4AUG

FERC commits to June 2026 grid-load order

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10:53UTC

The Federal Energy Regulatory Commission pledged on 16 April to act by end of June 2026 on Docket RM26-4-000, the rulemaking that will set how electricity loads above 20 MW connect to the US interstate grid.

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Key takeaway

FERC's June order is the only federal counter-escalation to the muni-tier consent freeze.

On 16 April 2026, the Federal Energy Regulatory Commission (FERC, the US federal electricity regulator) pledged to act by end of June 2026 on Docket RM26-4-000, the rulemaking that will standardise how new electricity loads above 20 MW connect to the US interstate transmission grid. The proceeding was opened by Energy Secretary Chris Wright under Section 403 of the DOE Organisation Act in October 2025, and on 16 April Deputy Secretary James Danly issued a statement commending the announcement. FERC said the order would be 'quick, efficient, and legally durable'.

Legal analysis from Mayer Brown identifies three contested questions in the docket: whether hyperscalers can bypass standard interconnection studies for accelerated review, how behind-the-meter solutions are treated for grid-exit cost allocation, and who pays for the upgrades large loads trigger. The behind-the-meter ruling determines whether projects copying Pure DC's Dublin microgrid template still pay their share of transmission upgrades; the cost-allocation ruling determines whether the trigger load pays alone or the wider ratepayer base picks up the bill. Mayer Brown's reading is that cost allocation drives the largest economic effect, and that whichever way the commission lands, the bypass and study-process answers tend to follow that choice.

The proceeding will bind every US RTO and ISO (Regional Transmission Organisation and Independent System Operator). It cannot reach ERCOT, the Texas grid which sits outside both the Eastern and Western Interconnection. That asymmetric reach is exactly why operators trying to escape the federal layer have begun routing capacity into West Texas already. The municipal moratoriums in Maine, Seattle, and Northern Virginia cannot rewrite federal interconnection rules; only FERC can, and the order arrives in eight weeks. For projects facing the UK's structural ceiling, where 50 GW of data-centre demand sits behind 45 GW of national peak , there is no equivalent single-actor lever; for projects in PJM, MISO, SPP, NYISO, ISO-NE, or CAISO, the next eight weeks will define the cost basis for every new application.

Deep Analysis

In plain English

FERC is the US federal agency that oversees the rules for how electricity flows across state lines and how large industrial facilities connect to the national grid. It announced it will set new rules by June 2026 for how large power users, like data centres that need more than 20 megawatts, get connected to that national grid. Before this rulemaking, each utility applied its own interconnection study process, producing timelines that ranged from 18 months (ERCOT) to seven years (PJM) for the same class of applicant. The new rules matter because they could either speed up data centre connections (if they allow shortcuts) or force data centres to pay more of the cost of grid upgrades (if they assign upgrade costs to the new load rather than existing ratepayers).

Deep Analysis

Root Causes

The US interstate transmission grid was designed in an era when large industrial loads grew incrementally (steel mills, aluminium smelters, semiconductor fabs) and were located adjacent to generation sources. Data centres have a fundamentally different location logic: they site near population centres and existing fibre density rather than near generation, which means they connect to distribution-level grid infrastructure not designed for their load profiles.

FERC's existing interconnection queue rules, codified in the pro forma Large Generator Interconnection Agreement, were written for generators connecting to the bulk power system, not for loads. The queue for loads above 20 MW has no equivalent standardised framework. RM26-4-000 is essentially writing the first national load-interconnection rulebook, which is why its three contested questions are genuinely novel and not resolvable by reference to prior FERC precedent.

What could happen next?

Opportunity
A favourable RM26-4-000 outcome on bypass and cost-allocation would reduce interconnection timelines for loads above 20 MW from the current 4-7-year queue to a compressed 18-24-month process, unlocking projects currently parked in the Northern Virginia, PJM, and MISO queues.
Risk
Incumbent utility litigation within 60 days of the final rule, seeking a preliminary stay, is the base-case outcome based on FERC's last three major interconnection reform orders; a successful stay would suspend the rule's effect for 2-4 years.

Source Landscape

This story draws on neutral-leaning sources

Primary parallel: FERC Order 888 (1996) opened wholesale electricity markets to non-utility generators and was challenged in court by incumbent utilities within months of issuance. The litigation ran six years before the DC Circuit upheld it in 2002.

FERC managed that delay by issuing interim guidance that allowed the market to develop while the litigation proceeded. The same 'issue and operate under interim guidance' model is available for RM26-4-000, which is why the June deadline is commercially significant even if the final rule faces court challenges.

Counter-parallel: FERC Order 2023 (2023), the most recent interconnection reform, required a 12-month technical analysis period before the final rule could take effect, and incumbent utilities immediately sought and obtained a partial stay in the DC Circuit. RM26-4-000 uses a different statutory pathway (Section 403 rather than the Federal Power Act Section 206 that Order 2023 used), which may give it greater resistance to a preliminary stay, but this has not been tested in court.

