified production through thermal allocation alone.

What would change the assessment

The judgment would strengthen if additional allocation were accompanied by executed replacement investment, firm energy contracts and operational infrastructure. It would weaken if supported sites maintained output temporarily while replacement projects, upstream functions or the next investment cycle moved elsewhere.

Open official record

The decisive evidence is a plant-level reconciliation of allocation benefits, national support, effective energy procurement and investment execution. Cluster-wide claims require evidence of actual supplier, utility and intermediate-product dependencies.

Chapter 5 — Italy and France: Manufacturing Exposure and Investment Choices

Italy and France face the same European carbon framework through different energy systems and industrial investment conditions. The most important distinction is whether a plant can convert temporary carbon-cost relief into a durable reduction in production costs. France’s electricity system creates opportunities for electrification that are not automatically available on equivalent terms in Italy. Italy’s policy challenge is correspondingly broader: preserving internationally traded manufacturing while reducing the energy-price disadvantage affecting both existing and replacement processes.

Electricity geography can outweigh an allocation adjustment

ARERA’s 2026 presentation reports an Italian average wholesale electricity price of €115.9/MWh in 2025, against €61.1/MWh in France and €65.3/MWh in Spain. Germany’s regulator reports €89.32/MWh for its day-ahead market over the same year. These observations describe wholesale market conditions, rather than the final bills of otherwise identical industrial consumers. See Presentazione del Presidente: Relazione annuale 2026 — ARERA — 2026, page 5 and 2025 electricity market data — Bundesnetzagentur — January 2026. arera.it

Table 5.1 — Wholesale electricity conditions in 2025

Market	Annual average	Difference from France
France	€61.10/MWh	Reference
Spain	€65.30/MWh	+€4.20/MWh
Germany	€89.32/MWh	+€28.22/MWh
Italy	€115.90/MWh	+€54.80/MWh

Calculated comparison: differences use the cited annual averages. National market arrangements differ; these are not matched industrial contract prices.

Forward markets provide a separate perspective. RTE’s first-half 2026 assessment reports average electricity forward prices for 2027 delivery of €54/MWh in France, €89/MWh in Germany, €101/MWh in Italy and €57/MWh in Spain. These are period-average forward observations, not October quotations or forecasts of realised prices. See Bilan du premier semestre 2026 — RTE — July 2026, synthesis. assets.rte-france.com

Table 5.2 — Illustrative electricity procurement exposure at 100 GWh

Market	Reported average forward price for 2027 delivery	Energy-only expenditure at assumed 100 GWh	Difference from France
France	€54/MWh	€5.40 million	Reference
Spain	€57/MWh	€5.70 million	€0.30 million
Germany	€89/MWh	€8.90 million	€3.50 million
Italy	€101/MWh	€10.10 million	€4.70 million

Calculation: 100 GWh equals 100,000 MWh; expenditure equals consumption multiplied by the reported forward price. The illustration excludes network charges, taxes, profile costs, balancing, support and contractual differences.

At an assumed allowance value of €75, the €4.70 million Italy–France difference is arithmetically equivalent to approximately 62,700 allowances. This is a scale comparison, not an entitlement estimate. It shows why a useful allocation increase may still leave the central operating disadvantage unresolved.

The investment implication is stronger than the immediate bill comparison. A company considering electrification must evaluate the recurring electricity requirement over the asset’s life. Temporary relief through 2030 can improve financing, but cannot establish the post-2030 energy economics of equipment expected to operate for much longer.

Italy: weak volumes and rising prices require different interpretations

Italy’s August 2026 industrial-production release records a 1.3% monthly decline, a 1.1% reduction over the latest three months against the preceding three months, and unchanged calendar-adjusted output against August 2025. Separately, industrial producer prices increased 10.9% year on year, with domestic electricity and gas supply prices rising 26.3%. The coexistence of weak output and rising prices is more relevant to industrial margins than either indicator in isolation. See Industrial production — August 2026 — Istat — October 2026 and Prezzi alla produzione dell’industria e delle costruzioni — Agosto 2026 — Istat — September 2026. Istat

Table 5.3 — Italy’s industrial conditions: volumes and prices

Indicator	Reference comparison	Published change
Industrial production	August 2026 against July; seasonally adjusted	−1.3%
Industrial production	Latest three months against preceding three months	−1.1%
Industrial production	August 2026 against August 2025; calendar adjusted	0.0%
Industrial producer prices	August 2026 against August 2025	+10.9%
Domestic producer prices excluding energy	August 2026 against August 2025	+3.3%
Domestic electricity and gas supply producer prices	August 2026 against August 2025	+26.3%

Sources: the cited Istat releases. Price indices measure selling-price developments in the specified activities; they are not a direct measurement of every manufacturer’s energy purchase bill.

Additional allocation can protect cash flow when a plant cannot pass higher costs into final prices. Its effect is smaller where energy costs rise much faster than the allowance benefit or where demand weakness prevents profitable utilisation. Evaluation must therefore distinguish a liquidity problem from a persistent gap between the full cost of production and achievable sales revenue.

Ceramics: export dependence makes the location question immediate

Confindustria Ceramica’s 2025 survey reports 117 Italian tile-producing companies, 17,676 direct employees, production of 390.9 million square metres, and sales of 386.9 million square metres. Export sales accounted for approximately 82% of turnover. Investment fell 16% to €321 million, despite increased sales volumes. These are industry-association survey results and should be attributed accordingly. See Presentati in conferenza stampa i dati 2025 dell’industria ceramica italiana — Confindustria Ceramica — June 2026. Confindustria Ceramica

Table 5.4 — Italian ceramic tiles: production, trade and investment

Indicator	2025 result	Reported annual change
Production	390.9 million m²	+5.7%
Total sales volume	386.9 million m²	+2.3%
Export sales volume	301.7 million m²	+2.8%
Turnover	Approximately €6.0 billion	−0.4%
Export share of turnover	Approximately 82%	—
Investment	€321 million	−16%
Investment relative to turnover	5.3%	—

Source: Confindustria Ceramica — June 2026. Scope: tiles produced in Italy, rather than all ceramic activities or foreign production controlled by Italian groups.

The divergence between sales volume and turnover suggests pressure on average revenue per square metre, potentially reflecting prices, product mix, destinations or exchange-rate effects. It does not establish a single cause. The reduction in investment is nevertheless important because competitiveness depends on continued process renewal, product development and equipment performance.

For an export-oriented producer, relief may help preserve domestic investment without guaranteeing the competitiveness of every destination market. The state’s interest is not simply that a company continues selling products under an Italian brand. It is that commercially viable production, specialised suppliers and technological capabilities continue to be renewed in Italy.

