FACT-CHECK & ANALYSIS
A collaboration between Lewis McLain & AI
How the Legislature built the machine it is now trying to stop
Subject article: “Texas lawmakers turn against massive power lines they ordered after outcry” — Kelsey Brown, San Antonio Express-News / Austin American-Statesman, August 17, 2026
Prepared: August 17, 2026
Method: 18 discrete claims checked against primary sources — ERCOT filings, enrolled bill text, PUC orders, and the CCN applications themselves — plus contemporaneous reporting from ten outlets.
| The short version Your instinct is right — this is big, and it is bigger than the article makes it look. The core narrative checks out: Texas legislators voted 135–0, 31–0 and 139–3 for the bill that produced this buildout, and a bipartisan-but-mostly-Republican bloc is now trying to stop it. That reversal is real and well documented. But three headline numbers are wrong or stale, two material facts are missing, and the single most damning finding never appears: House Bill 5066 itself created the 180-day permitting clock that landowners are now furious about, and Sen. Charles Schwertner — who is demanding the applications be denied — was the bill’s Senate sponsor. |
Contents
1.2 Why this is bigger than the article suggests
2. Claim-by-claim verification
3. How Texas built the machine it is now trying to stop
4. Is 765 kV the right answer?numbers
4.2 What the article got right, and what it left on the table
5. Is the need real? The demand case is the weak link
5.1 What Texas actually uses, and what it is projected to use
5.2 The Permian numbers specifically
5.3 The counter-case, which is also strong
6. Who pays — and the December deadline nobody is covering
6.2 What the buildout adds to a household bill
6.3 The CREZ precedent, which everyone should be citing and nobody is
7. Is gas generation a real alternative?
7.2 The economics are worse than the supply chain
7.3 The state already tried subsidizing it
7.4 And the gas itself is harder than it looks
8. The box the commission is in
8.1 Denial is legally available — on the right grounds
8.2 The middle path nobody is discussing
8.3 Why abatement is the weakest option
8.4 Litigation risk is lower than it looks
9. Why this is a political earthquake, not a zoning dispute
9.3 The coalition is not unified — and the article flattens it
9.4 Texas is an outlier on scale and a laggard on tools
9.5 The tax fight running in parallel
10.1 Three questions the reporting has not answered
1. Verdict
The article is a competent, directionally accurate account of a genuinely significant story. It is also loose with three numbers in ways that matter, and it leaves out the two things that would make the piece land hardest.
1.1 Scorecard
| Dimension | Verdict | Note |
| Core narrative — lawmakers ordered it, now oppose it | SOUND | Vote counts, hearing, and reversal all confirmed by primary sources. |
| Named officials, titles, party, hometown | ACCURATE | Schwertner, Kolkhorst, Campbell, Sparks, Gleeson, Staples all correctly identified. |
| Procedural chronology | MOSTLY ACCURATE | July 29 hearing and Aug. 14 PUC meeting confirmed. The Aug. 19 House State Affairs hearing could not be confirmed — no notice appears in Texas Legislature Online’s posted House committee meetings as of Aug. 17. |
| Headline dollar figures | 1 WRONG, 1 LOOSE | “$1.4 billion” is one utility’s share of a $2.9 billion line. “$33 billion” is the statewide plan, not the Permian plan — a conflation most Texas outlets share. |
| Demand forecast | STALE | “Quadruple by 2032” is a number ERCOT’s CEO superseded at the very hearing the article covers. |
| Direct quotes | 2 UNSOURCED | Campbell and Staples quotes could not be found in any other account. Not evidence they are wrong — evidence they are exclusive or paraphrased. |
| Political completeness | MATERIAL GAP | Lt. Gov. Dan Patrick called for denial and made it a 2027 priority. He is not mentioned. |
| Structural analysis | MISSED | HB 5066 created the 180-day clock and the statutory deference to utility forecasts. Schwertner sponsored it in the Senate. |
1.2 Why this is bigger than the article suggests
The story is usually told as a property-rights fight: ranchers versus power lines. That framing is accurate but small. Three larger things are happening underneath it.
- A statutory boomerang. The Legislature did not merely order a plan. It shortened the approval clock from one year to 180 days and wrote into law that the PUC “must consider” load forecasts supplied by the utilities — including load with no signed interconnection agreement. It then expressed surprise at the result.
- A cost-allocation reckoning. Under ERCOT’s postage-stamp method, every ratepayer in the state pays for every line regardless of who benefits. That is precisely what Sen. Campbell was attacking. A rulemaking that could change it must conclude by December 31, 2026 — and almost nobody is covering it.
- A possible partisan realignment on energy. One July 2026 poll found Texas Republicans wanting more regulation of data centers than Texas Democrats do — 75–14 versus 59–30. That is a single question in a single survey and should not be over-read, but the state’s agriculture commissioner is publicly warning his own party it will lose seats over this. Transmission is where three Republican orthodoxies — property rights, permissive permitting, and cheap power — collide and cannot all survive.
2. Claim-by-claim verification
Eighteen checkable assertions, in the order they appear. “Partly” means the substance survives but a detail does not.