Consensus view: Energy law firm Stoel Rives partner Karen Norberg assessed that FERC's Section 403 authority, used by Energy Secretary Chris Wright to open the docket in October 2025, is broader than the standard Order 2023 interconnection reform framework because it bypasses the normal NOPR (notice of proposed rulemaking) process and allows a final rule within 12 months. The June 2026 deadline is therefore legally achievable and not a political commitment that could be deferred.

Counter-view: Institute for Energy Economics and Financial Analysis (IEEFA) grid analyst Dennis Wamsted argues that the three contested questions Mayer Brown identified are not procedural clarifications but substantive re-writes of how interconnection cost responsibility is allocated across existing ratepayers.

Any rule that allows hyperscalers to bypass standard interconnection studies necessarily transfers some upgrade costs to existing customers, which FERC's own precedent in Order 1920 (the long-term transmission planning rule finalised in May 2024) required be justified through a formal benefit-cost analysis. Wamsted expects litigation from incumbent utilities within 60 days of the final rule.

Key tension: Whether FERC can write a rule that accelerates large-load interconnection without triggering the incumbent utility litigation that stopped or delayed Orders 888, 2000, and 2023 in federal court, a pattern that has added 2-5 years to every major interconnection reform of the past three decades.

Sources:FERC

Mentions:Federal Communications Commission →Chris Wright →IEEFA →West Texas →ERCOT →Pure DC →Virginia →Maine →Dublin →Texas →Seattle →Northern Virginia →FERC Docket RM26-4-000 →James Danly →Mayer Brown →Department of Energy →FERC →DOE Organisation Act →

First Reported In

Update #2 · Maine veto, Seattle freeze, $725bn capex

FERC· 6 May 2026

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Causes and effects

This Event

FERC commits to June 2026 grid-load order

The single federal lever municipal moratoriums cannot reach; cost-allocation and behind-the-meter rulings will define hyperscaler economics across every grid except Texas.

Led to

ERCOT large-load queue passes 225 GW

FERC's June 2026 commitment on RM26-4-000 is structurally irrelevant to ERCOT, which sits outside FERC jurisdiction; this is the causal link making ERCOT's 225 GW queue a de facto attraction for operators seeking to escape federal rules.

Occurred 1 Apr 2026

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PJM faces Monday FERC tariff deadline

FERC's pledge to act on RM26-4-000 by end-June established the PJM 18 May filing deadline as the immediate regulatory precursor.

Occurred 18 May 2026

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DOE lets PJM switch off data centres

FERC's April pledge to settle RM26-4-000 by end-June created the regulatory backdrop against which the emergency order arrived first, pre-empting the formal rule.

Occurred 18 May 2026

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FERC delays its grid rule to 2027

FERC met its April pledge to act on RM26-4-000 by end-June but chose show-cause over direct rulemaking, extending the timeline it had promised to close

Occurred 18 Jun 2026

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Different Perspectives

Government of Odisha

Odisha signed a $1.5bn agreement with HCLTech and Sarvam AI on 24 July for a sovereign AI data centre in Bhubaneswar, targeting 2028 operations. While regulators elsewhere price developers out of the queue, Odisha is bidding state financial assistance to bring capacity in, betting the AI infrastructure boom is worth courting rather than rationing.

Switch Datacenters and Uithoorn

The developer, the municipality, Liander and dozens of greenhouse growers signed a waste-heat agreement letting a 60 MVA facility proceed under a provincial rule that bans sites above 5 MVA. The public-interest exception argues the site relieves rather than adds to grid congestion, working around a standing ban from inside rather than waiting for it to change.

Iskandar Puteri residents

Residents protested in February over falling water pressure they attribute to ZDATA's 300 MW construction; ZDATA disputes causation and has not yet resolved the dispute with its wastewater-only pivot. The complaint sits unadjudicated while the operator advertises compliance to state authorities the residents cannot address directly.

Microsoft

DC Byte reports Microsoft looking to the Nordics for new capacity while Dublin's regional share falls to 15 per cent, though this is a market-intelligence inference rather than a company statement. Microsoft keeps its existing Dublin cloud region, which is costly to relocate, while directing new investment where power is cheaper and the queue is shorter.

ISO New England

ISO-NE proposed excluding new large loads from its Installed Capacity Requirement entirely, forcing data centres to bring their own generation or accept curtailment, even though New England's demand has been flat or falling for a decade. The reform is pre-emptive, written before the region has felt the strain PJM and MISO already report.

Ofgem

Ofgem opened its Data Centre Commitment Fee consultation on 29 July, arguing that free options on grid capacity let developers bank places on ten sites and abandon nine, crowding out projects that would build. It expects the deposit to filter the queue before the rule even takes final form.