Owning the risk factor you are priced against

Portfolios are priced against a carbon risk factor they do not own.

Institutional allocators routinely model climate-related portfolio repricing. The frameworks they use, which include climate scenarios published by the Network for Greening the Financial System (NGFS), MSCI Climate Value-at-Risk, internal shadow carbon pricing, and proprietary stress-testing platforms, share a common feature: they embed a carbon price signal as the transmission mechanism through which transition risk converts into changes in portfolio value. As carbon-pricing regimes tighten, the modeled carbon price rises, and carbon-intensive holdings are repriced downward through direct cost imposition, demand substitution, stranded-asset recognition, and rising cost of capital.

These models produce material projected impacts. Ortec Finance's 2024 climate risk assessment of the top 30 US pension funds found that a disruptive transition scenario could reduce investment performance by up to 19%. Research jointly published by GIC, the Economic Development Board of Singapore, and McKinsey & Company demonstrated, in their modeling, that the energy transition can create portfolio return drag of 20–40 basis points annually, and that a modeled carbon allocation of 0.5–1% can neutralize that drag on a standard 60/40 reference portfolio. In the same modeling, a 5% carbon allocation enhanced expected annual returns by 50–70 basis points while reducing modeled portfolio volatility by 30–50 basis points. Separately, researchers at the University of Nottingham found that adding carbon futures to a European equity portfolio reduced the modified Conditional Value-at-Risk (the expected loss in worst-case scenarios) by approximately 39% (Figure 1).

Portfolios are priced against a carbon risk factor they do not own.

The institutional response to this exposure has been substantive. Portfolio decarbonization, ESG integration, clean-technology venture investment, and portfolio company engagement each address a facet of climate risk and genuinely reduce it. What none of these responses provides is a position whose payoff is mechanistically linked to the carbon price signal, which is the very variable the allocator's own models identify as the transmission mechanism through which transition risk impairs portfolio returns. The portfolio is incomplete in a specific sense: it bears the downside of carbon repricing while holding no instrument that systematically appreciates in the same scenario.

This paper argues that direct exposure to utility-grade carbon units (emissions reduction units that are correspondingly adjusted under Article 6 of the Paris Agreement and carry demonstrable eligibility within existing or imminent compliance frameworks) constitutes the most efficient hedge available against the transition risk embedded in institutional portfolios. A convergence of regulatory catalysts, led by CORSIA Phase II (mandatory from 2027), the EU's 2040 Climate Law (which permits the use of high-quality international carbon credits for up to 5% of the 2040 target from 2036), and the scaling of bilateral ITMO markets, anchors compliance-driven demand against a constrained authorized supply. Current voluntary market pricing for high-integrity credits sits at €7–15 per tonne, while EU ETS allowances have traded between €60 and €80 per tonne through 2025; published forecasts from BloombergNEF, GMK Center, and others project EU compliance pricing rising toward €100+ per tonne over the period to 2030 under NGFS-consistent scenarios.

The gap between today's acquisition cost and compliance-anchored realized value is a structurally driven convergence margin, anchored by legislated demand rather than voluntary sentiment.

The quality threshold matters. This paper draws a deliberate and sharp distinction between utility-grade carbon units (those that are verified, correspondingly adjusted, and eligible for compliance use) and the broader voluntary carbon market, which carries well-documented integrity risks. The hedge thesis depends on regulatory demand; regulatory demand depends on compliance eligibility; compliance eligibility depends on corresponding adjustment and sovereign authorization. Units that do not meet this threshold are not hedge instruments. They are environmental claims with uncertain financial utility.

The paper proceeds in six analytical sections followed by a brief implementation discussion. Sections 1 and 2 establish the empirical case for climate risk as a portfolio-level threat and examine how allocators currently model it. Section 3 critiques the adequacy of prevailing institutional hedging responses. Section 4 presents the theoretical and empirical case for direct carbon exposure as the natural hedge. Section 5 draws the distinction between utility-grade units and generic voluntary market credits. Section 6 maps the regulatory demand catalysts and their implications for pricing and timing. Section 7 sets out the structural requirements that any institutional implementation of the hedge thesis must meet.

Figure 1. Three independent studies converge on the same hedge utility. Sources: Nottingham (2022); GIC/EDB Singapore/McKinsey (2021); Ortec Finance (Nov 2024).

Climate risk as a portfolio-level threat

Climate risk is not a future externality awaiting realization. It is a present, measurable, and actively modeled source of portfolio value impairment. The major classes of institutional allocator (pension funds, sovereign wealth funds, and insurers) have moved beyond debating whether climate risk is real and are now engaged in the more operationally consequential question of how to manage it within their existing risk frameworks.

Two distinct channels transmit climate risk to portfolio returns. Transition risk operates through the policy and market mechanisms by which economies decarbonize: carbon pricing, regulatory mandates, technological displacement, and shifts in capital allocation and consumer preference. Physical risk operates through the direct economic damage caused by a changing climate: extreme weather events, sea-level rise, heat stress on labor and agricultural productivity, and the cascading effects of these disruptions on supply chains, insurance markets, and sovereign creditworthiness. Both channels produce portfolio-level repricing. But they differ in timing, in the precision with which they can be modeled, and, critically for the investment thesis developed in this paper, in the directness with which they can be hedged.

1.1 Transition risk: the repricing mechanism

Transition risk is the more immediately actionable channel for institutional hedging because it operates through a quantifiable price signal: the cost of carbon. As jurisdictions impose or tighten carbon-pricing regimes, carbon-intensive assets face earnings impairment through multiple simultaneous mechanisms. Direct cost imposition raises the operating expenses of emitters subject to cap-and-trade systems or carbon taxes. Demand substitution shifts consumption toward lower-carbon alternatives as the relative economics of carbon-intensive goods deteriorate. Stranded-asset recognition forces write-downs as reserves, infrastructure, and production capacity are repriced to reflect reduced economic viability under tightening carbon constraints. And the rising cost of capital increases the discount rate applied to carbon-intensive cash flows as lenders and equity investors incorporate transition risk into their underwriting.

These are not theoretical dynamics. In the jurisdictions most relevant to the institutional allocators targeted by this paper, carbon pricing is operational, binding, and intensifying. The EU Emissions Trading System (the world's largest cap-and-trade market) has been operational since 2005 and has entered its fourth phase (2021–2030), with EUA prices fluctuating between €60 and €80 per tonne through 2025 and consensus forecasts projecting continued increases toward €100 by 2027. The EU's Carbon Border Adjustment Mechanism entered its definitive compliance phase on January 1, 2026, extending carbon costs to imports of cement, steel, aluminium, fertilizers, electricity, and hydrogen, with scope expansion to downstream products proposed for 2028. A second EU ETS covering road transport, buildings, and small industry is scheduled to launch in 2028 (postponed from 2027 under the amended Climate Law), with BloombergNEF projecting allowance prices reaching €149 per tonne by 2030. Canada maintains a federal carbon pricing backstop alongside provincial cap-and-trade systems. Singapore has implemented and progressively increased its carbon tax. The direction of travel is unambiguous; the remaining uncertainty concerns the pace of implementation, not the trajectory itself.

The EU's 2040 climate target, a binding 90% reduction in net greenhouse gas emissions relative to 1990 levels formally adopted by the EU Council on March 5, 2026, provides a particularly clear illustration of the regulatory trajectory. The agreed framework includes a provision permitting member states to use high-quality international carbon credits for up to 5% of total emissions reductions from 2036 onward. This creates a new and substantial demand channel for correspondingly adjusted carbon units from outside the EU, a development with direct implications for the pricing of the asset class examined in this paper.

