A week of delay on a 50 MW datacenter hall costs about $2.7 million. The liquidated damages clause in the transformer contract behind that hall pays back $74,000 for the same week, and stops paying after ten weeks. On a 2 MW plant the ratio is worse: $649,000 of lost value added, diesel and carrying cost against $13,300 of LDs. We pulled every liquidated damages clause we could find in public transformer, switchgear and genset contracts, priced a week of delay for both buyers from the Large-Load Cost Table, and compared the cap to what the vendor actually earns. This piece covers the clauses as written, the 0.5% a week and 5% cap norm, the cost of a week for a plant and a hall, the caps against OEM margins, what courts do with these clauses, and, behind the paywall, how to negotiate above the cap.
Source: Open Factory Large-Load Cost Table (compiled from BEA and EIA, Digital Realty Q4 2025 supplemental, Turner & Townsend DCCI 2025, Riverside bids SUB-871 and SUB-872, Ziegler Rental, Cat XQ2000 spec sheet, EIA diesel, Moody's Baa; as of July 2026)
The 2 MW plant loses $649,000 a week and recovers $13,300; the 50 MW hall loses $2.73 million and recovers $74,000, so the clause covers 2.0% and 2.7% of the weekly loss respectively.
What the Public Clauses Actually Say
Liquidated damages are a pre-agreed sum for a breach, usually late delivery, that replaces proof of actual loss. Under UCC 2-718 they are enforceable “only at an amount which is reasonable in the light of the anticipated or actual harm,” and “a term fixing unreasonably large liquidated damages is void as a penalty.” That sentence is the reason every clause is written low. The seller’s lawyer argues that anything above their margin is a penalty; the buyer’s lawyer, who cannot prove the future loss on a plant that does not exist yet, takes what is offered.
We read the eleven positions below in full. They come from City of Ocala’s two power transformer contracts (2023 and 2024), BrightRidge’s March 2026 transformer bid, the FAR, and the standard terms that Hitachi Energy, Eaton and Cummins attached to public quotes. Every one is in the Bid-Tab Price Book with its URL.
Source: Open Factory Bid-Tab Price Book (compiled from City of Ocala, BrightRidge, City of Santa Clara and FAR documents; as of July 2026)
Of the eleven, three buyers secured a rate and a 5% cap, two federal clauses set a per-day figure with no cap in the clause text, three OEM standard terms exclude liquidated damages entirely, and three seller clauses excuse or waive delay.
The 0.5% a week, 5% cap norm is real, and it is the seller’s number, not the buyer’s. When PTI Transformers bid $8,070,340 for two 105/140/175 MVA autotransformers for Ocala’s Dearmin substation in June 2023 (Virginia Transformer bid $16,168,895 for the same two units), PTI’s proposal fixed the buyer’s remedy at “0.5% per week to a maximum of 5% of the purchase price of the unit, the delivery of which has been delayed,” and then the lesser of that and “the actual liquidated damages suffered by Purchaser,” and then, in the document’s own words, “No harm no foul.” The clause only fires for delay “solely attributable to the negligence or willful act of Seller,” and PTI’s force majeure clause in the same proposal excuses “inability to obtain necessary labor, materials, manufacturing facilities, or supplies,” which in a 143-week transformer market covers most delays a buyer will ever see. The city’s own paper, in the executed agreement, sets $1,742 per calendar day for late substantial completion, about 0.30% a week on a $4.0 million unit, with no stated cap.
A year later Ocala bought three 25/33.3/41.6 MVA transformers from Virginia Transformer at $1,892,556 each. The contract requires delivery within 72 to 76 weeks against a stated “manufacturer’s standard lead times (96 to 136 Weeks),” sets LDs at “$500 PER DAY for the 25/33.3/41.6 MVA power transformer(s),” and caps them at “FIVE PERCENT (5%) of the offending unit contract value.” That is 0.18% a week. The same contract lets Virginia Transformer charge the city “a re-scheduling fee of THIRTY PERCENT (30%) of the specific order value” if the city’s delay loses the production slot, and pass through up to 6% of cost increases. The seller’s remedy for buyer delay is six times the buyer’s remedy for seller delay.