Italy’s investment instruments should be assessed alongside the ETS

GSE describes Energy Release 2.0 as a mechanism linking a 36-month energy-advance period with commitments to develop renewable generation and return the advanced energy over the subsequent 20 years, under the applicable rules. Its economic function therefore differs from free allocation: it connects near-term energy treatment with a longer-term generation obligation. See Energy Release 2.0 — GSE — accessed October 2026. gse.it

The relevant policy question is whether these instruments form a coherent investment package. A company should not count the gross value of an energy mechanism as an unconditional saving while omitting construction, guarantee, repayment or procurement obligations. Equally, an ETS benefit should not be counted twice if it is already incorporated into the operating cash flows used to evaluate an investment.

Italy’s infrastructure choices add another layer. On 20 October 2026, Eni reported that Ravenna CCS Phase 2 had been selected for funding under the Innovation Fund. The stated development plan targets 4 million tonnes of annual storage capacity by 2030, with possible later expansion. Selection for funding and planned capacity are milestones, not evidence that those industrial-scale services are already operating. See Ravenna CCS selected under the European Innovation Fund — Eni — October 2026. eni.com

The implication is to differentiate installations with a realistic connection and capture pathway from those for which the infrastructure is geographically, technically or commercially inaccessible. National storage potential is not equivalent to a bankable abatement option for every Italian plant.

France: electricity availability must become an industrial contract

RTE reports French electricity generation of 547.5 TWh in 2025, including 521.1 TWh of low-carbon generation, maintaining a low-carbon share above 95%. It also reports electricity consumption remaining approximately 6% below its pre-crisis level. France therefore entered the investment debate with substantial low-carbon supply, but unused national potential does not automatically translate into industrial consumption. See Bilan électrique 2025: les conditions sont réunies pour permettre à la France d’accélérer son électrification — RTE — February 2026. RTE

The remaining decisions concern the delivered price, connection timetable, reliability requirements and commercial demand for the transformed product. France’s advantage is strongest where a company can secure those conditions together. Low average wholesale prices are less decisive where a project faces a delayed grid connection, uncertain product revenues or a process that cannot economically electrify.

Recent production data also counsel against equating electricity strength with a general industrial recovery. Insee reports manufacturing output down 1.2% over June–August 2026 against the same period in 2025. Transport-equipment output fell 5.0%, food and beverages 1.5%, and the broad grouping of other industrial products 0.8%. See In August 2026, manufacturing output bounced back partially — Insee — October 2026. Insee

Dunkirk demonstrates the difference between relief and a replacement project

ArcelorMittal’s February 2026 announcement confirms a €1.3 billion electric-arc-furnace investment at Dunkirk, with capacity of 2 million tonnes annually and start-up scheduled for 2029. The company states that Energy Efficiency Certificates will support 50% of the investment. These are declared investment and financing parameters, rather than realised production or independently verified emissions performance. See ArcelorMittal confirms the construction of an electric arc furnace in Dunkirk, France — ArcelorMittal Europe — February 2026. ArcelorMittal Europe

Dunkirk’s significance is that a transformed production route requires a coordinated decision on capital, electricity, inputs and market conditions. The contrast with the earlier German investment decision illustrates how projects within the same corporate group can face different national business cases. It does not establish that benchmark relief caused either decision, particularly when the decisions preceded the targeted revision.

Table 5.5 — Italy and France: different routes from relief to investment

Investment question	Italy	France
Principal electricity challenge	Reducing the delivered-cost disadvantage	Converting supply strength into competitive, bankable contracts
Role of temporary allocation relief	Preserving investment capacity under cost pressure	Supporting the period before replacement assets operate
Infrastructure test	Accessibility of renewable supply, connections and relevant CO₂ services	Timely connections and coordination of large electricity-consuming projects
Export exposure	Especially important for internationally oriented manufacturing branches	Important alongside domestic and European industrial demand
Main risk	Relief sustains production but does not close the replacement process’s cost gap	Available low-carbon electricity fails to generate sufficient executed industrial demand
Evidence of success	Domestic process renewal and competitive delivered energy	Commissioned projects with sustained utilisation and contracted supply

This table presents analytical implications of the cited national and project evidence, not a ranking of total national support.

Key judgments

Italy’s need is to combine carbon-cost relief with a reduction in the energy disadvantage that affects manufacturing renewal. France has a stronger electricity platform for selected transformations, but that platform must be converted into contracts, connections and viable sales. In both countries, the decisive outcome is replacement investment in domestic productive capability.

What would change the assessment

The Italian outlook would improve with sustained reductions in effective industrial energy costs and greater execution of renewal projects. The French outlook would improve as announced electricity-intensive investments reach commissioning and commercial utilisation. Repeated project delays would weaken both assessments, even if allocation transfers increased.

Open official record

Comparable plant-level energy contracts, support obligations, investment expenditure and commissioning dates remain necessary. National average prices and announced project capacities cannot establish the realised competitiveness of individual installations.

Chapter 6 — The United Kingdom and Non-EU Competitors: Carbon Costs, Trade and Location

European industrial location decisions depend on the combined burden of energy, carbon, capital, logistics and market access. The EU benchmark revision changes one component of that calculation. Its international significance will be greatest where additional allocation closes a relatively narrow competitiveness gap; it will be weaker where a persistent energy or investment disadvantage dominates. The United Kingdom is a particularly relevant comparator because it combines its own carbon market with industrial electricity support and extensive exposure to European trade.

The United Kingdom: lower historical prices did not eliminate renewed pressure

The UK’s September 2026 energy-price release reports that manufacturers paid an average 17.4 pence/kWh for electricity in the second quarter of 2026, up 4.0% year on year, and 3.85 pence/kWh for gas, up 6.3%. The figures are provisional, expressed in current terms and exclude the Climate Change Levy. See Quarterly Energy Prices: September 2026 — UK Government — September 2026, manufacturing energy prices. assets.publishing.service.gov.uk

Table 6.1 — UK manufacturing energy purchase prices

Fuel	Q2 2026 average	Equivalent per MWh	Annual change
Electricity	17.4 pence/kWh	£174.00/MWh	+4.0%
Natural gas	3.85 pence/kWh	£38.50/MWh	+6.3%
Gas oil	9.34 pence/kWh	£93.40/MWh	+13.8%

Definition: manufacturing-sector averages, current prices excluding the Climate Change Levy; provisional. Per-MWh figures are calculated unit conversions. They should not be compared directly with euro-denominated wholesale prices without reconciling exchange rates, customer coverage and price components.