1.2 Physical risk: the amplifier

Physical climate impacts impose portfolio value impairment through asset damage, supply-chain disruption, sovereign credit deterioration, and insurance-market repricing. These impacts include acute events such as floods, droughts, wildfires, and storms, as well as chronic processes such as sea-level rise, heat stress, and agricultural yield decline. The NGFS has expanded its scenario framework to include granular acute physical risk data from 56 countries and now models damages from droughts and heatwaves in addition to cyclones and floods.

The economic magnitude of physical climate risk, however, remains more contested than that of transition risk. The damage function developed by Kotz et al. (2024), which underpinned the physical risk estimates in NGFS Phase V long-term scenarios, was retracted from Nature following academic critiques during post-publication review. The authors are resubmitting a revised version. The NGFS has noted that its short-term scenarios and previous phases of long-term scenarios are unaffected by the retraction and has cautioned that the economic effects of climate change might prove more severe than anticipated, particularly if tipping points are reached.

The precise economic quantification of physical climate damages remains genuinely uncertain, and the research community is actively working to refine it. What is not uncertain is the direction of impact. Physical risk imposes real economic costs; the global insurance industry's escalating catastrophe losses are empirical evidence of this, not modeled speculation. And for the investment thesis presented here, the precise magnitude of physical damages is less important than the second-order effect: physical risk intensification accelerates political pressure for transition action. Extreme weather events, insurance-market dislocations, and visible climate impacts create the political conditions in which carbon-pricing regimes are tightened and new compliance frameworks are activated. Physical risk, in this sense, is a reinforcing input to the transition risk thesis: a catalyst for the very policy acceleration that drives carbon prices higher and creates demand for the compliance-grade units that form the hedge.

Recent research from CPP Investments underscores this dynamic. In a 2025 report examining how public funds are addressing physical climate risks, CPP Investments observed that for much of the past decade, investors had ample reason to prioritize transition risk, given the clear policy environment anchored by the Paris Agreement. While noting that recent populist political developments have complicated the transition thesis in certain jurisdictions, the report emphasized that physical risk is increasingly functioning as an independent catalyst for policy response, creating a feedback loop between climate impacts and regulatory acceleration that institutional investors cannot afford to ignore.

1.3 Quantifying portfolio impact across transition pathways

The portfolio repricing projected by leading climate risk models are material by any standard of institutional risk management. Ortec Finance, in its November 2024 assessment of the top 30 US pension funds, found that short-term climate risks (2025–2030) are dominated by transition risk, with the most extreme transition scenario projecting a 19% reduction in investment performance. In the long term, physical risks were found to have the greatest negative impact on investment portfolios compared to other climate-related risks. The study concluded that the greatest harm to a pension fund's investment portfolio is likely to arise from either drastic and uncoordinated short-term policy changes or a long-term failure to undertake the low-carbon transition; both of which, notably, produce environments in which carbon prices spike.

GIC and McKinsey, using Planetrics' bottom-up climate scenario analysis platform, modeled the impact of transition risks on an illustrative global equity portfolio across transition scenarios. Their analysis found that climate-related repricing affects portfolios unevenly across sectors and within sectors, creating pockets of concentrated loss that simple portfolio-level metrics may understate. Funds interviewed by CPP Investments for its 2025 report described using scenario analysis to assess macroeconomic impacts on portfolios, examining GDP and inflation effects through models including the National Institute Global Econometric Model (NiGEM) and the NGFS framework, while acknowledging that current scenario tools tend to underestimate the full impact of climate-related physical risks and that misalignment between the time horizons of physical risks and investment cycles creates analytical blind spots.

The NGFS scenarios themselves have evolved from a policy tool for selected users to what the network describes as a common language for climate risks used by financial institutions, policymakers, and other stakeholders globally. The latest NGFS Guide to Climate Scenario Analysis (2025 update) notes that since the first Guide was published in 2020, climate scenario analysis has moved from an emerging topic to a critical tool for risk management, strategic planning, and policy design. The institutionalization of climate risk modeling is itself significant: it means that the carbon price signal embedded in these frameworks is now a standard input to portfolio construction, asset allocation, and stress testing across the global institutional investor base. What remains largely unaddressed is the obvious corollary: that if the carbon price signal is material enough to model, it should be material enough to hedge.

If the carbon price signal is material enough to model, it should be material enough to hedge.

How allocators model carbon risk – and what their models imply

The institutional investment community has moved well beyond qualitative acknowledgment of climate risk. Over the past five years, a robust and increasingly standardized infrastructure for quantifying climate-related portfolio exposures has emerged, anchored by the NGFS scenario framework and supplemented by proprietary tools from analytics providers and internal modeling teams. The result is that the carbon price signal, which is the mechanism through which transition risk converts into changes in portfolio value, is now a standard, quantified input to portfolio construction, strategic asset allocation, and regulatory stress testing for most major institutional allocators.

2.1 The institutional risk modeling landscape

The NGFS climate scenarios, first published in 2020, have become the dominant reference framework for climate risk assessment. The NGFS itself reports that 95% of respondents who have completed scenario-based exercises are at least partially satisfied with the outcomes, and that the scenarios are now used across a widening variety of applications, from bank supervisory stress tests to pension fund strategic asset allocation to insurer solvency assessments. The latest NGFS Guide to Climate Scenario Analysis, updated in 2025, describes climate scenario analysis as having moved from an emerging topic to a critical tool for risk management, strategic planning, and policy design.

Within this framework, carbon prices function as endogenously determined variables that translate policy ambition into economic impact. Under the NGFS Net Zero 2050 scenario, shadow carbon prices rise sharply to reflect the policy tightening required to limit warming to 1.5°C. Under delayed transition scenarios, carbon prices remain low in the near term but spike abruptly when belated policy action is imposed, creating precisely the kind of non-linear repricing event that is most damaging to unhedged portfolios.

The carbon price is the transmission variable.

Beyond the NGFS framework, allocators deploy complementary tools. MSCI's Climate Value-at-Risk framework provides firm-level and portfolio-level estimates of transition and physical risk exposure. GIC and Planetrics (McKinsey Sustainability) have published a bottom-up methodology that assesses transition impacts at the individual company level and aggregates them to the portfolio, revealing that climate-related repricing varies substantially not only across sectors but within them; this is a finding that complicates simple portfolio-decarbonization strategies. Internal shadow carbon pricing, in which allocators apply an assumed carbon cost to portfolio holdings as part of their own underwriting and valuation processes, is increasingly common and further embeds the carbon price signal into investment decision-making.

2.2 The implied carbon price and the structural short

These models share a common structural feature that is underappreciated in its investment implications: they embed a carbon price signal that correlates positively with policy tightening and negatively with the returns of carbon-intensive portfolio holdings. When the modeled carbon price rises (because transition policy accelerates, because physical risk triggers a policy response, or because a compliance deadline approaches), the model projects repricing of carbon-intensive equities, fixed income, and real assets. The carbon price is the transmission variable.

This creates what is, in economic terms, a structural short position. The portfolio's value declines as carbon prices rise. The allocator has modeled this relationship, quantified it, stress-tested it, and disclosed it. What the allocator has typically not done is acquire the offsetting long position that the model itself implies. The portfolio bears the full downside of carbon repricing, through impaired earnings, elevated discount rates, and stranded-asset recognition, without holding any instrument whose value moves mechanistically with the carbon price signal. Incidental gains in carbon-light holdings are idiosyncratic and unreliable; they do not constitute a systematic offset.