Source: Open Factory Bid-Tab Price Book
CSV: data/02b-ld-rates-and-caps.csv
Weekly rates run from 0.18% (Virginia Transformer, $500 a day on a $1.89 million unit) to 0.30% (Ocala’s own $1,742 a day) to 0.50% (PTI), and every stated cap is 5%.
BrightRidge, the Johnson City, Tennessee utility, put “$250 per day, not to exceed five percent (5%) of the purchase price of the unit” in its March 2026 bid form for a 30/40/50/56 MVA, 69:13 kV transformer, with the trigger at “Certification” ready for energization and the right to set the damages off against milestone payments. The federal government’s own clause, FAR 52.211-11, leaves the daily figure blank for the contracting officer and makes it payable “in place of actual damages”; FAR 11.501 tells that officer the rate “must be a reasonable forecast of just compensation” and that LDs “are not punitive.”
Then there is the paper the OEMs send. Hitachi Energy’s terms, attached to a 2024 WESCO quote for a 2,500 kVA pad-mount, say the company shall in no event “be liable for penalties or penalty clauses of any description.” Eaton’s terms on Silicon Valley Power’s switchgear orders exclude “LOSS OF PROFITS, LOSS OF REVENUE, LIQUIDATED DAMAGES, OR LOSS OF USE” and cap liability at the purchase price; we walked through the rest of that document in Reading a Switchgear Quote. Cummins’ Sourcewell terms on two 500 kW mobile gensets exclude “LIQUIDATED, OR CONSEQUENTIAL DAMAGES OF ANY KIND.” If your PO went out on the vendor’s quote form, this is your clause, and the RFQ checklist exists to stop that.
What a Week of Delay Costs a 2 MW Plant
The 2 MW case is the plant from The 2 MW Plant Service Upgrade: a 2,500 kVA pad-mount and a 15 kV metal-clad lineup, the lineup priced at Riverside’s $2,561,551.88 SUB-871 award and the pad-mount at about $98,000, a $2.66 million package. At 0.5% a week the LD is $13,300; the 5% cap is $133,000 and is reached in week 10. The Lead-Time Schedule puts the lineup at the end of the critical path, so a late lineup is a late plant.
The loss has four lines, all in data/02-cost-of-delay-weekly.csv. Lost output is the big one. We have no plant-specific margin, so we use the national average: BEA puts manufacturing value added at 9.4% of GDP in Q4 2025, or $2,954 billion on GDP of $31,423 billion, against EIA’s 1,042,217 GWh of 2025 industrial retail sales, which is $2.83 of value added per industrial kWh. A 2,000 kW plant at 60% load factor uses 201,600 kWh a week, so ~$571,000 of value added a week stands idle. An energy-intensive plant will be well under that figure; a machine shop or a pharma line will be over it.
Bridge power is the second line. A 2,000 kW rental unit listed at $33,945 a month at Ziegler is $7,800 a week bare; a full-service package in Houston runs $75,000 to $110,000 a month. Fuel dominates: the Cat XQ2000 burns 77.7 gallons an hour at 50% load, 13,054 gallons a week, and at EIA’s $5.134 a gallon for the week of July 20, 2026 that is $67,000 a week. The Genset TCO tool runs the same math at any load. Carrying cost on the stranded package at Moody’s Baa yield of 6.19% (July 2026) is $3,200 a week. If the electric service agreement has already started billing contract demand, AEP Ohio’s GS primary demand charge of $8.08/kW plus the $10.79/kW transmission rider adds $8,700 a week for nothing delivered; we leave that line out of the total because most ESAs start at energization.
Total: $649,000 a week against $13,300 of liquidated damages, a 49 to 1 ratio, and the clause stops paying at week 10. Even a buyer who throws out the value-added line and counts only diesel, rental and carrying cost is at $78,000 a week, six times the LD.