| # | Claim | Verdict | Finding |
| 1 | The Permian Basin Reliability Plan is a “$33 billion” plan | PARTLY | ERCOT’s own Permian plan totals $13.77B for the 765-kV option ($12.95B for 345-kV, $15.32B for 500-kV). The $33B ($32.99B) figure is ERCOT’s statewide 765-kV Strategic Transmission Expansion Plan, of which the Permian plan is one component. Most Texas outlets make the same conflation, so the article is in good company — but it overstates the Permian plan by roughly 2.4x. |
| 2 | A “$1.4 billion line” through 14 Hill Country counties, San Antonio to West Texas | WRONG | This is Docket 59336, Howard–Solstice — a joint AEP Texas / CPS Energy application filed March 2, 2026, running ~371 miles from CPS’s Howard Road station in southwest Bexar County to AEP’s Solstice station near Fort Stockton. The 14 counties are right. But $1,369,459,891 is CPS Energy’s share alone. AEP’s share is $1.516B; the project totals roughly $2.886B. Also: only about half the 14 counties are Hill Country — Pecos, Terrell, Crockett, Val Verde, Sutton and Kinney are Trans-Pecos and border country. |
| 3 | In 2023 legislators “overwhelmingly voted” for the bill requiring the plan | VERIFIED | HB 5066 (Rep. Charlie Geren, R-Fort Worth). House 135–0 on May 6, 2023; Senate 31–0 on May 21; House concurrence 139–3 on May 25. Signed June 13, effective immediately. “Overwhelmingly” understates it — it was very close to unanimous. |
| 4 | A “15-hour public hearing last month” | VERIFIED | Senate Committee on Business and Commerce, Wednesday July 29, 2026, running past midnight. Interim charge: “Managing the Impacts of 765-kV Transmission Lines on Private Property Rights.” Attendance reports vary — 100+ testified, 200+ attended. |
| 5 | Schwertner chairs Senate Business & Commerce; his quote and call to deny | VERIFIED | Confirmed by at least two independent outlets. His July 31 letter asked the PUC to reject the applications and called for “a complete overhaul” of the process before they advance. |
| 6 | Thomas Gleeson is PUC chairman; plan submitted mid-2024 before ERCOT’s forecast | VERIFIED | Gleeson is chair as of the Aug. 14, 2026 meeting. ERCOT filed the Permian plan July 25, 2024. The chronology holds — and is more damaging than the article says, because the plan was built on load forecasts supplied by the transmission companies, which ERCOT’s COO testified were “substantially higher” than ERCOT’s own. |
| 7 | ERCOT forecast peak demand “could more than quadruple by 2032” | WRONG | Arithmetically defensible against an April 2026 statewide figure, but regulators called that forecast almost certainly flawed and ERCOT has withheld official forecasts while reworking its methodology. At the July 29 hearing the article covers, ERCOT CEO Pablo Vegas gave the committee roughly 175,000 MW by 2032 — “nearly double,” not quadruple. Attributing “quadruple” to ERCOT on August 17 is the most substantive accuracy problem in the piece. |
| 8 | Sen. Donna Campbell: “We ask data centers to bring their own power…” | UNVERIFIED | Campbell is correctly identified as R-New Braunfels and the argument is squarely hers. But this exact wording appears in no other account. Her documented hearing line was: “It just seems like it’s just a rich daddy that doesn’t want to pay for developing transmission lines.” Worth noting the article omits Schwertner’s on-the-spot rebuttal: “There is a universal benefit of a public utility, whether it’s water or electricity.” |
| 9 | Kolkhorst: Permian demand is electrification, not population growth | PARTLY | Correctly identified as R-Brenham. The substance is right and supported by ERCOT’s data. But her most-quoted line that day was different and far better: “We voted on House Bill 5066, and I’m not sure we knew what that was going to become.” |
| 10 | Sen. Kevin Sparks voted for the plan; “overlooking the obvious” on gas | VERIFIED | Sparks (R-Midland) voted for HB 5066 in the 31–0 Senate vote. Quote confirmed. The article omits his stated motive: “If we charge through with these lines right now, it’s almost guaranteed that what we’ll fill these up with is more wind, mostly solar.” That reframes his objection considerably. |
| 11 | Todd Staples is TXOGA president; his “five years” quote | PARTLY | Title confirmed. The quote could not be located in any other account. His documented lines are different but make the same point: “This is not an academic exercise. These are real people with a real crisis.” |
| 12 | One 765-kV line carries as much as three or four 345-kV lines | PARTLY | Conservative. ERCOT’s own claim is five, and physics supports it — capacity scales with the square of voltage, and (765/345)² ≈ 4.9. But ERCOT’s actual plan delivers only 1.57x per import path (2,105 MW vs 1,340 MW). Both numbers are true and measure different things; the gap between the marketing and the engineering has fed a lot of the distrust. |
| 13 | Exxon, ConocoPhillips and Chevron commissioned a 2022 study | PARTLY | It was six companies, not three — add Devon Energy, Diamondback and Pioneer Natural Resources. Conducted by S&P Global, December 2022. It projected Permian demand growing from 4.2 GW to 17.2 GW by 2032, and ERCOT relied on it. That the demand case rests partly on an industry-funded study is a fact the article should have surfaced. |
| 14 | At the Aug. 14 meeting the PUC took no action to halt development | VERIFIED | Special open meeting requested by Gleeson. His advance memo said explicitly that no final decisions would be made on any individual line. More than 20 landowners testified. Rep. Brad Buckley told commissioners: “The only remedy to this is denial of all applications of CCN.” |
| 15 | A House committee hearing Wednesday; PUC could review a line Friday | UNVERIFIED | Reported as House Committee on State Affairs, 8 a.m. Wednesday Aug. 19, chaired by Rep. Ken King, announced by Speaker Dustin Burrows. Two independent research passes could not confirm it: Texas Legislature Online’s posted House committee meetings run current through Aug. 17 and show no State Affairs hearing on Aug. 18 or 19, and the only House hearing located that week is an Aug. 18 broadband hearing. This may simply be a notice posted after publication — but do not repeat the date without checking. The Aug. 21 PUC item is the northern line (Dockets 59029 and 59315), not the Hill Country line. |
| 16 | Jimmy Fair of Lingleville testified | UNVERIFIED | Circumstantially strong. “Jimmy Fair” and “Lingleville” both appear in PUC Docket 59315 filings dated April 8, 2026, and Lingleville sits in Erath County directly on the Oncor Dinosaur–Longshore route. The vineyard, the reclaimed-wood house and the 35-year insurance career could not be independently confirmed — presumably direct reporting. |
| 17 | Lt. Gov. Dan Patrick | OMITTED | Not mentioned in the article at all. Patrick publicly endorsed denial — “and not consider re-applications” — and pledged the Senate would prioritize the issue in the 90th session. Every other major outlet led with him. Omitting the lieutenant governor materially understates the political weight behind the reversal. |
| 18 | Whether lawmakers actually approved 765 kV | OMITTED | HB 5066 contains no voltage specification. It ordered a plan; the PUC chose the technology, in two separate decisions (Sept. 26 / Oct. 7, 2024 to authorize applications on all eight import paths, and April 24, 2025 to select 765 kV). Gleeson acknowledged as much at the July hearing. This is the crux of the entire legal and political fight and the article does not raise it. |
| On the two unsourced quotes Neither the Campbell nor the Staples quote could be found in any other account of the July 29 hearing. That is not evidence they are fabricated — a staff reporter at a 15-hour hearing will capture lines nobody else does, and both are consistent with what those speakers demonstrably argued. But if this analysis is going anywhere it can be challenged, the safe move is to source them to the hearing recording before quoting them onward. The same applies to Jimmy Fair. The docket filings put a person of that name in the right county on the right route in April 2026, which is about as good as external confirmation gets without the recording. |
3. How Texas built the machine it is now trying to stop
The most useful thing to understand about this story is that almost nothing went wrong procedurally. The Public Utility Commission did roughly what the Legislature instructed, on the schedule the Legislature imposed, using the inputs the Legislature told it to weigh. The outrage is real, but it is outrage at an outcome that the 2023 statute made close to inevitable.