The analogy to interest rate risk is instructive. An allocator who modeled the sensitivity of portfolio returns to interest rate movements but declined to hold any fixed-income instruments, or any interest rate derivatives, would be understood to be running an uncompensated exposure. The same logic applies to carbon. The risk is modeled. The price signal is quantified. The transmission mechanism is understood. The hedge instrument exists. The position is not held.

The risk is modeled. The price signal is quantified. The transmission mechanism is understood. The hedge instrument exists. The position is not held.

This is not an argument that carbon exposure should replace existing risk management tools. It is the more precise argument that carbon exposure fills a specific gap in the current toolkit: it provides direct exposure to the underlying risk factor that the allocator's own models identify as the driver of projected repricing. The sections that follow examine why the existing toolkit fails to fill this gap, and what characteristics a carbon hedge instrument must possess to fill it effectively.

The hedge gap – why current approaches fall short

Institutional allocators have not been passive in the face of climate risk. Over the past decade, a substantial array of strategies has been deployed under the broad heading of climate risk management. These strategies are not without value; several achieve meaningful objectives. But none of them provides what the risk models demand: direct exposure to the carbon price signal that drives projected portfolio repricing. This section examines the most commonly deployed approaches and identifies their common structural deficiency.

3.1 Portfolio decarbonization

Portfolio decarbonization, the reduction of portfolio-level carbon intensity through divestment from or underweighting of high-emission assets, is the most visible and widely adopted climate risk strategy. Its logic is intuitive: if carbon-intensive assets are expected to lose value as transition policy tightens, reducing exposure to those assets reduces the portfolio's transition risk.

The strategy achieves something real, but it achieves something different from hedging. Decarbonization is a risk-reduction strategy, not a risk-transfer strategy. It lowers the portfolio's sensitivity to carbon repricing but does not create any position that gains value when repricing occurs. In a transition scenario where carbon prices rise sharply, a decarbonized portfolio loses less than a non-decarbonized one; but it still loses. There is no offsetting gain.

Decarbonization is a risk-reduction strategy, not a risk-transfer strategy.

Decarbonization also introduces secondary costs that are rarely weighed against the risk reduction it provides. It creates tracking error relative to standard benchmarks, which is a governance concern for allocators with benchmark-relative mandates. It introduces concentration risk by reducing the investable universe. And it may impair returns if carbon-intensive assets are repriced slowly, non-linearly, or not at all over the allocator's investment horizon.

There is a further limitation to this strategy that is often overlooked: even a fully decarbonized portfolio remains exposed to the systemic and macroeconomic consequences of carbon repricing. A sharp increase in carbon costs propagates through the broader economy via input price inflation, supply chain disruption, GDP drag, and financial market volatility; these effects impact portfolio returns through channels that have nothing to do with the carbon intensity of the portfolio's own holdings. An allocator who has decarbonized ahead of the market has reduced direct exposure to carbon-intensive assets, but still holds assets (sovereign bonds, real estate, diversified equities, credit) whose values are sensitive to the macroeconomic dislocation that an abrupt transition can produce. Decarbonization addresses the idiosyncratic carbon risk of individual holdings; it does not address the systematic carbon risk that affects asset prices economy wide. A direct carbon position addresses both.

3.2 ESG integration and tilts

ESG integration (incorporating environmental, social, and governance factors into security selection and portfolio construction) has become standard practice across most institutional allocators. In its climate-specific application, ESG integration typically involves screening portfolios for carbon intensity, climate transition readiness, or alignment with temperature pathways, and tilting allocations toward companies with stronger ESG profiles.

ESG is a quality filter, not a carbon hedge.

The limitation is one of precision. ESG factors are broad, multi-dimensional, and imprecisely correlated with the specific carbon price signal that drives transition risk in portfolio models. A company can score well on aggregate ESG metrics (strong governance, good labor practices, community engagement) while remaining materially exposed to carbon repricing through its direct emissions, supply chain, or end-market demand. Conversely, a company with a low ESG score may have limited carbon exposure. The correlation between ESG scores and portfolio sensitivity to carbon price movements is positive but weak, unstable across time periods, and dependent on the specific ESG methodology employed.

3.3 Clean-technology and green venture investment

Allocating capital to clean-technology ventures, renewable energy infrastructure, and green growth opportunities has become a significant component of many institutional climate strategies. These investments are valuable; they finance the technologies and infrastructure required for the transition. But they are a growth thesis, not a hedge thesis.

Clean-tech investments carry idiosyncratic project risk: technology commercialization uncertainty, regulatory and permitting risk, competitive dynamics, and execution risk. Their returns are driven by technology adoption curves and commercialization success, not by carbon price movements. A clean-tech portfolio can underperform severely in a scenario where carbon prices rise sharply, if, for example, the policy mechanism chosen is a carbon tax rather than technology subsidies, or if the specific technologies in the portfolio lose out to competing solutions.

The distinction between this unreliable correlation and the carbon hedge proposed in this paper is structural, not merely statistical. Utility-grade carbon units are not a proxy for regulatory tightening; they are the instruments that regulatory frameworks demand. When CORSIA requires airlines to offset emissions, it requires correspondingly adjusted carbon units; the price of those units rises as a direct consequence of the obligation. When a government performs a corresponding adjustment under Article 6.2, it creates a sovereign-level claim on the unit that anchors its value to the regulatory framework itself. The correlation between regulatory tightening and the value of these units is not observed after the fact; it is engineered into the design of the instruments and the frameworks that consume them.

Utility-grade carbon units are not a proxy for regulatory tightening; they are the instruments that regulatory frameworks demand.

More fundamentally, clean-tech investments respond to carbon repricing events through intermediated and delayed transmission channels. When a carbon price moves (because a compliance deadline triggers, because an ETS cap tightens, or because a new regulatory framework activates), the impact on clean-tech asset values is mediated by technology adoption dynamics, subsidy regime adjustments, competitive repositioning, and market re-rating processes that unfold over quarters or years, not days or weeks. By contrast, the value of utility-grade carbon units is mechanistically tied to the regulatory frameworks that drive repricing. While current liquidity constraints in the high-quality carbon market mean that NAV is printed quarterly (carbon remains a Level 3 asset under fair-value accounting), the structural alignment between the hedge instrument and the risk factor is direct and verifiable at each valuation point. As trading volumes and exchange infrastructure develop, valuation frequency will improve; the underlying mechanistic linkage does not depend on it.

3.4 Engagement and stewardship

Active ownership and engagement (using shareholder influence to encourage portfolio companies to reduce emissions, set science-based targets, and improve climate disclosures) is a well-established institutional practice. GIC, for example, has publicly described its approach of engaging with companies on transition plans rather than bluntly divesting, on the basis that direct engagement builds richer understanding of future risks and leads to more beneficial long-term outcomes.

Engagement is a legitimate and potentially effective long-term strategy for reducing portfolio-level climate risk. But it is not a hedge. Its effects operate on multi-year timescales, depend on company-level execution, and produce uncertain and difficult-to-quantify outcomes. Engagement does not provide portfolio-level protection against a systemic carbon repricing event: a sudden tightening of carbon pricing policy, a regulatory deadline activation, or a shift in market risk premia. When the carbon price moves, engagement cannot respond in kind.

3.5 The common deficiency

Each of these approaches addresses a real facet of climate risk. Decarbonization reduces exposure. ESG integration improves portfolio quality. Clean-tech investment finances the transition. Engagement influences corporate behavior. But none of them provides what the allocator's own risk model says is needed: systematic, direct exposure to the carbon price signal.