The UK government opened applications for the British Industrial Competitiveness Scheme on 1 October 2026, describing support for more than 10,000 manufacturing businesses and electricity-bill reductions of up to 25%, with support from April 2027. “Up to” is an eligibility-dependent maximum, not the expected reduction for every manufacturer. See Applications open for scheme to slash electricity bills for over 10,000 manufacturers — UK Government — October 2026. GOV.UK

The applicant guidance also explains that exemptions cannot exceed 100% of the relevant charges at a meter. Existing British Industry Supercharger treatment can therefore reduce the additional exemption obtained through BICS. See British Industrial Competitiveness Scheme: guidance for applicants — UK Government — October 2026. GOV.UK

For European comparisons, this means that announced support percentages cannot simply be added to other exemptions or applied to an entire national average bill. The appropriate comparator is the effective cost at a specific competing site after applicable support, contractual conditions and eligibility restrictions.

Carbon-market linking changes expectations before it changes law

The UK ETS policy overview, updated 21 October 2026, continues to describe negotiations to link the UK and EU systems. It also records the extension of the UK scheme into a 2031–2040 phase. The retrieved official record therefore supports a long-term UK carbon-market framework, but not an assumption that linkage has already made UK and EU allowances interchangeable. See UK Emissions Trading Scheme: a policy overview — UK Government — October 2026. GOV.UK

The investment implication is that companies should test both continued separation and eventual linkage. A project justified only by an assumed persistent difference between UK and EU carbon prices is exposed to a policy change that could remove part of that advantage. Conversely, linkage could reduce selected trading and compliance frictions while leaving electricity, network and industrial-support differences intact.

The UK’s published border-adjustment factsheet introduces another distinction: indirect emissions are deferred until 2029 at the earliest, while glass and ceramics are outside the initial 2027 scope. These choices create a different protection profile from the EU’s; they should be evaluated at product and emissions-boundary level rather than treated as an identical border regime with a later start date. See Factsheet: Carbon border adjustment mechanism — UK Government — November 2025. GOV.UK

The United States is a collection of industrial energy locations

The United States offers an important energy-cost comparator, but its national average conceals substantial geographical differences. EIA’s July 2026 data show industrial electricity prices of 6.08 US cents/kWh in Louisiana, 7.07 in Texas, 9.77 nationally, and 25.11 in California. These are preliminary average retail observations, not quotations for otherwise identical plants. See Electric Power Monthly, Table 5.6.A — US Energy Information Administration — September 2026. U.S. Energy Information Administration (EIA)

Table 6.2 — US industrial electricity geography, July 2026

Location	Industrial average, US cents/kWh	Equivalent US$/MWh
Louisiana	6.08	$60.80
Texas	7.07	$70.70
United States	9.77	$97.70
California	25.11	$251.10

Source: EIA — September 2026. Dollar-per-MWh figures are calculated conversions. No exchange-rate-adjusted European comparison is implied.

The relevant location comparison for a European chemical or metals project is therefore a competing US region, energy contract and supply chain. A favourable national political environment does not make every US site equally attractive, just as EU carbon pricing does not make every European site equally costly.

The IEA’s 2026 electricity assessment estimates that European energy-intensive industrial electricity prices in 2025 remained roughly twice US levels and substantially above Chinese levels. Its methodology includes assumptions about European compensation and uses Texas as the US reference. This is an indicative large-consumer comparison, not a universal ratio applicable to every sector. See Prices — Electricity 2026 — International Energy Agency — January 2026. IEA

That methodology matters because it demonstrates that the cost gap can persist even after selected compensation is recognised. Increasing direct-emissions allocation does not necessarily close an electricity disadvantage already measured after other support.

China cannot be analysed as an economy without carbon pricing

The World Bank reports 87 implemented carbon-pricing policies and coverage of just over 29% of global greenhouse-gas emissions in its 2026 assessment. The relevant international distinction is increasingly between systems with different coverage and effective burdens, rather than a simple division between Europe and jurisdictions without carbon policy. See Direct Carbon Pricing Covers Nearly One Third of Global Emissions — World Bank — May 2026. worldbank.org

China’s government reports 3,378 entities under national carbon-market quota management in 2025, including steel, cement and aluminium smelting.

Table 6.3 — China’s reported national carbon-market participation in 2025

Sector	Entities under quota management
Power generation	2,087
Steel	232
Cement	962
Aluminium smelting	97
Total	3,378

Source: China’s national carbon market maintains stable operation in 2025 — State Council website, reporting Ministry of Ecology and Environment information — January 2026. Entity counts do not measure the effective carbon cost paid per tonne of production. english.www.gov.cn

China’s official progress report describes the sectoral expansion as a phased process involving accounting, verification and allocation arrangements. Such institutional coverage does not establish equivalence with EU allowance scarcity or the purchasing requirement of a competing European plant. See Progress Report of China’s National Carbon Market 2025 — Ministry of Ecology and Environment, official provincial-government repository — 2025. xcoss.henan.gov.cn

A defensible comparison must therefore estimate the effective burden after allocation, relevant electricity costs, applicable support and product-specific emissions. A nominal foreign carbon price can coexist with a much smaller purchasing requirement; alternatively, an efficient foreign producer can have a lower burden because it emits less. The policy response differs in those two cases.

A carbon advantage can be outweighed by an energy disadvantage

The relationship can be expressed without assuming a particular country ranking:

Net cost disadvantage = additional energy cost + additional net carbon cost + other cost differences.

Additional allocation changes the second term. It does not necessarily determine the sign of the total.

Table 6.4 — Illustrative electricity-cost threshold for a carbon-cost advantage

Assumed net carbon-cost advantage	Assumed electricity use per tonne of product	Electricity-price disadvantage that exactly offsets the advantage
€15/t product	0.5 MWh/t product	€30/MWh
€30/t product	0.5 MWh/t product	€60/MWh
€30/t product	1.0 MWh/t product	€30/MWh
€45/t product	1.5 MWh/t product	€30/MWh

Calculated scenarios: all inputs are assumptions, not observed sector averages. The threshold equals the carbon-cost advantage divided by electricity use. Other costs, efficiency changes, capital expenditure and revenues are held constant.

The table explains why the same allocation benefit can have different strategic importance across products. A modest electricity requirement allows carbon relief to close more of the competitiveness gap. A highly electricity-intensive route may remain exposed even after substantial relief. The appropriate policy response is therefore process-specific, especially where decarbonisation increases electricity demand.

Location decisions concern different stages of the value chain

The choice facing a company is not always whether to manufacture an entire product in Europe or abroad. It may retain finishing, formulation, engineering or customer services in Europe while sourcing more energy-intensive intermediates elsewhere. Such a decision can preserve significant domestic value added while increasing dependence on external upstream capacity.

Authorities should consequently distinguish relocation of a complete plant from changes in sourcing, replacement investment and the production stage receiving new capital.