3.1 What HB 5066 actually did
Four provisions matter. Only one of them is widely discussed.
| Provision | What it says | Consequence |
| §39.166 The general power | Requires reliability plans for any region with rapid electrical load growth, as determined by transmission service providers. No expiration date. | Almost never mentioned, and it is the durable one. §39.167 expired; this did not. Whatever happens to the Permian lines, the statutory machinery for the next region remains in force. |
| §39.167 The Permian plan | Directs the PUC to direct ERCOT to develop a reliability plan for the Permian Basin under §39.166, addressing transmission to mineral-production areas. Expired Sept. 1, 2025. | The only part anyone remembers. Notably voltage-neutral — it says nothing about 765 kV, 345 kV, or any technology. |
| §37.057 The 180-day clock | Changed the PUC’s decision deadline from “the first anniversary” of filing to “the 180th day,” enforceable by mandamus in Travis County district court. | This is the compressed timeline landowners are now protesting. It was not imposed by the PUC or the utilities. The Legislature wrote it. |
| §37.056(c-1) The deference rule | For ERCOT reliability projects, the PUC “must consider” forecasted load growth and load seeking interconnection — “including load for which the electric utility has yet to sign an interconnection agreement, as determined by the electric utility with the responsibility for serving the load.” | The quiet one, and the most consequential. It writes statutory deference to the utilities’ own load projections, including speculative uncontracted load, into the need finding. Transmission owners earn a regulated return that scales with capital deployed. |
Read together, the provisions do something specific: they expanded what the commission must weigh while halving the time it has to weigh it, and told it whose numbers to use. A Bell County landowner put it more crisply than any analyst has: “More to evaluate, half the time to evaluate it.”
| The finding the article missed Sen. Charles Schwertner was HB 5066’s Senate sponsor — and it moved through his own committee. The chairman now demanding the PUC deny these applications, and calling for “a complete overhaul” of the certification process, carried in the Senate the bill that created the 180-day clock and the deference rule he is objecting to. Texas Legislature Online lists the bill as “By: Geren; Morales, Eddie (Schwertner)” — Rep. Charlie Geren as author, Rep. Eddie Morales as joint author, Schwertner as the Senate sponsor. Confirmed independently by LegiScan, which lists him as the only senator on the bill. It was referred to Senate Business and Commerce — the committee he chairs, and where he held the July 29, 2026 hearing that produced the reversal. This is not a gotcha. Near-unanimous votes mean almost every legislator now complaining voted for it, and Sen. Kolkhorst has said as much candidly. But it is the strongest available evidence for the article’s own headline premise, and it appears in none of the coverage located. |
3.2 Who actually chose 765 kV
Not the Legislature. The record is unambiguous and it happened in two steps a year apart:
- September 26 / October 7, 2024. The PUC approved the Permian plan and authorized transmission providers to prepare applications for all eight import paths — three at 765 kV and five at 345 kV — while deferring the voltage decision. ERCOT’s own January 2025 report records that the commission “deferred a decision on the voltage level of the import paths,” with a determination anticipated by May 1, 2025, and approved the plan “irrespective of the voltage level.”
- April 24, 2025. A second order selected the three 765-kV paths and terminated authorization for the 345-kV alternatives.
- December 9, 2025. ERCOT’s board endorsed the first two 765-kV projects — the AEP Texas / CPS Energy / Oncor / CenterPoint “Eastern Backbone” and the Oncor / AEP “Drill Hole to Sand Lake to Solstice” project. This is the step between the voltage selection and the 2026 applications, and it is missing from most accounts.
That deferral is the crux. The commission plainly understood the voltage choice to be its own discretionary call, made nine months after it approved the plan and nearly two years after the statute passed. Critics who say the Legislature never voted for a statewide 765-kV grid are correct on the record.
The counter-argument is equally fair: the Legislature ordered a reliability plan, wrote a deference rule favoring the utilities’ forecasts, and imposed a deadline that made deliberation harder. Having done all that, complaining about the technology the commission selected is a thin position. Both things are true, which is why this will be litigated politically rather than resolved factually.
4. Is 765 kV the right answer?
Better than its critics allow, and worse than its promoters imply. Here is ERCOT’s own comparison, which almost nobody in the public debate has read.