Consider the position of an allocator who has implemented all four strategies simultaneously. The portfolio has been decarbonized, ESG-integrated, allocated to clean-tech, and the portfolio companies have been engaged. In a scenario where carbon prices rise sharply (because CORSIA Phase II activates, because the EU ETS cap tightens, or because a CBAM-equivalent mechanism is adopted in a major trading partner), this allocator's portfolio still suffers net value impairment. Individual holdings may benefit incidentally from carbon repricing, but these gains are idiosyncratic, unreliable, and not systematically linked to the carbon price signal at the portfolio level. The portfolio has no position whose value appreciation is mechanistically driven by the carbon price increase itself.

Now consider the same allocator with an additional 1% allocation to utility-grade carbon units. In the same scenario, that 1% position appreciates in value as the carbon price rises, because the units have compliance utility within the very regulatory frameworks that are driving the repricing. The gains in the carbon position offset some or all of the value impairment elsewhere in the portfolio. This is hedging in the financial sense of the term: holding a position whose payoff is systematically and mechanistically linked to an identified risk exposure.

The distinction is not subtle, and it is not semantic. It is the difference between managing a risk and hedging a risk. Everything in the current institutional toolkit manages climate risk. Nothing in it hedges climate risk in a systematic way, because nothing in it provides direct, mechanistic exposure to the underlying risk factor. An allocator who models interest rate risk holds fixed-income instruments. An allocator who models currency risk holds currency hedges. An allocator who models carbon risk holds, in most cases, nothing.

An allocator who models interest rate risk holds fixed-income instruments. An allocator who models currency risk holds currency hedges. An allocator who models carbon risk holds, in most cases, nothing.

Figure 2. The hedge gap. Existing climate strategies manage risk; none of them transfers it.

The direct hedge – carbon as an investable risk factor

If the carbon price signal is the transmission mechanism through which transition risk impairs portfolio returns, then the natural hedge is an instrument whose value rises as the carbon price rises. Carbon units, specifically those with compliance utility within binding regulatory frameworks, are that instrument. This section examines the empirical evidence for the hedging relationship and the characteristics that make carbon a distinctive risk factor.

4.1 The correlation structure

The hedging relationship between carbon and carbon-intensive equities is grounded in mechanism, not merely in statistical observation. The same policy actions that impose costs on emitters (tighter ETS caps, higher carbon taxes, new CBAM obligations, CORSIA compliance requirements) create value in carbon markets by increasing the price of emissions allowances and eligible credits. This inverse dynamic is structural: it follows from the design of carbon-pricing regimes, not from coincidental market behavior. When a government tightens a carbon cap, the cost to emitters rises and the value of a corresponding carbon unit rises. The repricing of carbon-exposed assets (equities, fixed-income securities issued by carbon-intensive corporates and sovereigns, and real assets) and the gains in carbon positions are two expressions of the same policy event.

This distinguishes carbon from other assets that are sometimes proposed as climate hedges. Green bonds, clean-energy equities, and catastrophe bonds are each influenced by climate-related factors, but their correlation with the carbon price signal is indirect, unstable, and mediated by numerous other variables: interest rates, technology risk, weather patterns, issuer-specific factors. Carbon exposure is the only instrument whose value moves mechanistically with the risk factor that institutional models identify as the driver of transition repricing.

4.2 Empirical evidence

The empirical literature, while still developing, provides supportive evidence for the hedging thesis.

The most directly relevant study for institutional portfolio construction is the work by researchers at the University of Nottingham, published in Energy Economics in 2022, which analyzed carbon credit futures as a hedging and diversification tool for equity portfolios using dynamic conditional correlation (DCC-GARCH) models. The study found that including a small portion of carbon futures in a stock portfolio provides hedging benefits and reduces overall risk for a given level of expected return. Two findings from this study are particularly relevant. First, a €0.068 short position in carbon was shown to hedge a €1 long position in European equities over the sample period (2014–2021), implying that a very small carbon allocation provides meaningful hedge ratios. Second, adding carbon to a European equity portfolio reduced the modified Conditional Value-at-Risk by approximately 39%, a substantial reduction in downside risk from a marginal allocation.

Separately, GIC, the Economic Development Board of Singapore, and McKinsey & Company conducted bottom-up portfolio modeling using Vivid Economics' Planetrics platform, applying Monte Carlo simulation across 100,000 portfolio paths under climate transition scenarios. Their findings, published in 2021, indicated that a modeled carbon allowance allocation of 0.5–1% could mitigate the negative impact of climate transition risk on the returns of a 60/40 reference portfolio. In the same modeling, a 5% carbon allocation enhanced expected annual returns by 50–70 basis points relative to the expected return for a regular reference portfolio of approximately 4%, while reducing modeled portfolio volatility by 30–50 basis points relative to expected volatility of approximately 9.8%. These results held under immediate and delayed transition scenarios: precisely the conditions under which the hedge is most needed.

4.3 Why carbon, not carbon proxies

The distinction between direct carbon exposure and carbon-adjacent investments deserves emphasis because it is frequently conflated. Clean energy equities are sometimes characterized as a carbon hedge, on the theory that clean energy benefits from the same policy tailwinds that raise carbon prices. The correlation exists but is unreliable: clean energy equity returns are driven by technology risk, subsidy regimes, interest rate sensitivity, competitive dynamics, and execution risk, all of which can dominate the carbon price signal. A portfolio of clean energy stocks can decline in value even as carbon prices rise if, for example, interest rates increase simultaneously, or if a favored technology loses competitive ground.

Green bonds face a similar limitation. While they finance environmentally beneficial projects, their return profile is that of a fixed-income instrument, driven primarily by credit spreads and interest rates rather than by carbon price movements. The correlation between green bond returns and carbon prices is weak and inconsistent.

Direct carbon exposure, whether through compliance allowances, eligible carbon futures, or utility-grade credit positions, eliminates this intermediation. The value of the instrument moves with the carbon price because the instrument is the carbon price, denominated in a tradable and regulatorily anchored form. This directness is the source of its hedge effectiveness.

4.4 Allocation sizing

The evidence suggests that the allocation required to achieve meaningful hedge utility is small relative to total portfolio size, a finding that should reduce governance friction for allocators considering a carbon position. The GIC/McKinsey analysis demonstrated hedge utility at 0.5–1% of portfolio value, with enhanced risk-return characteristics at 5%. The Nottingham study's hedge ratio (€0.068 per €1 of European equity exposure) implies that the capital required for a meaningful hedge is modest. For a large pension fund or sovereign wealth fund, a 1% allocation to carbon is a small absolute position that can be funded from the alternatives or risk-hedging sleeve without material reallocation of existing strategies.

In practice, institutional deployment of a carbon hedge typically begins at a fraction of the full hedge ratio implied by the studies above. The reasons are twofold. Decarbonisation programmes already in place reduce direct exposure to carbon-intensive holdings, lowering (though not eliminating) the modeled transition exposure; the residual macro and systemic transition risk that decarbonisation cannot reach is the principal target of a direct carbon position. Hedge sizing is also itself a material factor in strategy design, since many hedge instruments behave well at certain scales and degrade at others, and initial deployments at a fraction of the full hedge ratio allow strategy behaviour to be verified through real compliance activation before capital is scaled toward the modeled exposure. Initial allocations on the order of 0.01–0.05% of portfolio value, scaling toward the empirically-supported 0.5–1% hedge ratio over multiple deployment cycles, is the conventional path.