Table 6.5 — Industrial-location decisions and the evidence needed to interpret them

Decision	Potential European benefit	Strategic exposure	Evidence required
Renew the full production chain domestically	Retains upstream and downstream capabilities	High investment and operating-cost requirements	Executed expenditure and sustainable operating margins
Import intermediates and retain downstream production	Preserves selected skills and customer-facing activity	Greater supplier and logistics dependence	Origin, concentration and substitutability of inputs
Locate new capacity abroad while retaining existing EU plants	Preserves current European output temporarily	Gradual loss of replacement investment	Geographic capital allocation over successive investment cycles
Move selected stages within Europe	Can exploit energy and infrastructure differences	Uneven regional employment and industrial effects	Net European capacity and supplier-network changes
Delay investment while awaiting infrastructure or policy clarity	Avoids premature commitment	Ageing assets and missed market opportunities	Revised decision dates and evidence that uncertainty is being resolved

These are analytical pathways, not forecasts or probability assignments.

For economic-security policy, the desirable outcome cannot be defined solely as the maximum possible domestic production of every intermediate. Some sourcing changes may reduce costs and emissions while preserving higher-value activity. Others can remove capabilities that are difficult to reconstruct. The distinction depends on supplier concentration, substitution time, technical knowledge and the consequences of disruption.

The benchmark revision should therefore be judged partly by whether it preserves viable options. Maintaining a plant through a credible infrastructure or investment transition can retain an option of strategic value. Maintaining it indefinitely without a competitive successor can consume resources while concealing the erosion of that option.

Key judgments

The United Kingdom’s position depends on its combined carbon, electricity-support and trade arrangements, rather than its allowance price alone. US competitiveness must be assessed regionally, while China’s expanding carbon market requires comparison of effective burdens rather than assumptions of zero carbon cost.

For European manufacturers, additional allocation is most likely to influence location where it closes a narrow operating gap or enables an otherwise viable transition. Where energy, infrastructure or market conditions dominate, the measure will provide relief without determining the next investment decision.

What would change the assessment

The judgment would change with binding UK–EU linkage arrangements, sustained convergence in effective industrial energy costs, or evidence that additional allocation materially shifts the geography of executed investment. Announced projects, preliminary support eligibility and headline carbon prices are insufficient on their own.

Open official record

The remaining requirement is a matched comparison of competing production routes: effective energy contracts, net carbon expenditure, capital support, logistics, product revenues and investment execution. That evidence would distinguish genuine improvements in European competitiveness from temporary transfers that leave the industrial-location decision unchanged.

---

Pillar III — Market Integrity, Public Resources and Strategic Choices

Chapter 7 — Allowance Supply, Carbon Prices, Auction Revenues and Transition Funds

7.1. The essential distinction: industrial relief, market supply and public revenue

Increasing free allocation creates an immediate economic benefit for eligible installations, but its effects on the carbon market depend on where the allowances come from, when they enter circulation and what would otherwise have happened to them.

Three quantities must therefore be kept separate:

• The value transferred to industrial recipients: the market value of their additional allowances.
• The change in allowances available to the market: measured against the relevant legislative counterfactual.
• The change in public resources: including auction receipts and resources assigned to transition funds.

These quantities can differ substantially. An allowance transferred free of charge can replace a purchase that an installation would otherwise make. However, if the same allowance would have been auctioned during the same period, changing its initial recipient does not mechanically increase total market supply.

Conversely, making previously unavailable allowances usable can increase effective supply, even when the statutory annual cap remains unchanged.

Allocation or supply operation	Immediate industrial effect	Mechanical effect on market availability	Public-resource question
Free allocation replaces an auction in the same period	Recipient purchases fewer allowances	No initial increase in total units available	Which auction beneficiary loses receipts?
Previously unused allocation headroom is distributed	Recipient receives additional compliance assets	Depends on the headroom’s previous legal treatment	Would those units otherwise remain unused, be auctioned or serve another purpose?
Allowances withheld under conditionality are redirected	Other eligible recipients can receive additional support	Depends on the original destination and timing	Which innovation or auction resources are displaced?
Allowances are withdrawn into the MSR	Compliance assets become less available outside the reserve	Circulating supply decreases relative to no withdrawal	Auctions and receipts are postponed or reduced
Allowances remain valid in the MSR instead of being invalidated	No immediate allocation benefit	More units potentially survive for future release	Future monetisation becomes possible, subject to release rules
Allowances are released from the MSR	Additional units become available through the applicable mechanism	Circulating availability increases	Auction receipts depend on quantities and prices

Analytical classification. The treatment of a specific allowance pool must be established from the applicable legal text.

This distinction also explains why “budget neutral” is narrower than “economically costless.” The Commission’s original benchmark proposal states that it creates no additional implications for the Commission budget because the allowances’ financial value is not attributed to that budget. That accounting statement does not establish that every alternative use of the allowances has zero value. See the budgetary explanation in the Commission proposal, COM(2026) 619, Section 4. data.consilium.europa.eu

7.2. What 88 million allowances are worth—and what that valuation cannot establish

The Council’s September position identifies approximately 88 million available allowances and cites a Commission estimate of around €6 billion in industrial cost savings. That is an estimated benefit to the sectors concerned, rather than a separately appropriated cash grant. See the Council statement of 16 September 2026. Consilium

The gross valuation is straightforward:\[ \text{Gross allowance value}=88{,}000{,}000\times \text{EUA price} \]

Assumed allowance price	Gross value of 88 million allowances	Valuation change from a €10/EUA movement
€50	€4.40 billion	€880 million
€65	€5.72 billion	€880 million
€75	€6.60 billion	€880 million
€90	€7.92 billion	€880 million
€100	€8.80 billion	€880 million

Author’s calculations. These are price sensitivities, not market-price forecasts, budget-loss estimates or estimates of additional investment.

Actual cash relief depends on an installation’s compliance deficit, banking strategy and hedging position. A recipient that would otherwise purchase allowances can reduce purchases. A recipient already holding sufficient allowances can retain or sell the additional assets.

Neither outcome establishes that an equivalent amount will finance decarbonisation. That requires separate evidence on investment commitments and spending.

Nor is it valid to multiply all 88 million allowances by a market price and automatically describe the result as lost national auction revenue. That conclusion requires proof that those same units would otherwise have been auctioned for national budgets.

7.3. The MSR makes supply effects conditional and delayed

The Commission’s May 2026 calculation reported a 2025 total number of allowances in circulation—TNAC—of 1,023,494,202, implying an MSR intake of 190,494,202 allowances between September 2026 and August 2027.

Under the rules described in that communication, intake equals TNAC minus 833 million when circulation lies between 833 million and 1,096 million; above that range, the applicable intake rate through 2030 is 24%. See the Commission’s 2026 TNAC communication. climate.ec.europa.eu

The following calculation illustrates the mechanism without predicting the benchmark measure’s actual effects.

