Why FERC Transmission ROE Incentives Are No Longer Guaranteed

A guaranteed profit margin that has sat inside utility rates for over two decades is now under coordinated attack, and the people leading the charge are the same state governments that once tolerated it.

In September 2026, regulators across the northeast moved almost in unison to strip major grid operators of a half-percentage-point bonus on their returns. The trigger was legislation these same states had just passed.

Within months, Connecticut, Maine, Maryland, and New Jersey each enacted laws forcing transmission owners to participate in regional grid organisations. Then three of those states walked into the Federal Energy Regulatory Commission and used the new mandates to argue the bonus should disappear.

The logic is deceptively simple. If a state now requires grid membership, the regulators contend, there is nothing left to reward.

For anyone holding transmission-heavy utilities, the FERC transmission ROE incentives at the centre of this fight are no longer a footnote in a rate filing. They are a live variable in your earnings model.

This piece covers the legal mechanics of the state complaints and gives you a framework for judging how the clash could reprice infrastructure assets sitting in your portfolio.

The legal syllogism threatening utility margins

The states have built their case as a clean chain of logic, and the appeal of that logic is exactly what makes it dangerous for utility returns.

The Maine Public Utilities Commission and associated agencies filed a Federal Power Act Section 206 complaint at FERC on 1 September 2026, targeting the 0.5% return on equity adder collected by Central Maine Power (a subsidiary of Avangrid), Versant Power, and Maine Electric Power Co. (MEPCO) for their membership in the regional grid operator, ISO New England.

The Maine state agencies’ Section 206 complaint filed on 1 September 2026 anchors its case explicitly in LD 2038, the 2026 state law mandating ISO-New England participation, arguing that the mandate extinguishes the voluntariness on which the adder’s legal justification rests.

Section 206 is the provision that lets FERC investigate whether an existing rate has become unjust or unreasonable. That is the door the states are walking through.

Connecticut’s Attorney General and state agencies filed a parallel complaint earlier in 2026, aimed at Eversource and Avangrid. Maryland agencies followed with their own filing, citing the state’s newly passed participation law.

Here is the syllogism the complainants are advancing:

• The Federal Power Act empowers FERC to set just and reasonable rates and to grant incentives that encourage beneficial conduct.
• The adder was expressly justified as a reward for voluntary participation in a grid organisation.
• Once state law mandates that participation, no voluntary conduct remains to incentivise.
• Continuing to pay the adder therefore conflicts with its original purpose and renders the rate unjust and unreasonable.

The New England States Committee on Electricity (NESCOE), which represents the region’s governors, reinforced the argument in a 21 September 2026 filing supporting the Maine complaint. NESCOE urged FERC either to cap the adder at a three-year maximum or eliminate it entirely, describing the payment as a windfall stacked on top of the base return without driving any behaviour.

The utilities are not conceding the point. Central Maine Power, MEPCO, and the Edison Electric Institute (EEI) filed opposition comments on 21 September 2026, characterising the state laws as unlawful intrusions on FERC’s exclusive authority over interstate transmission pricing.

Their counter rests on Section 205 of the Federal Power Act, which utilities argue grants them the right to join or exit a grid organisation and to set the rates they file with FERC.

The speed of this offensive is the real signal for you. State legislatures weaponised brand-new statutes against federal returns within months of passage, which tells you that political pressure over electricity bills is now overriding the older regulatory truces you may have assumed were stable. That hostility belongs in any forecast of future utility cash flows.

Energy security mandates have increasingly become the lever through which state governments reshape federally regulated markets, and the RTO participation laws passed by Connecticut, Maine, Maryland, and New Jersey follow the same structural template: states enact a policy objective, then use the resulting mandate to challenge the federal compensation that predated it.

Understanding the ROE adder and RTO participation

To judge what is actually at stake, you need to understand what this adder is and where it came from, because its origin story undercuts the idea that it was ever permanent.

Return on equity, or ROE, is the profit rate FERC allows a utility to earn on the capital its shareholders have invested in transmission assets. The adder is an extra 0.5% (50 basis points) layered on top of that base return, awarded specifically for belonging to a regional transmission organisation (RTO) or independent system operator (ISO).

FERC approved the 50-basis-point adder for RTO membership in New England in 2004. It was framed as compensation for transmission owners voluntarily handing day-to-day operational control of their systems to an independent grid operator.

The word that mattered was voluntary. The incentive existed to nudge utilities into giving up control they did not have to surrender.

That nudge quietly hardened into an entitlement. NESCOE observed in 2020 that although FERC claims to grant the adder only when justified, in practice the Commission has typically awarded it to almost any utility that joins or already belongs to a grid organisation.

The financial mechanics are straightforward. The adder sits on top of the base ROE, that combined return flows into the transmission tariff, and consumers ultimately pay it through their bills.

The dollar figures give you a sense of scale. According to the Maine PUC’s September complaint, the adder tied to Central Maine Power and Versant added roughly $6 million to charges across New England in 2024, with Maine ratepayers carrying about $700,000 of that.

FERC’s own past decisions complicate the utilities’ case, because the Commission has already refused the adder where participation was mandatory.

The takeaway for your valuation work is that a payment utilities have treated as a fixture was engineered as a behavioural incentive. If you have been modelling these adders as guaranteed, the history suggests you should be treating them as contingent instead.

