⚡ THIS WEEK'S SIGNAL
Five weeks after the Department of Energy (DOE) named its 31 speed-to-power transmission projects, I can't find a single signed agreement that DOE or a recipient has made public. That matters most out West. Projects wholly inside the Western grid, plus two links tying the Eastern and Western grids together, account for $800.9 million of the $1.89 billion, or 42%. A selection is a handshake, not a check. Until the paperwork clears, the speed is still theoretical.
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📰 MAIN STORY
The money has a name but not a signature. On September 24, DOE selected 31 projects for $1.89 billion under SPARK, its speed-to-power transmission program, and we read the national list in The speed-to-power money landed. California isn't on the list. DOE's program page still lists the expected award window as October 2026 through January 2027, and as of November 1 I could not find an executed agreement announced by DOE or any recipient. What has moved is the supporting cast: partners inside selected projects announcing their roles, a bit like announcing a new job before the offer letter arrives. This week is the Western read, because the West's share is bigger than the headline suggested.
Here is what each party is optimizing for. DOE wants capacity on lines that already exist, because new corridors take a decade. PacifiCorp, Berkshire Hathaway Energy's six-state utility, wants federal dollars against capital it would otherwise place entirely in rate base, the investment a utility earns a return on; its two divisions hold the two largest wholly Western selections. Cooperatives like Kit Carson Electric in Taos want upgrades their members could not finance alone. Two state agencies, Colorado's working with Xcel Energy and Oklahoma's with developer Grid United, want the Eastern and Western grids tied tighter. No hyperscaler is a party. Pacific Power's application says its project will enable new large-load interconnections in Washington and Oregon. Analysis: whoever those loads are gets headroom without signing anything.
Now the contrast. Alphabet reported $51.4 billion of property and equipment purchases for the quarter ended September 30, about $558 million a day (my arithmetic, over 92 days). DOE's federal share across all seven wholly Western projects is $300.9 million, roughly 13 hours of Alphabet's third quarter. The other $268.6 million comes from the recipients. For investor-owned utilities, that is capital in rate base, recovered from the customers already on those systems. For cooperatives, it is money members repay.
The numbers, from DOE's Selected Applications for DE-FOA-0003580 (SPARK):
Seven wholly Western projects: $300.9 million federal of $569.4 million total, a 52.8% federal share.
PacifiCorp: Rocky Mountain Power, $87.5 million of $175.1 million (Utah, Idaho, Wyoming); Pacific Power, $50.0 million of $105.5 million (Washington, Oregon). Together $137.5 million, 45.7% of the Western-only federal dollars, with $143.0 million in cost share.
The rest: Puget Sound Energy $40.2M of $80.4M; Kit Carson $38.1M of $50.8M; PNM $29.4M of $65.8M; Arizona Electric Power Cooperative $29.1M of $38.9M; NorthWestern Energy $26.5M of $53.0M.
The seam: Colorado's intertie project, $250 million of $1.21 billion; Oklahoma's Three Corners Connector, $250 million of $832.2 million. That is $500 million federal against $2.04 billion, a 24.5% federal share.
West plus seam: $800.9 million, 42.3% of the program (my arithmetic). No California utility is a prime applicant.
Scenario A: DOE executes the Western agreements by January with scopes intact. PacifiCorp's capital program gets federal dollars against $280.6 million of work, and the conductor and line-rating vendors behind it get a dated order book. Kit Carson's members carry a quarter of a $50.8 million project instead of all of it. Scenario B: negotiations slip past January or scopes shrink. The selections become what we tracked in 90 Gigawatts Announced, 2 Gigawatts Running: announced capacity. Recipients defer the work or fund it at full cost, so a Pacific Power customer in Oregon carries the whole project instead of half. Grid United's investors carry the most exposure, since Three Corners still needs land rights before construction.
The one thing to watch: whether DOE or any of the seven Western recipients announces an executed SPARK agreement before DOE's expected award window closes in January 2027.
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🧾 DEAL DECODER
The instrument: Three Corners Connector's SPARK selection, a state-prime award with a private subrecipient.