Hypothetical increase in measured TNAC	Resulting TNAC, million allowances	Calculated MSR intake, million allowances
None: published reference	1,023.494	190.494
20 million	1,043.494	210.494
60 million	1,083.494	250.494
88 million	1,111.494	266.759

Author’s mechanical sensitivity calculation using the published reference and stated intake rules. It assumes all other determinants remain unchanged.

This table does not assume that the benchmark revision adds 88 million allowances to TNAC in one year. A multiannual allocation envelope and an annual circulation measurement are different objects. Emissions, auctioning, banking, cancellations and allocation timing all affect the actual result.

The implication is that the MSR can absorb part of a supply disturbance through later auction withdrawals. It does not follow that the reserve neutralises the measure immediately, completely or without fiscal consequences.

7.4. The October MSR agreement changes future availability, not immediate allocation

A separate development now affects the assessment. On 20 October 2026, Council and Parliament reached a provisional agreement to retain MSR invalidation while increasing its threshold from 400 million to 700 million allowances. Formal endorsement and adoption remain necessary.

The agreement also envisages considering a gradual threshold reduction in the wider ETS review. See the Council announcement of 21 October 2026. Consilium

Quantity	Meaning	Incorrect interpretation to avoid
Approximately 88 million	Benchmark-related free-allocation envelope under discussion	An automatic increase of 88 million in the annual cap
190.494 million	Published MSR intake for September 2026–August 2027	An amount directly offsetting the entire benchmark package
400 million	Existing reserve invalidation threshold	The same variable as circulating allowance supply
700 million	Provisionally agreed replacement invalidation threshold	An immediate release of 700 million allowances
300 million	Difference between the two invalidation thresholds	Newly created allowances or an industrial allocation entitlement

The 300 million difference is arithmetic. Its practical effect depends on reserve holdings, subsequent withdrawals, release conditions and the amendment’s entry into force.

The strategic concern is cumulative. Benchmark relief changes the distribution and potentially the availability of compliance assets. A higher reserve invalidation threshold can allow more allowances to survive for possible future release. Their combined effect must be evaluated against a common counterfactual.

An unchanged cap trajectory remains an important constraint. Nevertheless, it does not by itself establish an unchanged cumulative emissions outcome when banking and invalidation also change.

7.5. Auction revenues face both quantity risk and price risk

Public auction receipts can be represented as:\[ R=Q\times P \]

where \(Q\) is the auctioned volume and \(P\) the average realised price.

The benchmark measure could affect either variable, but the direction and magnitude cannot be inferred from the allocation envelope alone.

Illustrative scenario	Auction volume	Average price	Receipts	Change from reference
Reference	400 million	€80	€32.0 billion	—
Lower volume only	380 million	€80	€30.4 billion	−€1.6 billion
Lower price only	400 million	€70	€28.0 billion	−€4.0 billion
Lower volume and price	380 million	€70	€26.6 billion	−€5.4 billion

Entirely hypothetical stress test. These figures do not describe an official auction calendar or a forecast attributable to the revision.

The price channel also redistributes benefits more widely than the allocation channel. If the measure contributes to a lower EUA price, purchasers outside the eligible sectors can benefit. Low-emission investments can simultaneously lose part of their expected carbon-price advantage.

Authorities should therefore assess targeted recipient relief and system-wide price effects separately. A daily price movement around a parliamentary vote cannot establish causation without controlling for energy prices, industrial demand, weather, hedging and other policy announcements.

7.6. Public revenues already finance several competing objectives

The Commission reports that ETS auctions raised more than €43 billion in 2025, with approximately €24 billion directly benefiting Member States. Its detailed 2024 account provides a useful distinction between industrial compensation and other climate expenditure:

Official 2024 revenue category	Amount
Total auction revenue	€38.8 billion
Revenue directly accruing to Member States	€24.4 billion
Reported financing of indirect carbon-cost aid	€3.2 billion
National revenue subject to Article 10(3) climate and energy purposes	€21.2 billion

Member States must use the relevant revenues, or an equivalent financial value, for climate and energy action; spending need not occur entirely in the collection year. Source: Commission explanation of ETS revenue use. European Commission

This creates a strategic allocation problem. Resources can protect present production, finance industrial transformation, strengthen grids, improve household efficiency or support other climate objectives. Each can be defensible, but they deliver different outcomes and benefit different constituencies.

Relief for an industrial balance sheet cannot be assumed to substitute fully for a public investment in electricity infrastructure. Equally, a future grid project may arrive too late to prevent an otherwise viable plant from closing.

7.7. The allowance pool’s legal origin determines the fund trade-off

The conditionality-related pool deserves particular scrutiny.

The Fit-for-55 legislative text provides that allowances withheld through specified allocation reductions first protect qualifying installations against the cross-sectoral adjustment. Remaining units are divided between innovation support and auctioning for Member States, with revenues intended to address residual leakage risks and support decarbonisation.

The Council’s September 2026 negotiating mandate instead proposes directing the estimated 33 million conditionality-related allowances towards the fallback benchmark adjustment. Compare the 2023 legislative text, Article 10a amendment with the Council’s September negotiating mandate. data.consilium.europa.eu

This is a direct opportunity-cost question, distinct from a general carbon-price effect.

Resource channel	Possible effect of expanded free allocation	Evidence needed
Innovation Fund allowance resources	Direct displacement where units otherwise assigned to innovation are redirected	Final legal routing and reconciled allowance quantities
Member State auction resources	Direct loss or postponement where auction destinations change	Revised national auction schedules
Modernisation Fund	Price exposure on relevant future monetisation; any direct reallocation must be identified separately	Fund-specific legal provisions and auction records
Existing signed support commitments	Financial pressure depends on available resources and contractual terms	Cash balances, committed liabilities and payment schedules
Future calls and investment rounds	Reduced capacity if receipts fall without replacement	Updated funding plans and available balances

No defensible assessment should charge the full value of the same allowances simultaneously to national budgets, the Innovation Fund and the Modernisation Fund.

7.8. Transition funding is an active industrial instrument

On 19 October 2026, the Commission selected 77 projects across 23 EEA countries for approximately €3.4 billion of Innovation Fund support. The projects entered grant-agreement preparation; selection therefore does not mean that the full amount has already been paid or that the installations are operational. See the Commission’s announcement. Représentation au Luxembourg

The Modernisation Fund has a different geographical purpose. Its July 2026 announcement covered 51 projects in 11 Member States and reported €23.2 billion made available since January 2021.