The financial friction between ratepayers and capital providers

This dispute pits two legitimate objectives against each other, and the tension is sharpest precisely because the timing is so awkward for the grid.

On one side sit the states, which view the adder as an unjustified charge that inflates household electricity bills for behaviour the law now compels. On the other sit utilities and their investors, who rely on stable, predictable returns to justify committing capital to enormous transmission projects.

Rising energy costs are the political engine behind these complaints; state governments are under constituent pressure to reduce electricity bills, and challenging transmission adders is one of the few levers available to them within the federal rate-setting system without triggering a full restructuring of FERC jurisdiction.

The Edison Electric Institute has argued that pulling the incentive would inject regulatory unpredictability at the worst possible moment, just as grid expansion becomes a national priority. EEI also contends that eliminating the adder ignores the benefits Maine has drawn from ISO-NE membership and the real risks transmission owners carry as participants.

The Edison Electric Institute perspective Removing the incentive increases regulatory unpredictability at a time when expanded transmission investment is considered necessary. An inconsistent, case-by-case approach to incentive availability could carry implications extending well beyond any single complaint.

The pressure is not confined to New England. In June 2025, three regional state committees, the Organization of MISO States (OMS), the Organization of PJM States (OPSI), and the Southwest Power Pool Regional State Committee (SPP-RSC), filed a joint letter in FERC’s transmission incentive proceeding declaring the organisation ROE adder unsupportable and stating they did not support it existing at all.

That coalition tells you the sentiment behind these complaints stretches across multiple grid regions, not just the northeast.

The capital allocation risk

Sudden changes to embedded expected returns do something specific to long-lived assets: they reset the risk profile after the capital has already been committed.

Transmission projects are expensive, take years to build, and carry heavy permitting and construction risk. When utilities and investors have baked the adder into their financing assumptions, removing it midstream directly trims projected earnings from projects already in service or on the drawing board.

Coverage from 2025 noted utility warnings that capping the extra ROE at three years or ending it outright could reduce their income by millions annually.

The likely investor response is straightforward. If explicit adders vanish and regulatory risk climbs, you and other capital providers may demand higher base ROEs to compensate, which raises the cost of capital for the entire build-out.

The broader read for you is uncomfortable. Stripping this incentive could prompt utilities to slow, shrink, or reprioritise the complex multi-state projects the grid modernisation story depends on, which means the timelines you have penciled in for electrification-driven infrastructure growth may need to stretch.

Jurisdictional risks and precedents watching FERC

Treating this as a regional squabble would be a mistake, because the outcome will function as a national template for how transmission returns are set.

The California and Ohio precedents matter because FERC has already applied the exact logic the states are now invoking. In both states, the Commission denied the adder on the grounds that mandatory participation left nothing to incentivise, and complainants in Maine, Connecticut, and Maryland are citing those decisions as directly on point.

The complication is that the state mandates themselves are not settled law. FERC Commissioner Mark Christie noted in a 7 July 2026 public post that Connecticut’s participation law is being challenged in federal court on statutory and constitutional grounds.

That opens a second front. If courts find that state mandates improperly intrude on FERC’s rate-setting authority, the entire foundation for these complaints could wobble, leaving transmission compensation in limbo regardless of how FERC rules.

The DOE emergency grid order targeting Duke Energy in September 2026 illustrates how federal agencies are reaching beyond settled legal boundaries to direct grid outcomes, a posture that sits in uncomfortable parallel with the state-level campaign against transmission ROE adders.

As of late September 2026, the Maine and Connecticut dockets remain at the filing-and-comment stage, with no FERC order on the merits publicly reported. That means three broad outcomes are still in play:

1. FERC denies the complaints and preserves the adder, treating it as compensation for the ongoing burdens of grid participation rather than a pure voluntariness reward.
2. FERC revokes the adder in the mandating states, extending the California and Ohio logic and setting a precedent other RTO regions can copy.
3. Federal courts strike down the state participation mandates, unravelling the legal basis for the complaints before FERC even reaches a final decision.

The expanding roster of state regulators lining up against these adders is the warning you should act on. This strategy is spreading beyond New England, which means you should be screening your national utility holdings, particularly transmission-heavy names, for the same exposure before the next domino falls.

Navigating utility valuations during regulatory shifts

The core conflict is a collision between state governments determined to cut electricity costs and a federal system built to encourage the grid investment those same states will eventually need.

While the FERC dockets remain unresolved, the sensible frame is to treat the RTO participation adder as an at-risk earnings component rather than a permanent fixture, and to identify which utilities and regions carry the heaviest reliance on it. Transmission owners in states that have already mandated participation sit closest to the line of fire.

The larger shift is the one worth internalising. The era of near-automatic regulatory incentives is giving way to a period of aggressive, state-led margin compression, and that changes how transmission-heavy utilities should be valued going forward.

Energy transition volatility is reshaping utility valuations through multiple simultaneous channels: policy reversals, state-federal jurisdictional conflicts, and demand forecasts that shift with electrification timelines, all of which make static discounted cash flow models increasingly unreliable for transmission-heavy names.

This article is for informational purposes only and should not be considered financial advice. Investors should conduct their own research and consult with financial professionals before making investment decisions.

Past performance does not guarantee future results. Financial projections and regulatory outcomes are subject to change based on FERC decisions, court rulings, and various risk factors.