4.1 ERCOT’s own numbers
| Permian import paths, 2038 (2024 dollars) | 345 kV | 500 kV | 765 kV |
| Meets ERCOT / NERC criteria | Yes | Yes | Yes |
| Incremental N-1 transfer capability, MW | 1,340 | 1,712 | 2,105 |
| Transmission losses at system peak | 3.0% | 2.8% | 2.7% |
| Import paths required | 5 | 4 | 3 |
| New right-of-way, miles | 1,676 | 1,370 | 1,255 |
| Average line cost, $M per mile | 4.04 | 6.86 | 6.10 |
| Total cost, $ billions | 12.95 | 15.32 | 13.77 |
Three things fall out of that table that change how you should read the political fight.
- 765 kV is not the cheapest option. 345 kV is roughly $820 million cheaper in the Permian plan. The case for 765 kV rests on fewer corridors, lower losses, and — per ERCOT’s long-run simulation for 2039 — about $229 million a year in consumer energy cost savings plus $28 million in production cost savings. Not on capital cost. Anyone claiming 765 kV was chosen to save money is wrong; anyone claiming it was chosen despite being more expensive is right but incomplete.
- The right-of-way argument is the strongest one, and it is regionally true but statewide false. In the Permian, 765 kV needs 25% less new corridor — 1,255 miles versus 1,676. Across the full statewide plan, ERCOT’s own comparison states that the 765-kV build “includes 434 more miles of new ROW impact” than the 345-kV alternative, offset by roughly 1,443 fewer miles of upgrades to existing lines. “Fewer lines, less land” is a defensible regional claim being deployed as a statewide one.
- The capacity ratio depends entirely on which number you cite. The widely repeated framing is that one 765-kV line on a 200-foot corridor replaces five 345-kV lines needing 750 feet combined. That is textbook-correct for long-distance transfer and consistent with the physics. But the incremental transfer capability in ERCOT’s plan is 2,105 MW for the 765-kV configuration against 1,340 MW for the 345-kV configuration — a ratio of about 1.57, because the 345-kV costing assumes double-circuit construction while the 765-kV paths are single-circuit. Both figures can be honest and still leave a legislator with two very different impressions.
4.2 What the article got right, and what it left on the table
“One 765-kV line can carry the same amount of energy as three or four 345-kV lines” is a fair, conservative rendering. The more interesting story is that a 5:1 framing and a 1.57:1 engineering result are both circulating in the same hearing room and nobody has reconciled them publicly. That gap is worth a direct question to ERCOT rather than an accusation — but it is exactly the kind of thing that, once a landowner’s engineer notices it, corrodes trust in the rest of the case.
One caveat on sourcing: ERCOT publishes the underlying Permian study as a ZIP archive, and the 1,340 / 2,105 MW figures could not be re-verified independently of the research trail. Confirm them against the study itself before building an argument on the ratio.
5. Is the need real? The demand case is the weak link
If the plan gets stopped, this is where it will be stopped. Not on property rights — on the forecast.
5.1 What Texas actually uses, and what it is projected to use
| Measure | Figure | Context |
| All-time peak, Aug. 10, 2023 | 85,508 MW | The standing official record for most of the period this plan was designed in. |
| Peak, July 22, 2026 | ~91,089 MW | Up 6.5% over three years — real growth, but nothing like the forecast curve. |
| 2030, transmission-company reported | 208 GW | The number the utilities filed. HB 5066 requires ERCOT to count this, including load with no signed agreement. |
| 2030, ERCOT adjusted | 138 GW | ERCOT’s own screen of the same pipeline. |
| 2030, independent (Ascend Analytics) | ~120 GW | Applies a 55% success rate to announced projects. |
| 2032, cited in the article as ERCOT | “more than quadruple” | Traceable to an April 2026 figure regulators have called almost certainly flawed. |
| 2032, per ERCOT CEO on July 29, 2026 | ~175 GW — “nearly double” | Given to the committee at the hearing this article is about. |
| Large-load interconnection queue | 474 GW, ~90% data centers | Roughly five times the state’s all-time peak. About 205 GW survive ERCOT’s first viability screen; 315 projects had no qualifying study at all. |
The spread between 208 GW and 120 GW for the same year is not a rounding difference. It is the difference between a $33 billion emergency and a very expensive mistake, and the statute tilts the commission toward the high number.
5.2 The Permian numbers specifically
Chairman Gleeson told senators the buildout is “mostly based on oil and gas electrification.” By ERCOT’s own arithmetic it is about half.
| Permian load component | 2030 | 2038 | Share |
| Oil and gas electrification | 11,964 MW | 14,705 MW | 51% → 56% |
| Everything else | 11,695 MW | 11,695 MW | 49% → 44% |
| Total projected | 23,659 MW | 26,400 MW | vs ~7 GW today |
Two facts inside that table deserve far more attention than they have received.
- The non-oil-and-gas half is mostly crypto and hydrogen, not data centers. Roughly 59% is crypto mining, 22% green hydrogen, 13% general commercial and industrial, and only about 6% data centers. Federal hydrogen credits expire after 2027. Only 39% of this load is confirmed by executed contract; more than half rests on officer letters. This is the softest load in the plan and it is nearly half the plan.
- The oil-and-gas estimate itself varies by a factor of four. The S&P Global study commissioned by six oil majors put it at 11,964 MW. The University of Texas Bureau of Economic Geology put it at 5,291 MW in its base case. ERCOT’s own long-term load forecast implies roughly 3.1 GW. ERCOT built the plan on the highest of the three — the one paid for by the companies that benefit from the lines.
| The strongest argument against the plan, and the article barely touches it Not “this crosses my ranch.” The argument is: the need finding rests on a forecast supplied by parties with a financial interest in it being large, using an input study funded by the industry that benefits, under a statute that requires the regulator to count uncontracted load, on a 180-day clock that makes independent verification impractical. That is a serious regulatory-capture argument that a court could engage with. “We want to revisit this next session” is not. |
5.3 The counter-case, which is also strong
None of the above means the lines are unnecessary. ERCOT’s technical case is not speculative:
- The Permian has roughly 2,800 MW of conventional generation against 28,400 MW in North Central Texas and 25,900 MW on the Coast. The region is structurally short.