Selected beneficiaries in the July 2026 round	Reported amount
Romania	€636.9 million
Hungary	€552.3 million
Czechia	€516.8 million
Greece	€233.9 million
Poland	€180.0 million
Lithuania	€169.0 million

Selected country entries, not an exhaustive total. Source: joint Commission–EIB Modernisation Fund announcement. Modernisation Fund

The distributional implication extends beyond the industrial economies receiving the largest allocation benefits. Weaker transition-fund resources can affect Member States with greater infrastructure needs and less national fiscal capacity.

Chapter 7 — Key judgment. The measure’s industrial value is material, but its public cost cannot be represented by one multiplication. Authorities need a reconciliation of allowance origins, alternative destinations, issuance dates, auction changes and fund consequences. The principal unresolved question is how the final settlement combines immediate industrial relief with the preservation of resources for future competitiveness.

Chapter 8 — Decarbonisation Pathways and the Integrity of the 2030 Settlement

8.1. Lower emissions do not necessarily demonstrate industrial transformation

The Commission’s April 2026 release reported the following changes for 2025:

Indicator	Reported change from 2024	Analytical significance
Total covered ETS emissions	−1.3%	Aggregate emissions continued declining
Power-generation emissions	−0.4%	A different sectoral trajectory
Net electricity generation	+1.7%	Output and emissions moved in opposite directions
Energy-intensive industrial emissions	−2.5%	Requires separation of activity and efficiency effects

The Commission explicitly attributes the industrial decline partly to weaker activity and partly to industrial transformation, without quantifying that division in the release. Source: Commission assessment of 2025 ETS emissions. Climate Action

That distinction is central to assessing allocation relief.

A successful measure should help preserve economically sustainable production while reducing emissions intensity. Maintaining emissions because production recovers can be compatible with industrial decarbonisation if intensity improves sufficiently. Falling emissions caused entirely by closure provide a different outcome.

For a homogeneous product:\[ E=Q\times e \]

where \(E\) represents emissions, \(Q\) physical output and \(e\) emissions per unit.

Illustrative pathway	Output index	Emissions-intensity index	Emissions index	Interpretation
Reference	100	100	100	Starting position
Contraction only	90	100	90	Emissions fall through lower production
Efficiency improvement	100	90	90	Equal production with lower emissions
Growth with transformation	110	85	93.5	Output rises while emissions fall
Recovery without transformation	110	100	110	Production and emissions rise together

Author’s illustrative index calculations. These are analytical cases, not observed sectoral outcomes.

For diversified installations, the calculation must additionally control for product mix, quality, outsourcing and production boundaries. Otherwise, an apparent efficiency gain may reflect moving an emissions-intensive intermediate process elsewhere.

8.2. Free allocation can preserve the marginal carbon incentive

Receiving allowances free of charge does not automatically remove the value of avoiding an additional tonne of emissions. An allowance retained through abatement can still have a market value.

The investment effect becomes more complicated where technological change also changes allocation entitlement.

A simplified comparison is:\[ \text{Annual carbon-related investment benefit} = P\times(D-L) \]

where:

• \(P\) is the allowance price;
• \(D\) is the emissions avoided;
• \(L\) is the allocation lost because of the change, relative to continued operation under the alternative pathway.

This expression isolates the carbon component. Energy costs, maintenance, capital expenditure, financing and other support remain separate.

Illustrative annual emissions avoided	Illustrative allocation reduction	EUA price assumption	Annual carbon-related benefit
20,000 tonnes	None	€75	€1.500 million
20,000 tonnes	5,000 allowances	€75	€1.125 million
20,000 tonnes	15,000 allowances	€75	€0.375 million
20,000 tonnes	20,000 allowances	€75	Zero

Hypothetical investment comparisons. The allocation reductions are assumptions, not statements of automatic legal consequences.

The relevant policy test is therefore technology-specific: does the revised allocation framework improve the financial capacity to invest while preserving a credible return from choosing a cleaner process?

Greater liquidity can accelerate an investment constrained by financing. But greater support for continued fossil operation can also improve the incumbent pathway’s profitability and postpone replacement.

Both mechanisms are plausible. Their relative importance requires project evidence.

8.3. The central risk is that temporary relief finances a long-lived investment decision

The allocation period ends in 2030; industrial investment decisions often extend much further.

An operator choosing between repairing a fossil-fired furnace and installing a cleaner process does not consider only the next compliance year. It evaluates expected operating costs, asset life, infrastructure readiness and the credibility of future policy.

Investment situation	How relief could accelerate decarbonisation	How relief could delay it	Evidence that distinguishes the outcomes
Cleaner technology is technically available but finance is constrained	Improves liquidity and debt capacity	Funds maintenance or distributions instead	Binding investment decision and financing closure
Electrification awaits a grid connection	Keeps viable production operating until connection	Supports repeated postponement without a credible connection date	Connection agreement, construction milestones and commissioning
Hydrogen or CO₂ infrastructure is unavailable	Bridges a documented infrastructure gap	Maintains an indefinitely contingent transition plan	Contracted capacity, permits and infrastructure progress
Existing equipment approaches replacement	Enables a cleaner replacement	Makes fossil refurbishment more attractive	Equipment specifications and remaining asset life
Clean capacity is already operating	Supports competitive production during market development	Rewards output that would have occurred anyway	Additional production, investment and verified performance

Prospective analytical pathways, not estimates of their prevalence.

Relief is most persuasive where a viable plant faces a demonstrable temporary obstacle and has a credible transition schedule. It is less persuasive where support merely extends an operating model with no financially or technically developed replacement pathway.

The assessment should also distinguish a corporate announcement from an irreversible commitment. Permits, equipment orders, financing closure and construction provide stronger evidence than an undated statement of ambition.

8.4. The 2030 assessment requires several different boundaries

“ETS integrity” encompasses related but distinct tests.

Integrity test	Question	Potential weakness despite satisfactory results elsewhere
Compliance integrity	Are reported emissions verified and covered by surrendered allowances?	Legal compliance alone does not prove rapid technological change
Allowance-system integrity	Do cap, banking, reserve and invalidation rules preserve intended scarcity?	A constant headline cap can coexist with altered usable supply
Industrial-transition integrity	Is emissions intensity declining through investment?	Aggregate reductions can be driven by contraction
Economy-wide integrity	Is the EU progressing towards its overall climate target?	ETS progress cannot compensate automatically for weaknesses in other sectors
Global environmental integrity	Does European production become cleaner without offsetting increases abroad?	Territorial reductions can coexist with production displacement

The EEA’s November 2025 projection vintage illustrates the economy-wide distinction. It projected a 47% reduction in EU net emissions by 2030 under existing measures, and 54% with additional planned measures, against the at least 55% target, all relative to 1990.

These figures are a dated scenario baseline, not an October 2026 estimate of the benchmark revision’s effect. See the EEA indicator on emissions trends and projections. European Environment Agency (EEA)

They show why implementation matters. Planned measures must become effective measures, and progress in one policy system cannot establish delivery of every component of the overall settlement.