What a Week of Delay Costs a 50 MW Hall
The 50 MW case uses the Large-Load Cost Table inputs and the electrical package from Riverside’s SUB-872 award: three substation power transformers, two of them 45 MVA, from Delta Star at $14,878,322, bid opened April 16, 2026, awarded July 10, 2026, against Pennsylvania Transformer’s $15,175,278. At 0.5% a week that package yields $74,400 of LDs; the 5% cap is $744,000, the 10% cap $1.49 million.
Lost rent is the first line. Digital Realty’s Q4 2025 supplemental reports new Americas leases above 1 MW signed at $186 per kilowatt per month of annualized GAAP base rent, so a 50,000 kW hall forgoes $9.3 million a month, or $2.15 million a week. Carrying cost is the second: Turner & Townsend’s 2025 Data Centre Cost Index puts Phoenix and Columbus at $9.8 a watt, so a 50 MW build is $490 million, and at 6.19% that is $583,000 a week of interest on a building that cannot bill. The MEP Cost Table carries the same per-component view with each line’s lead time from the Lead-Time Monitor.
Total: $2.73 million a week against $74,400 of LDs, a 37 to 1 ratio. Bridging the hall on rental diesel instead of waiting does not change the order of magnitude: 25 rented 2 MW units are $196,000 a week bare and burn $1.68 million a week of diesel at 50% load, before permits, which is why the gas genset and turbine bridge market exists.
Source: Open Factory Large-Load Cost Table
CSV: data/04-cumulative-50mw.csv
At ten weeks late the hall has lost $27.3 million and collected $744,000; at twenty weeks it has lost $54.6 million and collected $1.49 million under a 10% cap, or still $744,000 under a 5% one.
The minimum-bill tariffs we mapped in What 50 MW Costs in 15 Markets make this worse, not better: AEP Ohio’s 85% minimum and Dominion’s GS-5 floor bill contracted capacity on a schedule the transformer vendor does not sign. The vendor’s exposure is 5% of its own price; the buyer’s is the tariff, the lease and the loan.
Why the Cap Sits Where It Does
The folk explanation for the 5% to 10% cap is that it equals the vendor’s margin: a vendor that pays the full cap on a contract has worked for free, and no rational vendor accepts a downside beyond zero profit. The procurement research file records the EPC version of the rule: contractors cap total LDs at 5% to 10% “because that is the contractor’s margin.” That was true for the people who wrote the first versions of these clauses. It is not true for the OEMs now signing them.
Source: Open Factory Book-to-Bill Table (compiled from FY2025 10-K and Q4 2025 8-K exhibits: ETN, CMI, HUBB, VRT, POWL, GNRC, GEV, EME; as of February 2026)
CSV: data/03-oem-margins-vs-caps.csv
Eaton’s Electrical Americas segment earned 29.9%, Cummins Power Systems 21.7%, Hubbell Utility Solutions 21.5%, Vertiv 20.4%, Powell 19.7%, Generac 17.0% and GE Vernova Electrification 14.9%, against EMCOR’s 10.1% and caps of 5% and 10%.
The filings are unambiguous. Eaton’s Electrical Americas segment posted $3,972 million of operating profit on $13,276 million of sales in 2025, a 29.9% margin, with backlog up 31%. Powell, which builds the switchgear lineups in these bid tabs, reported operating income of $217.9 million on $1,104.3 million in fiscal 2025, 19.7%, and its 10-K says plainly that “many of our customer contracts have schedule and performance obligation clauses that, if we fail to meet, could subject us to penalty provisions, liquidated damages or claims against us.” Hubbell’s Utility Solutions segment ran a 21.5% GAAP operating margin (24.1% adjusted). Cummins’ Power Systems segment posted EBITDA of 21.7% of sales in Q4 2025 on data center demand. GE Vernova’s Electrification segment, the grid equipment business, went from 9.0% to 14.9% EBITDA margin in a year with equipment backlog up 53%. The one company on the chart near the 10% line is EMCOR, an electrical contractor, at 10.1%.