- ERCOT’s base cases for both 2030 and 2038 failed to solve — voltage instability even at N-0, meaning before any equipment fails.
- ERCOT’s COO told the committee rolling blackouts in the Permian are possible as soon as next year, and that pushing the required power through existing lines “would damage the existing infrastructure.” He also said the lines are necessary “with or without” HB 5066.
- Todd Staples’ fairness point is legitimate and rarely rebutted: West Texas ratepayers helped fund transmission buildouts for Houston, San Antonio and the Rio Grande Valley under the same postage-stamp method now being questioned when the money flows the other direction.
One wrinkle worth flagging for anyone tracking this closely: on July 29 the COO said blackouts were possible “next year.” On August 14 the framing had become “within five years.” That may be a difference between speaking to a hostile committee and speaking to a friendly regulator, or a genuine revision. Either way it is the kind of drift that opponents will notice.
6. Who pays — and the December deadline nobody is covering
Sen. Campbell asked the right question: why can’t the Permian Basin pay for it themselves? The answer is structural, and it is the reason this fight exists.
6.1 The postage stamp
- How it works. Each transmission provider’s revenue requirement is recovered across all of ERCOT based on the four coincident peak (4CP) method — the average of the single highest 15-minute load intervals in June, July, August and September. There is no locational or beneficiary-pays element. A line built for the Permian and a line built for Houston recover identically, statewide.
- Why residential customers pay more than their share. Large industrial and transmission-level customers are billed on their own measured 4CP, so they can — and increasingly do — shut down during the four intervals that set their bill. Residential customers are billed volumetrically per kWh and cannot. At CenterPoint in 2023, residential customers were 33% of energy consumed but bore 49% of allocated transmission cost. Per-utility residential allocators run 41.6% to 49.3%.
- It is getting worse fast. ERCOT’s transmission cost of service went from about $1.5 billion in 2010 to $5.1 billion in 2024, with projections near $13 billion by 2034. Transmission and distribution together have gone from roughly 30% of a Texas residential bill in 2002 to roughly 40% today. The ERCOT transmission rate is up 116% since 2013, and the number of large customers actively dodging the 4CP intervals grew from 418 in 2022 to 1,080 in 2024 — which shifts more cost onto everyone who cannot dodge.
6.2 What the buildout adds to a household bill
| Source | Estimate | Basis |
| NRG (Feb. 2025) | +$178 to $268 per year | Residential transmission and distribution component up 24–32% at a $32.99B buildout with 4CP unchanged. Assumes 7.0% weighted cost of capital, 30-year depreciation, ~48% residential allocation. Also finds the buildout at least doubles annual ERCOT transmission cost of service, adding more than $6B/year. |
| Texas Public Policy Foundation (Jan. 2026) | “At least $100 per year” | Adds more than $3 billion annually in transmission cost of service across the 2030s; normalized to $18/MWh by 2034. TPPF opposes the plan and also opposes the renewable buildout — read accordingly. |
| Public Utility Commission | None | A commission spokesperson confirmed in February 2025 that the agency does not have an estimate. That is, on its own, a finding. |
| Sierra Club (June 2026) | Residential charges could fall ~10% | If 4CP is replaced with 12CP plus a large-load demand charge — the pending rulemaking. The ERCOT-wide residential allocator would drop from 30.75% to 27.53%. (Note this is the system-wide allocator, not the per-utility figures cited above.) |
6.3 The CREZ precedent, which everyone should be citing and nobody is
Texas has done exactly this before. Between 2009 and 2014 the state built roughly 3,600 miles of transmission to unlock West Texas wind under the Competitive Renewable Energy Zones program — also on the postage stamp, also with no cost assigned to the generators who benefited.
| CREZ | Outcome | Read-across |
| PUC cost estimate, 2008 | $4.93 billion | — |
| Final capital cost | $6.9 billion | A 40% overrun, driven largely by route changes that added more than 600 miles. |
| Bill impact | “Several dollars” per month | Never officially quantified. Reconstructed from cost-of-service data at roughly $4/month at the 2015 peak, falling to about $2.50 by 2024. |
| Offsetting benefit | $31.5 billion | Comptroller’s estimate of wholesale price savings from CREZ wind, 2010–2022. The strongest argument that these buildouts can pay for themselves. |
| Applied to this plan | $33B → ~$46B | If the same 40% overrun rate holds. Route litigation is already heavier than CREZ faced. |
| The deadline nobody is covering Senate Bill 6, passed in 2025, requires the Public Utility Commission to reevaluate the 4CP cost allocation methodology and amend its rules no later than December 31, 2026 — before the Legislature convenes. That is Project 58000. It proposes replacing 4CP with 12CP, codifying the settlement interval, and imposing a minimum billing demand on large loads. Comments closed August 11, 2026. A decision is expected in December. If it lands as proposed, it could cut the residential share of transmission cost by roughly a tenth and put real cost on the large loads driving the buildout — which is precisely what Campbell, Abbott and most Texas voters say they want. It may move more money than the entire certification fight, it requires no legislation, and it arrives one month before the session that everyone is waiting for. If you write one thing about this story that nobody else is writing, this is it. |
7. Is gas generation a real alternative?
Sen. Sparks says the utilities are “overlooking the obvious” by not building gas plants in a region swimming in natural gas. It is the most intuitive objection in the debate and the one that survives contact with the evidence least well.
7.1 You cannot buy a turbine
- GE Vernova was taking reservations for 2031 delivery as of July 2026. Siemens Energy quotes three years or more. Mitsubishi’s recent orders deliver 2028–2030.