Who signs what. DOE and Oklahoma's Office of Management and Enterprise Services, the prime; Three Corners Connector LLC, Grid United's project company, is subrecipient. Not a rate case, and not yet a grant: DOE's Selected Applications marks every figure subject to a final agreement.
Who fronts the capital. The developer. DOE lists $832.2 million of project value against $250 million federal. That is the application's scope, not necessarily the full 300-mile line, and that blur is the decode.
Who eats the loss. The records I reviewed don't say. Whether the line recovers its cost from contracted customers or from regulated rates decides whether Grid United's investors or ratepayers in the Southwest Power Pool and Colorado hold that risk.
Precedent. The Oklahoma Corporation Commission issued a final order on the certificate application in July (Cause PUD2026-000004). A state prime works like a co-signer: it gets a developer to the table it could not reach alone.
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⚡ QUICK HITS
California held Google's 250 MW San Jose deal a fifth time, now to November 19. The California Public Utilities Commission (CPUC) hold list moved Resolution E-5455 off its October 29 agenda, as PG&E and Google filed a revised agreement adding a $150 million advance, the same $600,000 per megawatt the draft resolution asked for. For PG&E ratepayers, that advance is the cushion if the load arrives late or never, and it is the first California deal to be repriced while it waits for a vote. [CPUC hold list] [California Regulatory Intelligence]
Alphabet spent $51.4 billion on property and equipment in Q3 and posted negative free cash flow. Its October 28 release shows a quarterly free cash flow of –$9.1 billion, the second negative quarter in a row, and the company held its 2026 capital spending guidance at $195 billion to $205 billion while saying 2027 would be significantly higher. For retail investors holding Alphabet through index funds, the power needed to energize that spend runs through utility agreements like E-5455, not through Alphabet's own balance sheet. [Alphabet Q3 release] [CNBC]
California's grid operator approved its large-load rules and will file at FERC by November 16. The California Independent System Operator (CAISO) board approved the proposal on October 28, including a "flexible interim load interconnection" that lets large loads connect before network upgrades finish, subject to curtailment when the grid is constrained. This answers the open item from our October 13 issue; for utility planners, the new monthly review window for large-load upgrades is the piece that lands in next year's workplan. [APPA]
SPARK subrecipients are announcing roles before the agreements are signed. Pitch Aeronautics disclosed its Farmington, New Mexico, line-rating work on October 8, and Ameren announced its share of the same $75.6 million selection on October 28. Infrastructure investors tracking grid-technology vendors should read these as positions in a negotiation, not booked revenue. [Securities.io] [DOE selected applications]
🧭 THE EXPOSURE MAP
If you hold equities. Analysis: the parts of the value chain structurally exposed are advanced-conductor, line-rating and power-flow-control suppliers and the contractors who install them, whose revenue follows signed agreements rather than selections. The confirming or contradicting event is an executed agreement, then a recipient's next capital-plan update. Companies named here are participants in a structure, not recommendations.
If you run projects at a utility. If 31 projects sign inside one quarter, conductor, hardware and line crews get ordered at once. Can your organization say which of its own reconductoring jobs share a supplier or contractor with a SPARK recipient?
If you set or influence policy. The open precedent is how a commission treats the federal share in rates. The next venues are PacifiCorp's rate filings in Utah and Oregon, and the CPUC on November 19 for California's own version of who pays.
If you pay a utility bill or buy AI compute. Nothing here touches a bill this quarter. Cost share reaches you through transmission rates, typically one to three years after the spending, if a commission allows it.
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🔧 TOOL / RESOURCE OF THE WEEK
CPUC Voting Meeting Hold List: The commission's running list of agenda items pulled or postponed, with the new date and who held it. Ratepayers and consumer advocates following E-5455 can check it the day before November 19 to know whether California's Google vote is actually happening. → docs.cpuc.ca.gov
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💬 CLOSING THOUGHT
I'm cautiously optimistic about SPARK out West. Reconductoring is the fastest capacity there is, and the West got a real share. For that to hold, the agreements have to execute by January, and the matching half has to show up in rate filings as clearly as the federal half showed up in press releases.
Will the conductor and crew queue be ready if all 31 agreements land in the same quarter? I think a lot of us are about to find out.