This is an important practical observation. Carbon hedging does not require a wholesale revision of portfolio strategy. It requires a marginal allocation, comparable in size to many tactical overlay positions, that addresses a specific, modeled, and disclosed risk exposure. The governance burden is proportionate; the risk-management benefit is disproportionate.

Not all carbon is equal – the case for utility-grade units

The investment case developed in the preceding sections depends on a critical assumption: that the carbon exposure acquired has genuine regulatory utility; that it is demanded by compliance frameworks, not merely valued by voluntary market sentiment. This section draws a deliberate and sharp distinction between utility-grade carbon units and the broader voluntary carbon market, and argues that this distinction is not a quality preference, but rather the mechanism through which hedge utility and alpha are created.

5.1 The integrity problem in voluntary markets

A substantial body of evidence questions the environmental integrity of carbon credits as traditionally understood. A 2024 study published in Nature Communications, covering over 2,300 carbon mitigation projects representing nearly one billion tonnes of CO₂e in issued credits, estimated that fewer than 16% of the credits in the investigated sample constitute real emission reductions. The study found wide variance across project types, with particularly poor outcomes for wind power and improved forest management projects.

A 2025 analysis published in PNAS Nexus examined the systemic drivers of overcrediting in voluntary markets and concluded that without structural reforms (realigning incentives, enhancing transparency, and tightening accountability), the market for offsets will remain prone to fundamental flaws. The authors noted that each actor in the credit supply chain is financially incentivized to maximize the volume of credits rather than their veracity, creating conditions for persistent bias.

These findings are not peripheral critiques. They describe systemic features of the voluntary carbon market that undermine the thesis for generic carbon credit exposure as a portfolio hedge. A credit that does not represent a real emission reduction has no defensible claim to compliance utility and no reliable basis for price appreciation driven by regulatory demand. It is, in economic terms, a certificate with uncertain and potentially zero intrinsic value: a poor foundation for a hedge instrument.

5.2 What makes a unit utility-grade

The units relevant to the investment thesis presented in this paper are categorically different from the credits described above. A utility-grade carbon unit, as defined here, must meet three cumulative requirements.

First, the unit must satisfy the seven substantive requirements established by Article 6.2 of the Paris Agreement (Decision 2/CMA.3, Annex, Appendix I) for internationally transferred mitigation outcomes. The emission reduction or removal must be real (quantified against a realistic, defensible, and conservative baseline, with avoidances excluded), additional (made possible only with financing from the program), quantified and verified by an independent third party using transparent and conservative methodologies, and permanent (with measures to monitor, mitigate, and compensate any risk of reversal). The underlying program must not cause net harm (it must comply with all laws, regulatory requirements, and international obligations of the sovereign sponsor), must not cause leakage (no increase in emissions elsewhere, with monitoring and compensation measures for any leakage risk), and must not be double counted (emissions reductions are counted once, with corresponding adjustments ensuring the unit is uniquely attributed in the global accounting system). These seven requirements, drawn from the Paris Agreement's rules, modalities, and procedures and supplemented by the Cancun Agreements safeguards (Decision 1/CP.16), constitute the minimum integrity threshold for utility-grade carbon.

Second, the host country must have authorized the unit under Article 6.2 of the Paris Agreement and performed a corresponding adjustment in its national emissions accounting. This is the critical differentiator. A corresponding adjustment means that the host country has removed the emission reduction from its own national inventory and transferred the claim to the acquiring party. The unit is provably unique in the global accounting system; it cannot be double-counted by both the host country (toward its Nationally Determined Contribution) and the acquirer (for compliance or hedging purposes).

Third, the unit must have demonstrated or prospective eligibility within a binding compliance framework. The relevant frameworks, as of early 2026, include CORSIA (where eligible emissions units must carry a Letter of Authorization from the host country with a corresponding adjustment), the EU's Fit for 2040 mechanism (which permits use of high-quality international credits from 2036, with a pilot period from 2031–2035 under consideration), and bilateral ITMO transactions under Article 6.2, which permits transfers both between governments and to non-state actors for "other international mitigation purposes" (governments including Japan, Switzerland, Singapore, and Sweden are actively acquiring correspondingly adjusted units, and the mechanism is expressly open to institutional participants).

These three requirements are cumulative. A unit that is verified but not correspondingly adjusted carries double-counting risk and lacks the regulatory demand anchor. A unit that is correspondingly adjusted but has no compliance pathway may have environmental integrity but lacks the demand-side certainty that drives pricing. Only units meeting all three criteria have the characteristics required for a reliable portfolio hedge: their value is anchored to regulatory demand, not to voluntary sentiment, and that demand is legislated, time-bound, and scaling.

Figure 3. The three cumulative gates that separate utility-grade units from generic carbon credits.

5.3 Corresponding adjustment as the quality threshold

The corresponding adjustment mechanism deserves particular attention because it is both the least understood and the most consequential feature of the post-Paris carbon market architecture. Before Article 6 became operational, the global carbon credit system permitted (and in many cases facilitated) double-counting: a credit-generating country could count the emission reduction toward its own climate targets while simultaneously selling the credit to a buyer who also counted it. This systematically overstated global mitigation and undermined the environmental and economic integrity of carbon credits.

Corresponding adjustment eliminates this. When a host country issues a Letter of Authorization and performs a corresponding adjustment, it forgoes the use of that emission reduction toward its own Nationally Determined Contribution; its NDC accounting must absorb a commensurate offset. The unit moves from the host country's NDC ledger to the acquirer's account. This is not merely an accounting convention; it is a sovereign commitment with direct implications for the host country's NDC compliance under the Paris Agreement.

The practical consequence for investors is that correspondingly adjusted units sit on fundamentally different economic footing than non-adjusted credits. They are scarce in a way that generic credits are not (because issuing them imposes a real cost on the host country in the form of reduced NDC compliance headroom). They are demanded by compliance frameworks that explicitly require corresponding adjustment: CORSIA, the EU's 2040 mechanism, and bilateral ITMO agreements. And their pricing is anchored to the compliance value of the regulatory frameworks they serve, not to the voluntary willingness-to-pay of corporate sustainability departments.

5.4 Implications for fund design

The quality threshold described above has direct implications for the design of any investment vehicle that claims to provide a carbon hedge for institutional portfolios. A fund that acquires non-correspondingly-adjusted credits (regardless of their environmental credentials) is not structurally aligned with the hedge thesis. Such credits lack the regulatory demand anchor that drives compliance-grade pricing, and their value proposition rests on voluntary market sentiment, which is discretionary, cyclical, and subject to reputational risk.

The discipline of investing exclusively in utility-grade units (verified, correspondingly adjusted, and compliance-eligible) is not a marketing distinction. It is the mechanism through which risk-adjusted alpha and hedge utility are created. The supply-demand dynamics that underpin the pricing thesis (examined in the next section) operate specifically in the market for correspondingly adjusted units, where supply is constrained by the sovereign cost of issuance and demand is driven by binding regulatory obligation. This is a fundamentally different market from the voluntary carbon credit market, and the two should not be conflated by investors, by allocators, or by fund managers.

The regulatory demand catalyst

As currently implemented through long-only exposure (the only practicable strategy given current market liquidity), the hedge thesis requires that carbon unit values appreciate over time as regulatory demand materializes. As the market matures and exchange-traded derivatives develop, short positioning could enable hedging against carbon price declines, creating a true two-directional hedge instrument.

The demand catalysts examined in this section are not forecasts; they are legislated frameworks with published timelines, operational infrastructure, and binding compliance obligations. The question is not whether demand will emerge, but how quickly supply can respond.