A 5% cap on a 20% to 30% margin business means the vendor that delivers a year late still clears 15 to 25 points on your order. The cap did not move when the margins did, because the buyer who negotiates it is reading the vendor’s paper, not the vendor’s 10-K. The Book-to-Bill Table puts the segment margin next to the backlog for every public OEM, which is the number to have open when the vendor says the cap is all they can bear. The sellers’ side of the same asymmetry is visible in the clauses themselves: PTI’s cancellation schedule charges the buyer 5% at order, 40% once materials are ordered and 100% after vapour phase; Virginia Transformer charges 30% for a lost slot; Hitachi Energy’s quote bills $375 to $425 a week per transformer for storage if the buyer is not ready. Every one of those is uncapped or effectively so.
Source: Open Factory Bid-Tab Price Book
CSV: data/06-remedy-asymmetry.csv
In the same two Ocala contracts the seller’s charges for buyer delay are 30% (lost slot), 40% (cancellation after materials are ordered) and 100% (after vapour phase), while the buyer’s cap on seller delay is 5%, and the three OEM standard terms allow 0%.
What Courts Do With the Clause
Three things a buyer should know before signing, none of which the vendor’s form will tell you.
First, a clause written as liquidated damages is enforced as written, even when the actual loss is smaller. In California & Hawaiian Sugar v. Sun Ship (9th Cir. 1986, 794 F.2d 1433) a shipyard owed $17,000 a day for a late barge and paid it under Pennsylvania’s version of UCC 2-718 although the buyer’s provable loss was far below the total. In Wahlcometroflex v. Westar Energy (10th Cir. 2014, 773 F.3d 223), an equipment supplier to a Kansas power plant argued the utility had to prove that its “late delivery of equipment” caused the damages; the court held that under the clause Westar “did not need to establish” any such thing. In DJ Manufacturing v. United States (Fed. Cir. 1996, 86 F.3d 1130) the government withheld LDs from a supplier of field packs during Desert Storm and the Federal Circuit let it. The clause is a bargain, and courts hold both sides to it.
Second, the clause is usually the only remedy. FAR 52.211-11 says the damages are paid “in place of actual damages.” PTI’s clause is the “full aggregate amount.” Once LDs are the sole remedy for delay, the lost rent and the diesel are gone as a claim, which is why the cap matters more than the rate.
Third, UCC 2-719(3) lets a seller exclude consequential damages “unless the limitation or exclusion is unconscionable,” and between two businesses it almost never is. Eaton’s and Cummins’ exclusions will hold. A buyer who signs the vendor form has agreed that a $2.7 million week costs the vendor nothing.
The practical corollary sits in a Riverside staff report. In January 2026 Prolec GE Waukesha was the apparent low bidder on two 66 kV grounding transformers at $2,749,330.28, but conditioned its offer with a 30-day price hold and “exceptions to the City T&C’s”, confirmed both when asked, and was ruled non-responsive; Niagara Power Transformer took the $2,762,537 award. A public buyer with mandatory terms can hold the line for $13,207. A private buyer can too, but only if the terms are in the RFQ before the quote arrives.
What to Do Monday
Put the LD clause, the cap, the trigger and the sole-remedy language in the RFQ, not in the PO negotiation, and make acceptance of the terms a condition of a responsive bid, the way Riverside did. Compute your own week of delay before you open bids: lost output or rent, bridge power at the Genset TCO rate, carrying cost at your loan rate, and any minimum bill from the Large-Load Cost Table. Write that number into the recitals as the anticipated harm; under UCC 2-718 it is what makes a higher rate “reasonable” rather than a penalty. Run the vendor’s quoted lead time through the Lead-Time Schedule and the Lead-Time Monitor so the delivery date you are protecting is one the market can meet. Then price the terms against the quote with Quote Check: a vendor who will not accept 0.5% a week and a 10% cap on a 20% margin business is telling you where the schedule risk really sits.
Behind the paywall: the four ways to get above the 5% cap that vendors with 20% to 30% margins have accepted in public contracts, model language for each, and the order to redline them in so the 30% rescheduling fee in the vendor’s paper becomes the number that anchors yours.