Thursday, August 20 was a busy day in Austin. At 1:52 in the afternoon, three administrative law judges filed a Proposal for Decision recommending that the Public Utility Commission deny Oncor and LCRA Transmission Services' applications for two segments of the Permian import path — not on routing, not on cost, on need. Earlier the same day, at the Commission's open meeting, ERCOT collected the good cause exceptions it had asked for on the missed Batch Zero deadline, and then told commissioners the study will not be finished by April 9, 2027, and that it does not yet know what date replaces it.

Texas spent three years arguing about how quickly it could say yes. This week it worked through the various ways it can say wait. The practical effect is that a position in the queue is worth less than it was on August 1 and an energized meter is worth considerably more, and the market has already started quoting the spread.

"Still Working on What That New Timeline Might Be"

The procedural part went as scripted. ERCOT filed on August 10 in Project No. 59142 seeking good cause exceptions to three Planning Guide obligations — the missed August 7 Batch Zero classification deadline and the August 1 and November 1 quarterly stability assessments. On August 20 the Commission granted all three and authorized conditional Batch Zero classifications targeting August 31. I noted two weeks ago that ERCOT had asked and the Commission had not yet granted anything, and that this happens August 20. It happened August 20.

The unscripted part came next. Chad Seely, ERCOT's general counsel and chief compliance officer, told commissioners the Batch Zero study will not be complete by its April 9, 2027 deadline and that ERCOT is, as Community Impact reported it, "still working on what that new timeline might be." Every term sheet, seller note and construction-loan covenant written in Texas this year against a Batch Zero project assumed that date. It is gone, and nothing has replaced it.

What ERCOT did commit to is a calendar for the audit itself. Requests for information go out to provisionally qualified large loads from the end of August into early September, with further rounds in October and November. The Eligibility Verification Report and the Community Impact Review Report get filed December 10, with Commission discussion at the December 17 open meeting. The cohort is roughly 250 to 300 projects at 75 MW or larger, most of them data centers, drawn from a large-load interconnection queue Governor Abbott's August 3 directive put at 474 GW and about 90% data centers. That supersedes the 438,000 MW figure ERCOT published in June and this newsletter has been using since; the queue grew 36 GW in ten weeks while everyone was arguing about whether to study it.

The number that actually moves money is smaller. Seely told the Commission that 17 large loads representing about 6.6 GW of peak demand have cleared every ERCOT gate except one: approval to energize. They are not classified, not verified, not audited. They are simply finished with everything else. Utility Dive has the exchange. BNEF put roughly 49.8 GW of national pipeline at delay risk from the pause. Both numbers are real. Only one of them has a substation attached.

"The Only Meaningful Remedy Remaining"

Administrative law judges Linda Brite, Linda J. Burgess and Dee Marlo Chico spent 100-odd pages on the Bell County East–Big Hill and Big Hill–Sand Lake 765-kV applications and arrived at a recommendation nobody at Oncor wanted to read. Conclusion of Law 14 recommends denial of both projects because the applicants failed to prove need. Conclusion of Law 15 recommends denial of Bell County East–Big Hill on notice grounds as well. This is a Proposal for Decision remanded to the Commission, not a final order — the commissioners can adopt it, modify it, or throw it out. But the need case for the center import path has now failed once, on the record, in writing.

The notice arithmetic is worth reading slowly. Oncor and LCRA TSC sent 2,809 invitations to the June 2025 pre-filing public meetings. Then roughly 400 miles of new route links went into the project. When the applications were filed, notice went to about 4,200 landowners, mailed on or after March 26, 2026 — meaning some 1,400 people first learned they were affected when the paperwork arrived, months after the meetings where community input was supposed to happen. The judges wrote that denial was "the only meaningful remedy remaining." Nine words, page 45.

The need finding is the one that travels. The ALJs credited intervenor testimony cataloguing 37 announced gas generation projects in the Permian, West Texas and the Panhandle-Northwest totaling 39.467 GW as of May 13, 2026, and found the 2022 oil-and-gas electrification forecast underpinning Import Path 2 rested on corporate pledges rather than committed load. This newsletter ran the wires-versus-pipes numbers three weeks ago and concluded the case was closer than the transmission planning process treats it. Three administrative law judges have now written a version of the same thing into a docket.

The Commission moved the next day. On August 21 Chairman Gleeson and Commissioners Jackson and Hjaltman — Rhode and Johnson absent — consolidated the Longshore Switch–Drill Hole Switch and Dinosaur–Longshore dockets under PURA §37.0541, solely on the issue of need. That is Gleeson trying to answer the need question once, cleanly, before the 90th Legislature takes the pen away from him. The same morning, a statement signed by 31 members of the Texas House landed in Docket 59029 asking the Commission to deny all five pending 765-kV certificates. Oncor's counsel told the Commission the governing statute "is not a study bill" and "demands action," as reported by Texas Scorecard — a reading of HB 5066 that both Gleeson and the bill's author have publicly disputed.

Three of those dockets are on today's open meeting agenda, which convened at 9:30 this morning: 59029, 59315, and 59336, the AEP Texas and CPS Howard–Solstice line, which runs into a statutory deadline this weekend. The meeting was underway at press time.

Six August Records, No Conservation Appeal

On August 18, Bloomberg reported that ERCOT expected peak demand to exceed the all-time record of 91,089 MW every day from August 20 through August 24, with the forecaster Atmospheric G2 projecting wind output down as much as 5 GW by that Friday. Five consecutive all-time records, into a wind sag, in August. It was the setup for a bad week.