Figure 4. The regulatory demand catalyst timeline. The relevant deadlines are legislated and approaching.

6.1 CORSIA Phase II (2027–2035): the first major compliance demand shock

The Carbon Offsetting and Reduction Scheme for International Aviation represents the most immediate and quantifiable demand catalyst for correspondingly adjusted carbon units. CORSIA's structure is worth examining in some detail because it illustrates precisely how regulatory demand creates pricing pressure for utility-grade units.

CORSIA entered its First Phase (2024–2026) with voluntary participation from 130 ICAO member states. Airlines with flights between participating states are required to offset emissions exceeding a baseline set at 85% of 2019 levels. The First Phase has already generated substantial compliance requirements: IATA estimates that airlines will need to purchase upward of 200 million eligible emissions units for the First Phase, at an estimated cost of \$4–5 billion. Fastmarkets' route-level modeling projects cumulative First Phase demand of 150–175 million tonnes.

The transition to Phase II in 2027 fundamentally changes the scale of demand. Phase II is mandatory for virtually all ICAO member states, with limited exceptions for least-developed countries and small island developing states. The inclusion of major aviation states (including countries that did not participate voluntarily in Phase I) expands covered emissions from approximately 64% to 87% of international aviation. Fastmarkets projects cumulative Phase II demand of 1–1.5 billion tonnes between 2027 and 2035, with annual offset requirements ramping from 62–88 million tonnes in 2027 to 166–257 million tonnes by 2035.

Critically, every CORSIA-eligible emissions unit must carry a Letter of Authorization from the host country and must be correspondingly adjusted under Article 6 of the Paris Agreement. This requirement is absolute; credits without CA are ineligible regardless of their environmental quality. This means that CORSIA demand flows exclusively into the market for correspondingly adjusted units, creating a direct pricing linkage between aviation compliance obligations and the value of the specific asset class examined in this paper.

The question is not whether demand will emerge, but how quickly supply can respond.

The supply side remains severely constrained. As of early 2026, only a handful of countries have issued Letters of Authorization for CORSIA-eligible units. Guyana's ART TREES program and a cookstoves project in Malawi under Gold Standard are among the very few projects to have issued credits with full CORSIA eligibility, with a combined supply of approximately 17 million units. A 2025 survey by PwC and IETA found that 67% of respondents expect an undersupply of eligible credits by 2027. Fastmarkets projects that cumulative supply of CORSIA-eligible credits between 2028 and 2030 could reach 300 million tonnes in an optimistic scenario; but in a constrained scenario characterized by continued authorization bottlenecks, available supply may lag forecast demand for several years.

The pricing implications are significant. Sylvera's scenario modeling projects CORSIA credit prices of \$25–36 per tonne by 2027 under moderate supply assumptions, with prices exceeding \$60 per tonne in supply-constrained scenarios. Fastmarkets estimates prices of \$30–45 by 2030. For context, voluntary market pricing for high-integrity credits currently sits at approximately €7–15 per tonne. The gap between current acquisition cost and projected compliance-grade pricing represents the price convergence opportunity at the core of the alpha thesis.

Figure 5. CORSIA Phase II annual offset obligation (2027–2035) against current cumulative CORSIA-eligible supply.

6.2 The EU's 2040 framework: a home-jurisdiction demand signal

For European institutional allocators, the most consequential regulatory development is the EU's formally adopted 2040 climate target and its explicit provision for high-quality international carbon credits.

On March 5, 2026, the EU Council formally adopted amendments to the European Climate Law, establishing a binding intermediate target of a 90% reduction in net greenhouse gas emissions by 2040 compared to 1990 levels. The amended law includes a provision permitting member states to use high-quality international carbon credits (sourced through Article 6 of the Paris Agreement) to make an adequate contribution of up to 5% of 1990 EU net emissions toward the 2040 target, starting from 2036. This means that at least 85% of emissions reductions must be achieved domestically, but the remaining 5% may be sourced from correspondingly adjusted international units.

The scale of this demand channel is substantial. EU-27 net greenhouse gas emissions in 1990 were approximately 4.0 billion tonnes of CO₂e (European Environment Agency). Five percent of that figure represents approximately 200 million tonnes annually, a demand channel comparable in magnitude to the cumulative annual issuance of correspondingly adjusted units across the entire global pipeline at present scale. The provision is binding within the EU Climate Law architecture and is the only mechanism by which member states may meet their 2040 obligations through external mitigation.

Equally significant for near-term positioning is the provision under consideration for a pilot period from 2031 to 2035, designed to establish and test the operational infrastructure for a high-quality international credit market before the formal compliance period begins in 2036. The European Commission launched a public consultation in February 2026 on the framework for international credit use, inviting input on quality criteria, acquisition mechanisms, and governance structures. This consultation process will produce the detailed rules that determine which units qualify; the clear signal from the adopted legislation is that corresponding adjustment and Paris Agreement alignment will be prerequisites.

For European institutional allocators this development is particularly significant because it creates a demand catalyst within their own regulatory jurisdiction. The argument for carbon exposure is no longer premised solely on external compliance frameworks (CORSIA, bilateral ITMO markets) operating at some remove from the allocator's home environment. The EU's own climate architecture now explicitly anticipates, authorizes, and creates demand for the asset class. The political risk of the thesis, the concern that regulatory demand could be reversed, delayed, or diluted, is materially reduced when the demand catalyst is embedded in the Climate Law of the allocator's own jurisdiction, adopted with binding legal force after multi-institutional legislative process.

The EU's own climate architecture now explicitly anticipates, authorizes, and creates demand for the asset class.

Moreover, the EU 2040 framework interacts with existing EU carbon market infrastructure in ways that amplify the demand signal. The EU ETS, which has been operational since 2005 and currently prices allowances at approximately €60–80 per tonne, provides an observable reference price for the cost of carbon within the EU. CBAM, which entered its definitive compliance phase on January 1, 2026, extends carbon costs to imports and explicitly links certificate pricing to EUA auction clearing prices. The planned revision of the EU ETS in 2026, which will address the potential integration of permanent carbon removals, cap adjustments, and possible linkage with other carbon markets, further tightens the overall supply of compliance instruments. BloombergNEF projects ETS prices reaching €149 per tonne by 2030. Consensus forecasts compiled across institutional analysts project EU ETS allowance prices of approximately €85 per tonne in 2026, crossing €100 by 2027, and trending toward €126 or higher by decade-end.

This pricing trajectory for EU compliance instruments provides a ceiling toward which correspondingly adjusted international credits will converge as the 2040 framework becomes operational. The current gap between voluntary market pricing for high-integrity credits (€7–15 per tonne) and EU compliance pricing (€60–80 per tonne and rising) represents a structural dislocation that the 2040 framework is explicitly designed to begin closing.

Figure 6. The price convergence window. Voluntary acquisition cost vs. compliance market clearing price.

6.3 Bilateral ITMO markets: establishing price references and infrastructure

In parallel with the multilateral frameworks, a growing number of bilateral Article 6.2 agreements are creating transactional infrastructure and establishing early price references for correspondingly adjusted units. Switzerland has been among the most active, executing bilateral agreements with multiple host countries and completing ITMO transfers. Japan has signed bilateral agreements and Japanese airlines (JAL and ANA) were the first operators to publicly retire CORSIA-eligible credits. Singapore's carbon tax regime and its active participation in Article 6 markets create a substantial demand channel. Singapore's landmark 2025 Article 6 tender attracted 17 bidders with pricing in the \$19–41 per tonne range (approximately €18–38), and resulted in a contracted procurement of 2.175 million tonnes at an average price of approximately \$25.50 per tonne (€23–24). Singapore's 2035 NDC targets emissions of 45–50 MtCO2e, and the government has stated its intention to use ITMOs under Article 6 to cover residual emissions reductions, with estimated annual ITMO requirements of approximately 2.5 million tonnes through 2030. Sweden has been a consistent participant in early Article 6 transactions.