- GE Vernova’s gas power backlog went from 83 GW at the end of 2025 to 116 GW by mid-2026. Global orders are running near 110 GW a year against 60–70 GW of manufacturing capacity. The bottleneck is single-crystal turbine blades, which cannot be scaled quickly.
- Prices have moved accordingly: roughly $785/kW in 2022 to about $2,400/kW today. BloombergNEF put US combined-cycle capital cost at $2,157/kW in 2025, up 66% against 2023, with build times 23% longer.
A gas plant ordered today does not reliably serve load before 2029–2031 — which is the same window the transmission lines are targeting, at a cost that is no longer obviously lower.
7.2 The economics are worse than the supply chain
- ERCOT’s scarcity pricing mechanism was active for 57 hours in 2025, against 1,458 hours in 2022. The revenue that justifies a peaker has largely evaporated.
- The West zone’s average real-time price in 2024 was $35.71/MWh — below the lowest new combined-cycle levelized cost, and below even a fully depreciated plant’s marginal cost 55% of the time.
- Brattle’s cost-of-new-entry study found no merchant combined-cycle plant met its criteria; aeroderivative turbines accounted for 98% of recent merchant thermal entry, at a levelized cost above solar-plus-storage.
- Revealed preference settles it. ERCOT’s 2025 additions were 6.2 GW of solar, 7.3 GW of storage, and 280 MW of gas. Developers are not declining to build gas in West Texas because they overlooked it.
7.3 The state already tried subsidizing it
The Texas Energy Fund offers 3% twenty-year loans covering up to 60% of project cost for dispatchable generation of 100 MW or more. It drew more than 70 applications totaling over 38 GW.
| Texas Energy Fund | Figure | Note |
| Selected for due diligence, Aug. 2024 | 17 projects, 9.7 GW | $5.38 billion requested. |
| Withdrawn by November 2025 | ≥8 projects, ~35% of proposed capacity | ENGIE cited “equipment procurement constraints.” WattBridge withdrew 1,620 MW across four projects. |
| Loans finalized as of June 2026 | 8 | Several were already under development before the fund existed. |
| Statutory disbursement deadline | Dec. 31, 2025 | Extended to Dec. 31, 2027 — the mechanical trigger for most withdrawals. |
7.4 And the gas itself is harder than it looks
- Flared gas is not a fuel supply. Total reported Permian flaring runs around 275 MMcf/d. A single 1,000 MW plant running at 90% capacity factor consumes 133–181 MMcf/d depending on heat rate — half to two-thirds of everything flared in the Texas Permian, and that assumes 100% capture, which is not achievable across thousands of dispersed wells. No grid-interconnected flare-gas power plant exists in the basin, and the sum of all genuine flare-gas generation ever built nationwide is well under 500 MW.
- Permian gas is often off-spec. Pipeline specification is 4 ppm hydrogen sulfide; some Permian wells run above 4% — ten thousand times that — with CO₂ above 10%. Treating requires amine plants and acid-gas injection wells. There is precedent: when Odessa built a 62-mile pipeline to burn local high-nitrogen gas in 2010, the turbines could not run on it at all above a 50% blend.
- Air permitting risk is rising. No part of the Permian is currently in ozone nonattainment, but a petition filed in April 2026 seeks that designation for 36 Texas counties. If granted, major-source thresholds drop sharply, emission offsets must be sourced from inside the area — and the Permian has no offset bank — and the required control standard does not consider economic impact. The limiting pollutant would be nitrogen oxides, which is exactly what turbines emit.
| Where this leaves Sparks and Staples They are describing the same market from opposite ends, and both are right. Staples is right that so much Permian demand is now met by intermittent solar and wind that a gas plant running only in the gaps cannot earn its capital back. Sparks is right that building 765-kV transmission into a region full of wind and solar will, in practice, move more wind and solar. Neither is describing a gas plant that can be financed, permitted, supplied with turbines and energized before 2030. That is the part of the argument that does not survive. |
8. The box the commission is in
Everyone is demanding the PUC “deny” or “pause.” Those are not equivalent, and only one of them is durable.
8.1 Denial is legally available — on the right grounds
Utilities Code §37.056(a) says the commission “may approve an application and grant a certificate only if” it finds the line necessary for the public convenience and necessity. Approval, not denial, is the burdened act. Subsection (b) expressly permits the commission to grant as requested, grant only a portion, or refuse to grant.
The problem is the stated reason. “The Legislature intends to revisit this next session” is not among the statutory factors. A denial order resting on that rationale is squarely exposed on substantial-evidence and arbitrary-and-capricious review in Travis County district court.
The durable path is to deny on grounds already in the record: defective notice and due process — roughly 1,300 landowners were added to proceedings after route changes — plus community values and environmental integrity, all of which are statutory factors. Legislative timing then operates as unstated motive rather than stated basis.
8.2 The middle path nobody is discussing
Section 37.056(b)(2) lets the commission grant a certificate for only a portion of the requested system. Given that the three import paths differ substantially in contestedness — the northern line is far further along than the Hill Country line — a partial grant would let the commission preserve the reliability case for the least-contested segments while sending the rest back. It has appeared in essentially no public commentary.
8.3 Why abatement is the weakest option
The 180-day clock in §37.057 is enforceable by mandamus — but mandamus compels the commission to decide, not to approve. Any party can force a decision, and the commission could then deny. Docket 59182 has already blown past its deadline with no order. Indefinite delay is not a stable position; it just moves the fight to a courthouse.
This also explains why opponents specifically want denial rather than delay. A denial kills the application; the utilities can refile, but a 2027 refiling would run under whatever rules the 90th Legislature writes. Delay leaves the current applications alive under current law. Following HB 5066’s own transition-rule pattern — new law governs proceedings commencing after enactment — denial-then-refile is the only route that actually changes the governing rules.