8.5. Banking changes the timing of the environmental outcome

An allowance allocated during 2027 need not support emissions during 2027. It can satisfy a current obligation, replace a planned purchase, be sold or remain banked for later use.

Consequently, three time horizons matter:

1. Near-term compliance and liquidity: how much relief operators receive before 2030.
2. Investment timing: whether that relief advances or postpones cleaner production.
3. Longer-term usable allowance supply: what happens through banking, MSR intake and invalidation.

This prevents two opposite overstatements.

First, additional free allocation does not prove an equal increase in emissions. Second, an unchanged annual cap does not prove that the measure has no environmental consequence.

A credible assessment must model the allowance balance and the industrial investment response together. The latter includes infrastructure delays, expected future prices and the possibility that an apparently temporary concession changes expectations about future political intervention.

8.6. Performance-based heat support provides a complementary approach

The Commission has published final terms for the planned €1 billion IF26 industrial heat auction, expected to open in December 2026. Successful projects would receive a fixed premium proportional to direct CO₂ emissions abated, for up to five years.

This provides a concrete alternative channel for directing ETS resources towards transformation. See the Commission’s September 2026 announcement. Climate Action

Instrument	Principal function	Strength	Main limitation
Additional free allocation	Reduces compliance purchases and supports operating capacity	Can deliver broad relief through established allocation systems	Does not itself demonstrate additional abatement
Competitive abatement premium	Supports eligible reductions delivered by selected projects	Links payments to defined performance	Requires credible baselines, verification and project delivery
Capital grant	Helps finance equipment and construction	Addresses initial investment costs	Completion does not guarantee sustained operation
Shared infrastructure investment	Removes grid, network or transport constraints	Can enable several industrial projects	Development and permitting can be slow

Analytical comparison; actual eligibility and payment conditions vary by programme.

These instruments address different constraints. Performance-linked support cannot necessarily prevent an immediate liquidity crisis. Free allocation cannot itself build a grid connection or guarantee that a cleaner furnace is commissioned.

Chapter 8 — Key judgment. Increased allocation can support decarbonisation when it preserves viable production through a documented transition and helps projects reach execution. It can slow decarbonisation when it improves the economics of fossil continuation more than the economics of replacement. The decisive evidence is the relationship between relief, physical output, emissions intensity and completed investment.

Chapter 9 — Policy Options, Monitoring Indicators and Final Strategic Assessment

9.1. The strategic objective should be productive transformation

The appropriate objective is to retain competitive European industrial capability while reducing its dependence on emissions-intensive production.

That requires a broader success criterion than the number of allowances distributed or the immediate reduction in compliance expenditure.

The final settlement should be judged against four outcomes:

• Continued production where European plants have a credible competitive future.
• Additional investment in lower-emission processes and enabling infrastructure.
• A predictable allowance system with transparent treatment of public resources.
• Protection that remains proportionate to demonstrated leakage exposure and transition constraints.

These outcomes can conflict. Policymakers should make the trade-offs explicit rather than assume that any increase in industrial support advances all four simultaneously.

9.2. Policy choices and their consequences

Policy option	Industrial advantage	Environmental or fiscal trade-off	Assessment
Broad increase using all identified allocation headroom	Predictable relief across eligible recipients	Support can exceed demonstrated need at some plants	Defensible only with transparent distribution and outcome evaluation
Greater reliance on conditionality-related allowance pools	Increases the available relief envelope	Can displace alternative innovation and auction uses	Requires an explicit destination-by-destination justification
Preserve transition-fund resources	Maintains financing for future competitiveness	Provides less immediate operating relief	Particularly important where infrastructure is the binding constraint
Expand competitive support for verified abatement	Directs resources towards measurable transformation	Requires project selection and delivery capacity	Strong complement where technologies and projects are ready
Increase shared infrastructure support	Benefits multiple installations and potential entrants	Benefits arrive later and require coordination	Essential for constraints beyond an operator’s control
Reopen allocation support repeatedly	Offers continuing short-term flexibility	Weakens predictability for clean investment and public funding	Poor substitute for a stable medium-term settlement

Policy assessment, not a description of already adopted obligations.

The preferred combination is bounded allocation relief, preserved enforcement and stronger support for deliverable decarbonisation.

The envelope should not become an automatic entitlement to future extensions. Equally, authorities should avoid imposing retrospective investment conditions that lack a clear legal basis. Additional conditions require the appropriate legislation or support contract.

9.3. Publish a complete resource reconciliation

Before claiming either a fiscal saving or a fiscal loss, authorities should publish a common reconciliation.

Required disclosure	Minimum content	Why it matters
Allowance origin	Legal provision and original pool	Establishes whether support uses existing headroom or redirects another resource
Alternative destination	Auction, fund, reserve, carryover or other treatment	Defines the relevant opportunity cost
Allocation year	Entitlement year and actual transfer year	Prevents confusion between annual support and catch-up transfers
Recipient distribution	Sector, benchmark type, Member State and installation data where legally publishable	Shows concentration and incidence
Valuation	Quantities and disclosed price assumptions	Separates allowance volume from market-price movements
Auction adjustment	Changes by year and beneficiary	Identifies direct revenue effects
Fund consequences	Changes to assigned units, receipts, commitments and available balances	Prevents double counting
Reserve interaction	Modelled TNAC, intake, release and invalidation effects	Connects the measure to effective scarcity

This disclosure should distinguish the Commission’s financial-accounting assessment from the wider economic assessment. Both are necessary; they answer different questions.

Commercial confidentiality can justify protecting specific information. It does not justify withholding aggregate quantities, methodologies or the reconciliation of public-resource destinations.

9.4. Establish a dashboard that measures outcomes rather than announcements

The dashboard should combine regulatory records, verified emissions, physical production, project delivery and public finance.