These bilateral transactions serve a market-building function beyond their individual volumes. They establish precedent for sovereign authorization processes, create reference pricing for CA-eligible units, demonstrate the operational feasibility of the corresponding adjustment mechanism, and generate the institutional learning that will accelerate future issuance. Each successful bilateral transaction reduces the novelty risk of the asset class and expands the universe of potential supply.

The structural driver behind bilateral demand is the marginal cost of domestic abatement. Once a country's low-cost domestic abatement options are exhausted, the next tonne of emissions reduction comes at progressively higher cost (often a substantial multiple of the bilateral ITMO price), at which point international acquisition becomes the cost-rational compliance pathway. The countries identified above (Switzerland, Japan, Singapore, Sweden, Norway) all share this profile: limited remaining domestic abatement supply against binding NDC and net-zero commitments. Their bilateral programs are not aspirational; they are operational and extending over multi-decade horizons because the alternative, exclusively domestic abatement, is economically infeasible at the required scale. Countries outside the EU that operate binding compliance frameworks will, under the same marginal-cost logic, find international credits a more cost-effective compliance pathway than domestic abatement alone. This is a structural demand source parallel to, and not contingent on, the EU 2040 mechanism.

6.4 The supply-demand imbalance

Aggregating across the major demand sources (CORSIA, the EU 2040 framework, bilateral ITMO acquisitions, and corporate net-zero commitments requiring CA-grade retirement) total demand for correspondingly adjusted carbon units is projected to reach levels that substantially exceed current and foreseeable supply.

On the demand side, CORSIA alone is projected to require 1–1.5 billion tonnes cumulatively through 2035 (Fastmarkets). The EU 2040 international credit allowance, once activated, will add approximately 200 million tonnes annually from 2036. Bilateral ITMO acquisitions by Japan, Switzerland, Singapore, Sweden, and others, together with corporate net-zero commitments calling for CA-grade retirement, contribute further volume. On the supply side, only approximately 17 million tonnes of Article 6.2-authorized units have been brought to market to date; current sovereign authorization processes constrain the rate at which additional supply can be generated. Host-country governments with surplus NDC capacity have a clear economic incentive to monetize their natural capital assets through Article 6 authorization, but the institutional infrastructure required to do so at scale (authorization processes, registry systems, bilateral frameworks) is still being built. This infrastructure friction is the rate-limiting factor on supply expansion.

The path from sovereign intent to verified, authorized, deliverable supply at scale runs five to ten years in practice. Indonesia announced its Article 6 framework in 2020; cumulative authorized supply remains in the low single-digit millions of tonnes, and other major potential supplier countries are at earlier stages still. The constraint is operational, legal, and administrative; it is not theoretical, and it applies in every host country that has attempted to scale authorization. The supply-demand gap is therefore not a transient feature of a market in early development; it is a structural feature of the time required for sovereign authorization infrastructure to mature against legislated demand, on a horizon measured in decades rather than years.

The resulting supply-demand imbalance is acute. Against approximately 17 million tonnes of currently authorized supply, combined compliance demand by 2036 is projected at more than 400 million tonnes annually, more than twenty times current authorized supply. This scarcity is the structural driver of price appreciation as compliance activation proceeds.

The defensibility question for an institutional allocator is not whether the headline demand figures will be precisely realized but whether the demand-to-supply ratio remains sufficient to support pricing at the scale of capital actually deployed. Sensitivity to absolute demand assumptions emerges only at multi-billion-euro deployment scales, which are downstream of an initial validation cycle and would be sized against verified rather than assumed demand. The thesis at proof-of-concept scale is robust to substantial uncertainty in the demand projections.

6.5 The price convergence window

The market for utility-grade carbon units exhibits a current pricing dislocation that is unusual in its magnitude and in the directness of its underlying mechanism. High-integrity voluntary market credits (the raw material from which correspondingly adjusted, compliance-eligible units are produced) currently trade at approximately €7–15 per tonne. The compliance markets into which these units will be absorbed price carbon at €30–100+ per tonne, depending on jurisdiction and vintage.

This gap exists because Article 6 infrastructure is still scaling, authorization processes are not yet standardized, and compliance buyers are in the early stages of procurement planning. As CORSIA Phase II activates in 2027, as the EU 2040 pilot period is designed and implemented, and as bilateral ITMO markets mature, the gap will close. The same units will be demanded for compliance use at prices anchored to compliance market clearing levels, not to voluntary market sentiment.

The convergence is not instantaneous, and the timing is subject to the pace of authorization infrastructure development. But the direction is structurally determined: demand for CA-eligible units is legislated and mandatory; supply is constrained and slow to scale; and the clearing price for compliance instruments (€60–100+ in the EU ETS) provides a well-established reference toward which eligible international credits will converge.

The pricing dynamic produces an asymmetric risk-return profile for allocators establishing a carbon position now. The downside is bounded by the voluntary market floor, which itself is supported by corporate demand for high-integrity credits. The upside is anchored to compliance market pricing levels that are multiples of current acquisition cost. The timing catalysts (CORSIA Phase II in 2027, EU 2040 pilot period from 2031, formal EU credit use from 2036) are legislated. The hedge thesis is conditional on the carbon-price linkage to policy intensity continuing to hold; the carbon-specific failure mode is a coordinated rollback of binding compliance regimes across multiple major jurisdictions, a scenario in which the broader portfolio's transition risk is also reduced. As with any investment, the position bears general macroeconomic risk on the same basis as the rest of the portfolio; it is not a strategy-specific exposure.

Implementation – the institutional access problem and its solution

The preceding analysis establishes that direct exposure to utility-grade carbon units provides an efficient hedge against transition risk, that a convergence of regulatory catalysts creates favorable entry conditions, and that the quality threshold (verified, correspondingly adjusted, compliance-eligible) is the mechanism through which hedge utility and convergence return are generated. A remaining question confronts the allocator who accepts this analysis: how, practically, to acquire and hold the exposure.

Four structural barriers have historically prevented institutional allocators from acting on the carbon hedge thesis, even where the analytical case is accepted.

First, utility-grade carbon exposure is governed by fragmented regulatory regimes and registries that sit entirely outside standard capital markets infrastructure. Carbon units are not securities. They are not cleared through standard custodians. They are not traded on exchanges familiar to institutional investors. The operational infrastructure required to acquire, hold, and transact in them is specialized and unfamiliar.

Second, maintaining utility-grade carbon exposure requires continuous monitoring, verification, and authorization tracking. The status of a correspondingly adjusted unit depends both on sovereign-level processes (host country authorization, registry transfers, NDC accounting) and on the underlying physical integrity of the project from which the unit was issued. Both must be tracked across multiple jurisdictions simultaneously. This operational intensity is difficult to replicate in-house at institutional scale.

Third, most allocators cannot directly hold, custody, and operationally manage carbon units at scale within their existing governance and risk frameworks. Investment committee mandates, custodian arrangements, risk systems, and reporting infrastructure are designed for securities, not for carbon instruments. Acquiring direct carbon exposure typically requires governance approvals, operational build-outs, and risk system modifications that impose substantial internal costs.