The record never fell. ERCOT's preliminary numbers show six straight daily August records from August 15 through August 20, topping out at 90,353 MW on Thursday the 20th, and then a new all-time weekend high of 90,411 MW on Sunday the 23rd. The July 22 mark held by 678 MW. There was no conservation appeal, no weather watch, no emergency notice. ERCOT published no news releases at all in August, which for a grid operator is its own kind of statement.

Two caveats on the figures. Every August number carries ERCOT's asterisk and is unofficial until settlement, and the July 22 record is drifting the wrong way for anyone quoting it: settlement data already puts that hour at 91,133.7 MW on an integrated hourly basis. Use 91,089 as preliminary or don't use it. For scale, the pre-2026 official record was 85,508 MW, set August 10, 2023. Texas is carrying about 6.5% more peak than it was three summers ago and doing it with more than 45 GW of solar and a battery fleet heading for 27 GW by year end.

The summer reliability question, the one that has driven a decade of Texas energy politics, quietly got answered in the affirmative this month. The tight window has moved off the August afternoon. What is left is winter, and winter is a different fleet problem with a different answer.

Nine Hours, and No Authority Over Community Impact

The day before all of it, the House Committee on State Affairs, chaired by Ken King of Canadian, sat for nine hours in JHR 140 on data center development and the 765-kV approval process, with two overflow rooms open. ERCOT President and CEO Pablo Vegas said the audit should conclude around December and acknowledged that some Batch Zero projects will drop out rather than sit through it.

The admission that matters came from the regulators themselves: PUCT and ERCOT have no explicit statutory authority over "community impact" and will rely on voluntary attestations from developers. So the most politically potent piece of the Governor's directive is a survey ERCOT cannot compel and cannot verify, covering facilities that in many cases sit below the Batch Zero threshold entirely. That is not a regulatory process. That is an evidence file, and every answer a developer gives this fall is an exhibit next spring.

Two other things got said out loud. Representative Drew Darby of San Angelo, on the 180-day certificate window that has been driving the whole transmission calendar: it "came from" the Permian Basin Reliability Plan, "not y'all deciding that we've got to run lines all the way across the state," and "I think we need to relook at that." And Adrian Rodriguez, president and chief operating officer of AEP Texas, on what delay actually costs: the 765-kV equipment order book is national, PJM and MISO are buying into the same slots, and Texas can lose its place in line. Transformers do not care which state's political process is having a moment.

$25 Million a Megawatt, If the Meter Already Spins

Which brings us to the price. IREN reported FY26 results on August 27: revenue of $707.0 million against $501.0 million a year earlier, with AI Cloud Services at $128.8 million and bitcoin mining at $578.2 million. In the fourth quarter AI Cloud finally passed mining, $70.5 million to $66.7 million. The company also booked a net loss of $702.6 million including $638.8 million of non-cash impairments, holds $5.90 billion of cash plus $1.72 billion restricted against $7.59 billion of debt, and told the call it plans $25 to $30 billion of capital expenditure in FY27.

Buried in that release is the cleanest price signal Texas has produced this year. IREN says recent three-year contracts are generating more than $20 million of revenue per critical IT megawatt, with roughly a two-year payback, and that active discussions are running near $25 million per megawatt on three-to-five-year terms, with customer prepayments covering 45 to 55% of the associated GPU capital. On August 13 Microsoft accepted Horizon 1 at Childress, the first of four 50 MW critical-load phases under a five-year contract worth about $9.7 billion signed last November. Phases two through four are targeted for the fourth quarter.

Set that against the other half of the state. Cipher, CleanSpark and Core Scientific are carrying gigawatts of Texas capacity whose value now depends on an audit that lost its deadline last week, and the sell side has been marking those positions down since the pause. Same state, same commodity, same regulator. The only variable is whether the meter is already spinning.

The constraint in Texas was never electrons. Everyone spent a decade planning for a shortage of generation and got a grid that took six straight August records without raising its voice. The shortage that showed up instead is permission, and permission is now the thing with a price.

What to Watch Next Week

Today's open meeting. Dockets 59029, 59315 and 59336 were all posted for discussion and possible action this morning. The Howard–Solstice application runs into its statutory deadline this weekend, which means the Commission either acts on it or explains why it did not.

ERCOT's Batch Zero RFIs. They go out from the end of this month into early September. The first real read on Vegas's prediction that projects will drop out is how many of the 250 to 300 respond, and how many quietly do not.

Exceptions to the Bell County East–Big Hill PFD. Docket 59475 is not on today's agenda. Oncor and LCRA TSC will file exceptions, staff and intervenors will reply, and the Commission takes it up in September. Watch whether the commissioners engage the need finding or dispose of it on the notice defect, which would be the narrow way out.

Project No. 58484. The transmission cost recovery docket has a December 31 statutory deadline and a March draft that would move ERCOT off four coincident peaks toward more of them, impose minimum demand charges on contracted peak for 10 to 15 years, and — in the companion proceeding — eliminate interconnection cost allowances for large loads. Nobody is protesting it on the Capitol steps. It will move more dollars than the 765-kV fight.

December 10 and December 17. The verification and community impact reports, and the open meeting that takes them up. Between now and then, the only Texas megawatts with a firm price are the ones already energized.

Disclaimer: The Grid Report is Barrio Energy's market intelligence product. Nothing here is investment advice. Links go to primary sources wherever possible; form your own view.