8.4 Litigation risk is lower than it looks
The industry is not united. The Association of Electric Companies of Texas appears to have publicly conceded the process was inadequate — its president is quoted saying “it’s become clear that the existing transmission routing process has been inadequate for the geographic expanse of these projects.” If that quote holds up, it is a remarkable admission from the trade association of the applicants, and it substantially weakens any later argument that denial on process grounds was arbitrary. It rests on a single sourcing chain and should be confirmed before it is relied on in an argument.
Oncor is the most likely lone litigant. The Permian Basin Petroleum Association has said it is “agnostic about the voltage, routes, or other considerations” and cares only about delay. No utility has publicly threatened suit.
Two political facts sit underneath all of this. Every sitting commissioner was appointed by Gov. Abbott — close to tautological given he has been governor since 2015, but it matters for how a denial would be read. And both Abbott and Patrick are on the November ballot.
No precedent for the PUC denying a major transmission certificate was located in any source consulted. That is an argument from absence and should be treated as one — the commission also routinely grants applications in part, which may be the more likely outcome here than a clean denial.
9. Why this is a political earthquake, not a zoning dispute
The article correctly notes that public sentiment has turned against data centers. The numbers behind that sentence are more dramatic than the sentence.
9.1 The polling
| Poll | Result | Detail |
| UT / Texas Politics Project, June 5–12, 2026 | 29% support, 56% oppose | Data centers in your community. 1,200 registered voters. Republicans 42–44. Rural 22–62, with 50% strongly opposed. Suburban women 18–65. Pollster Jim Henson: “we were a little surprised by the lopsidedness.” |
| Emerson College / Nexstar, Aug. 9–10, 2026 | 33% support, 60% oppose | 1,000 likely voters. Six weeks later, no improvement. |
| Texas A&M Bush School, July 27–30, 2026 | 65–22 for regulating data centers | Republicans 75–14. Democrats 59–30. Republicans want more regulation than Democrats — potentially the most politically consequential number in this story, though it is one question in one survey of 619 likely voters and the Republican crosstabs here sit oddly against the UT poll’s 42–44. Worth a second data point before building on it. |
| UH Hobby School, April 2026 | 78–79% say data centers should pay | Under 5% say households should pay for the grid upgrades data centers require. Identical across party lines. |
| Abbott job approval on the grid | 36 approve / 40 disapprove | Republicans 61–13, down from 43/39 overall in February 2024. His weakest issue with his own base. |
9.2 The map problem
An analysis of project locations found that at least 82 data centers — nearly 60% of those planned or under construction — sit in state House districts that voted for Trump and elected a Republican in 2024. More than half of planned Texas data centers are in unincorporated areas, up from 12% of existing ones — meaning they land in exactly the places with the least local authority to say no.
Agriculture Commissioner Sid Miller said it plainly in Lubbock on August 6: “Republicans should be on this issue and we’re not. The Democrats are, and they’re right on the issue. I’m not endorsing any Democrats, but we’re going to lose some elections in the midterms because of this one subject.”
9.3 The coalition is not unified — and the article flattens it
Reporting this as “landowners versus the lines” obscures at least five distinct positions that want incompatible things.
| Position | Who | What they actually want |
| Deny outright | Sen. Schwertner; Rep. Brad Buckley; most July 29 witnesses; Lt. Gov. Patrick (per most coverage) | Denial, so the 90th Legislature rewrites the process and utilities refile under new law. |
| Defer the need finding | American Stewards of Liberty; 43 legislators via a TPPF-drafted amicus brief | Reopen the demand case and force consideration of local gas generation. |
| Reroute | Hill Country Preservation Coalition; Bandera, Real, Edwards and Val Verde county resolutions; Devils River Conservancy | Move the lines to highway and existing corridors. The lines still get built. “We’re not against progress.” |
| Reform and build | Association of Electric Companies of Texas; Sen. Kolkhorst; Patrick’s own words | Fix notice and routing. Patrick said explicitly the lines are ones “many believe must be built.” |
| No delay | Oncor; Texas Oil & Gas Association; Permian Basin Petroleum Association | Proceed. “The greatest risk of failure is for these necessary projects to falter under any sort of delay.” |
| The ideological cross-current the coverage keeps missing The intellectual engine of the pause campaign is the Texas Public Policy Foundation, which drafted the 43-legislator amicus brief. TPPF also opposes the state’s wind and solar buildout, and its policy director argues Texas should “expand local gas generation” rather than transport power “to manage the problems associated with overbuilding wind and solar.” Sen. Sparks made the same point at the hearing: “If we charge through with these lines right now, it’s almost guaranteed that what we’ll fill these up with is more wind, mostly solar.” So one of the strongest currents against these lines is not property-rights conservatism at all — it is opposition to renewables, wearing property rights as a coalition partner. And the pro-transmission counterweight includes environmental groups, because 765-kV lines would move a great deal of West Texas wind and solar. Framing this as ranchers versus oil companies gets the alignment backwards. |
9.4 Texas is an outlier on scale and a laggard on tools
Local governments elsewhere kill data center projects by denying rezoning. Texas counties cannot — they have no zoning authority. The consequences are visible:
- Hood County: commissioners rejected a six-month pause 3–2 after a state senator sent a same-day letter to the attorney general asserting counties lack moratorium authority. They then cut allowed lot coverage from 50% to 10% — one commission member conceded the strategy was to make the rules strict enough “so none of them come.” Two developer lawsuits are pending.
- Hill County: passed the state’s first county data-center moratorium on May 12, 2026. A developer sued for $100 million in federal court on May 27. The moratorium was rescinded unanimously on June 4. Preemption did in four weeks what politics could not.
- San Marcos: voted 4–3 on June 16, 2026 to make data centers ineligible anywhere in the city — the first outright Texas municipal ban. A state senator has said he will challenge it.
- Fort Worth: voted unanimously on August 11, 2026 to take the first step toward a moratorium and to require every new application to show PUC and ERCOT interconnection approval — precisely when the state approval process is frozen.