Indicator	Measurement	Warning signal	Appropriate response
Incremental allocation	Actual allocation minus a consistently defined reference allocation	Reported benefits cannot be reconciled with registry transfers	Correct the allocation account
Effective relief	Additional allowances valued consistently, with cash and non-cash effects distinguished	Gross asset value is presented as investment expenditure	Require clearer financial reporting
Allocation coverage	Free allocation divided by verified emissions, with benchmark and scope explanations	Rising coverage without an intelligible operational explanation	Review activity, boundaries and eligibility
Emissions intensity	Verified emissions per comparable physical unit	Relief rises while comparable intensity stagnates	Examine technical constraints and investment execution
Physical production	Product-level output and utilisation	Emissions fall mainly because output collapses	Investigate competitiveness and displacement
Clean investment execution	Equipment orders, financing closure, construction and commissioning	Announcements repeatedly fail to reach execution	Address the specific financing or infrastructure obstacle
Conditionality enforcement	Applicable reductions, exemptions, verification and remediation	Similar cases receive inconsistent national treatment	Coordinate compliance practice
Auction resources	Auctioned quantities, realised prices and beneficiary receipts	Quantity losses and price effects are conflated	Publish separate attribution
Fund delivery	Commitments, payments, commissioning and verified results	Large award totals coexist with delayed implementation	Prioritise delivery and project support
Market liquidity	Spreads, depth, participation and concentration	Sustained deterioration across several indicators	Supervisory analysis before policy intervention
Allowance balance	TNAC, banking, MSR holdings and invalidation	Persistent divergence from the stated scenario	Update the system-wide assessment
Leakage and displacement	EU output, imports, exports and comparable foreign production	Domestic contraction accompanies rising replacement imports	Conduct product-specific causal analysis

Recommended monitoring framework. Warning signals initiate investigation; they do not automatically demonstrate abuse, leakage or policy failure.

No single indicator is sufficient. High allocation coverage can reflect an efficient installation, changed activity or a timing effect. Rising imports can reflect demand, exchange rates, product specialisation or relative costs. The interpretation requires linked evidence.

9.5. Evaluate additionality with a credible counterfactual

The hardest question is whether the measure changes behaviour relative to what would otherwise have occurred.

A sound evaluation should use installation-level records where available, while recognising that recipients differ systematically from non-recipients.

The approach should include:

1. A fixed reference allocation calculation. Recalculate the relevant allocations under a clearly identified alternative rule.
2. Comparable production and emissions boundaries. Adjust for product mix, acquisitions, outsourcing and installation changes.
3. Pre-intervention trends. Establish whether recipients already had different trajectories before the revision.
4. Exposure differences. Compare installations receiving different amounts of relief, controlling for other cost and demand factors.
5. Project verification. Connect claimed investment effects to financing and physical delivery.
6. Sensitivity analysis. Test conclusions under alternative energy prices, demand conditions and allocation assumptions.

A simple comparison between recipients and non-recipients would be misleading if eligibility selects plants with different technologies, markets or transition options.

Similarly, a comparison of emissions before and after implementation cannot isolate the measure from an industrial recovery or recession.

Authorities should publish a range of defensible findings where causal identification remains limited, rather than manufacture a precise estimate of jobs saved or emissions avoided.

9.6. Use an implementation timetable that separates legal duties from recommendations

The following timetable is proposed for governance purposes. It does not describe deadlines already imposed by the benchmark legislation.

Proposed stage	Deliverable	Principal institutional responsibility
At final adoption	Explain the final envelope, allowance origins, alternative destinations and expected distribution	EU institutions
Within three months	Publish the reference methodology and implementation reconciliation	Commission with national authorities
During allocation implementation	Reconcile entitlements, transfers, adjustments and applicable conditionality	National competent authorities
After each verified reporting cycle	Update production, intensity, allocation and compliance indicators	Commission and Member States
During annual auction and fund reporting	Explain quantity effects, price exposure and changes in funding capacity	Relevant auction and fund bodies
In 2028	Assess investment execution and distributional outcomes using available post-implementation evidence	Commission and national authorities
At the 2030 settlement review	Evaluate cumulative effects on production, investment, public resources and allowance scarcity	EU institutions

The 2028 assessment should identify implementation failures early enough to correct infrastructure and project-delivery problems. It should not presume that two years of evidence can reveal every long-term location decision.

9.7. Apply distinct remedies to distinct failures

A poor result does not always justify another increase in free allocation.

Observed problem	More appropriate first response
Allocation calculations are inconsistent	Administrative correction and harmonised interpretation
A viable electrification project lacks grid capacity	Connection investment, network coordination and permitting
A cleaner process faces a documented operating-cost gap	Competitive, proportionate operating support
Industrial demand has collapsed across markets	Broader demand and industrial analysis
Imports replace EU production despite comparable product demand	Product-specific leakage and trade assessment
Public funds have awards but little project delivery	Project preparation, financing and implementation support
An installation fails applicable conditions	Consistent enforcement and legally available remediation
Carbon-market functioning deteriorates	Supervisory investigation and use of the appropriate market mechanisms

This approach limits the risk that free allocation becomes the default response to electricity-market weaknesses, infrastructure delays or macroeconomic contraction.

It also protects the credibility of the instrument. Allocation relief is more defensible when policymakers can identify the problem it addresses and explain why another intervention would be less effective.

9.8. What would strengthen or weaken the strategic case

Evidence strengthening the case	Evidence weakening the case
Additional relief is concentrated in demonstrably exposed production	Allocation gains bear little relationship to documented exposure
Supported plants maintain output while reducing comparable emissions intensity	Continued production depends on repeated concessions without transformation
Cleaner projects reach financing closure and construction	Investment announcements are repeatedly deferred
Temporary infrastructure constraints have credible resolution dates	Support bridges an indefinite infrastructure gap
Fund resources and auction consequences are transparently reconciled	Resource losses are obscured by inconsistent accounting
Conditionality is enforced consistently	Non-compliance loses practical consequences
Market scarcity remains predictable under disclosed assumptions	Repeated interventions make future supply increasingly uncertain
Industrial retention reduces global displacement risk	Domestic support mainly prolongs high-emission capacity without a competitive pathway

9.9. Final strategic assessment

The benchmark revision can provide meaningful relief during a difficult industrial transition. Its strongest justification is the preservation of viable production, skills and investment capacity where cleaner alternatives face temporary financing, infrastructure or deployment constraints.

Its weakest justification is the assumption that distributing every available allowance necessarily produces the greatest strategic benefit.

The approximately 88 million allowances represent a significant economic resource, but neither their gross market value nor their distribution establishes the measure’s effectiveness. The decisive questions are whether the relief changes investment and production decisions, what alternative public uses are displaced, and how the wider allowance balance responds.

The revision should therefore be assessed as part of a combined settlement involving free allocation, auctioning, transition funding, banking and the MSR. The provisional October reserve agreement reinforces the need for that integrated assessment: preserving more potentially usable allowances can affect future scarcity even without changing the headline cap trajectory.

The preferred policy course is to implement clearly bounded relief with transparent accounting, retain credible enforcement, protect the capacity to finance transformation and resolve the infrastructure constraints that individual plants cannot overcome alone.

Success would mean competitive European production with declining emissions intensity and cleaner assets entering service. Failure would mean that temporary relief finances repeated postponement while public investment capacity weakens. The distinction can be established only through verified operating and investment outcomes—not through the volume of allowances distributed.

---

Copyright of debuglies.com – Even partial reproduction of the contents is not permitted without prior authorization Reproduction reserved