Fourth, existing carbon investment vehicles are structurally misaligned with the hedge thesis. Traditional carbon funds are built for impact outcomes or offset procurement; they own or originate credits for retirement, not for packaging hedge exposure into institutional allocation workflows. Their risk profiles carry equity-style project volatility (permitting risk, land risk, political risk) that does not behave like a hedge. And they do not typically provide the insurance-wrapped delivery assurance, authorization monitoring, and multi-jurisdiction execution that utility-grade hedge exposure requires.

Resolving these barriers requires a purpose-built operational stack with six structural components. The specific legal wrapper (regulated fund, separately managed account, internal mandate, or other format) is secondary to these components; the legal structure is a question of allocator preference, while the components below are a question of viability.

First, a regulated holding structure. The exposure must sit inside a vehicle that integrates with institutional governance, valuation, and risk reporting, whether a Luxembourg RAIF or comparable AIFMD-supervised structure for fund-based deployment, or a custodian-controlled separately managed account for balance-sheet deployment. Either path satisfies the same requirement: institutional auditability of holdings, net asset value, and compliance status.

Second, bankruptcy-remote custody. Carbon units must be held in a structure that ringfences them from the operational risk of any service provider, with title certainty equivalent to that of securities custody. Foundation-based structures operated by specialist carbon custodians (CSC Global being the largest) achieve this in a way that conventional securities custodians cannot, because the underlying assets are not securities and therefore sit outside the standard custody perimeter.

Third, insurance-backed risk transfer on the acquisition contracts. Forward purchase agreements and emission reduction purchase agreements (FPAs and ERPAs) typically have small, regionally concentrated counterparties whose balance sheets do not pass institutional credit committee review. Inserting an investment-grade insurance counterparty, most plausibly via Lloyd's syndicate cover on delivery and authorization risk, converts the credit exposure into one that institutional risk frameworks already know how to assess.

Fourth, geospatial diligence and continuous position monitoring. The integrity events that have driven public confidence problems in the voluntary carbon market (deforestation, methodology breaches, host nation policy shifts, biomass loss) are typically detectable in primary geospatial data well before they surface in annual verification cycles. A purpose-built operational stack must therefore underwrite each acquisition against satellite-derived biomass models, dMRV outputs, jurisdictional registry data, and forward-looking physical risk overlays (CMIP6 or equivalent) at the point of acquisition, and continue that surveillance after acquisition, with automated exception alerting on integrity events as they occur rather than at scheduled verification windows. This is not a peripheral feature. The credibility of the hedge depends on the credibility of the underlying units; the credibility of the units depends on diligence that exceeds developer self-reporting.

Fifth, sovereign authorization intelligence. The compliance utility of a correspondingly adjusted unit is contingent on the host country's Article 6 authorization remaining in good standing. Monitoring this requires continuous tracking of NDC accounting, bilateral agreement status, host-country policy stability, and the operational status of each project's Letter of Authorization across multiple jurisdictions. This intelligence layer is one of the variables most directly determinative of realized hedge value.

Sixth, institutional regulatory reporting. For European allocators, SFDR Article 9 disclosure, PCAF financed-emissions accounting, and CSRD compatibility are not optional. Any vehicle holding utility-grade carbon for institutional accounts must generate these outputs automatically from primary data (including the geospatial evidence underlying each unit's integrity), so that the allocator's own disclosure obligations are met without bespoke internal reconciliation. The same applies to ISSB S1/S2 reporting for non-EU institutional accounts.

These six components are the structural floor for institutional carbon hedge exposure. A vehicle that omits one of them is not suitable. A vehicle that satisfies all six can be implemented under multiple legal wrappers, depending on the allocator's preference for fund subscription, separately managed account, or internal mandate. The thesis is structure-neutral; the operational requirements are not.

Balance what you model with what you hold.

The argument presented in this paper can be reduced to a single observation: portfolios that model carbon risk without owning carbon exposure are structurally incomplete.

Portfolios that model carbon risk without owning carbon exposure are structurally incomplete.

Institutional allocators have invested substantially in the infrastructure to quantify climate risk: NGFS scenarios, Climate VaR frameworks, shadow carbon pricing, stress testing. These tools consistently identify the carbon price signal as the transmission mechanism through which transition risk impairs portfolio returns. Yet the offsetting position (direct exposure to the carbon price) is absent from most institutional portfolios. The prevailing toolkit manages carbon risk: it reduces exposure, improves portfolio quality, and finances alternatives. But it does not transfer carbon risk. A direct carbon position converts risk management into risk transfer: it creates a payoff systematically linked to the risk factor, providing portfolio-level offset rather than mere portfolio-level reduction.

The regulatory demand catalysts that underpin the hedge thesis are not speculative. CORSIA Phase II is mandatory from 2027. The EU's 2040 Climate Law, formally adopted on March 5, 2026, explicitly authorizes the use of high-quality international carbon credits for up to 5% of the 2040 target from 2036, with a pilot period from 2031 under consideration. Bilateral ITMO markets are operational and scaling. These frameworks create binding, non-discretionary demand for correspondingly adjusted carbon units: the specific asset class that provides hedge utility.

The quality threshold is clear. Only units that are verified, correspondingly adjusted under Article 6 of the Paris Agreement, and eligible for compliance use within binding regulatory frameworks carry the demand-side anchor required for a reliable hedge. The broader voluntary carbon market does not meet this threshold, and exposure to it should not be confused with the instrument described in this paper.

The allocation required is small. Evidence from GIC/McKinsey and the University of Nottingham demonstrates hedge utility at 0.5–1% of portfolio value, a marginal allocation that can be funded from existing risk-hedging or alternatives sleeves without material restructuring.

Current acquisition costs for high-integrity credits are a fraction of the compliance market pricing toward which correspondingly adjusted units will converge as CORSIA, the EU 2040 framework, and bilateral markets activate.

The question for institutional allocators is not whether carbon exposure belongs in a risk-managed portfolio. Their own models have already answered that question. What remains is the decision to take a position whose payoff is mechanistically linked to the same carbon price signal against which the portfolio is modeled.

AeonLoop advises on the design of institutional carbon hedge structures against the requirements set out in Section 7. For further information, write to info@aeonloop.com.

Andrew Gilmour

Founder & Managing Partner, AeonLoop

Andrew Gilmour designed Sovereign Carbon Securities and founded AeonLoop to make that architecture available to any government or institution that needs it. He founded Laconic Infrastructure Partners Inc. and served as its Chief Executive Officer, and designed Sovereign Carbon Securities there. The structure was selected by The Bahamas for its blue carbon monetization program.

His work sits at the intersection of structured finance, sovereign engagement, and compliance-grade carbon markets. He advises on Article 6.2 program design, corresponding adjustment and permanence obligations, CORSIA eligibility, institutional fund architecture, and the accounting treatment that determines whether an institution can hold an environmental asset at all.

He writes and speaks publicly on carbon market structure. He was the keynote speaker at the Singapore Carbon Market & Investor Forum in 2024, appeared at the Milken Institute Global Conference in 2025, and spoke at the First International Conference on Sustainability in the Judiciary in Brasília in 2024. His TEDx talk, How AI and financial innovation could save the planet, makes the case to a general audience. Between 2023 and 2025 he produced more than one hundred long-form pieces on natural capital finance and compliance carbon markets, reaching approximately 144,000 subscribers.

He holds a BA from the University of Chicago and is based in Chicago. Full biography at aeonloop.com/about/andrew-gilmour.