- Texas has no statewide initiative process, so the referendum route available in other states is closed. At least 34 counties have formally asked the state for more information.
Where Texas is genuinely ahead is market design — SB 6’s curtailment mandate, its 75 MW interconnection regime, and the December 4CP rewrite have no real peer in other states. The gap is in land use and water, not electricity markets.
9.5 The tax fight running in parallel
The data-center sales tax exemption has gone from costing the state $5–30 million a year between 2014 and 2022 to at least $1.3 billion in fiscal 2026. The biennial estimate for 2027–28 was revised from roughly $180 million to $3.2 billion. At a July 27 Senate Finance hearing it emerged that of 138 qualified data centers, only 20 had been audited — and 6 of those 20 were in breach. The Finance chair, who voted for the exemption in 2013, said: “No tax exemption should operate on autopilot.”
10. What to watch
| When | What | Why it matters |
| Aug. 18–19, 2026 (unconfirmed) | Reported House Committee on State Affairs hearing on the 765-kV regulatory and planning process, chaired by Rep. Ken King | First House engagement. The Senate has moved; whether the House matches determines if this is a Patrick project or a chamber-wide one. Call before relying on the date — no notice appears in Texas Legislature Online as of Aug. 17. |
| Aug. 21, 2026 | PUC may act on Dockets 59029 and 59315 — the northern line | The first real test. Not the Hill Country line, contrary to some coverage. |
| Aug. 25–27, 2026 | AEP Texas open houses on the Blu Lacy–Howard segment | A 150-mile segment from Nueces to Bexar County — evidence the buildout extends well beyond the Hill Country. |
| End of Aug. 2026 | PUC deadline on Howard–Solstice, Docket 59336 | The Hill Country line. The single most-watched decision. |
| Sept. 2026 | LCRA expects a decision on Bell County East–Big Hill, Docket 59475 | 122 alternative routes, 14 counties including Burnet, Llano and San Saba. The PUC already delayed this once in June. |
| Overdue | Docket 59182 (Big Hill–Sand Lake) is past its 180-day deadline | Anyone can seek mandamus to force a decision. Watch for whoever moves first. |
| Nov. 2026 | Bill pre-filing opens; Abbott and Patrick on the ballot; possible Lubbock moratorium ballot measure | The first electoral read on whether the backlash converts into votes. |
| Dec. 31, 2026 | Statutory deadline for the PUC to amend its cost allocation rules — Project 58000 | The most consequential and least covered date on this list. Could shift roughly 10% of transmission cost off residential bills without any legislation, one month before the session convenes. |
| Jan. 2027 | 90th Texas Legislature convenes | Schwertner wants “a complete overhaul” of the certification process. Abbott wants data centers to bring their own generation, pay their own interconnection, use closed-loop water, and lose the sales tax exemption. |
10.1 Three questions the reporting has not answered
- Has the Public Utility Commission ever denied a major transmission certificate? No precedent was found in any source. If the answer is genuinely no, that reframes both the political demand and its likelihood.
- ERCOT commissioned its own study from the University of Texas Bureau of Economic Geology, which put Permian oil and gas load at roughly half what the industry-funded S&P study projected. Why did the higher number drive the plan? Someone should ask that question on the record.
- If the cost allocation rewrite lands in December and shifts real cost onto large loads, does it defuse enough of the political pressure to let the lines proceed — or does it arrive too late, after the applications have already been denied?
| What to tell someone who asks why this matters Texas is about to spend roughly $33 billion statewide — of which the Permian plan is about $14 billion, and which could reach $46 billion if the CREZ overrun rate repeats — recovered from every electricity customer in the state, on infrastructure justified by a demand forecast that ranges by nearly a factor of two depending on whose numbers you use. The statute requires the regulator to weigh the highest one. The Legislature ordered it near-unanimously, compressed the review window, and told the commission to defer to the applicants. Now, facing voters who oppose the development driving it by roughly two to one, it wants the decision back. Whichever way it resolves, someone pays: ratepayers for lines that may not be needed, or West Texas for reliability it has been promised for a decade. There is no version where nobody loses. |
Sources
Primary documents were prioritized over reporting wherever both existed. Two constraints on this research are worth stating: the PUC Interchange document server and texasscorecard.com both block automated retrieval, so filings and some quotes are sourced through trade press, party filings and search extraction rather than the original pages. Docket numbers are given so they can be pulled directly.
Primary — statute and orders
- HB 5066 enrolled text (88th Legislature, 2023) — capitol.texas.gov/tlodocs/88R/billtext/html/HB05066F.htm
- SB 6 enrolled text (89th Legislature, 2025) — capitol.texas.gov/tlodocs/89R/billtext/html/SB00006F.htm
- Texas Utilities Code Chapter 37 — statutes.capitol.texas.gov/Docs/UT/htm/UT.37.htm
- PUC First Order approving the Permian Basin Reliability Plan, Oct. 7, 2024 (Project 55718)
- PUC Second Order selecting the 765-kV import paths, Apr. 24, 2025
- 16 TAC §25.192, four coincident peak allocation — puc.texas.gov/agency/rulesnlaws/subrules/electric/25.192/25.192.pdf
- Howard–Solstice CCN application, Docket 59336 — cpsenergy.com (Part 2 filing, Mar. 2026)
- Buckley/Sparks pause request, Docket 59029 Item 483; 43-legislator amicus brief, Item 465
Primary — ERCOT
- Permian Basin Reliability Plan Study, July 2024 — the source of the 345/500/765 comparison table
- 2024 Regional Transmission Plan: 345-kV Plan and Texas 765-kV STEP Comparison, Jan. 2025
- Senate Business & Commerce presentations, July 29, 2026 — Panel 1 (Vegas, load) and Panel 2 (Rickerson, 765 kV)
- ERCOT all-time peak demand records — ercot.com/static-assets/data/news/content/a-peak-demand/all-time-records.htm
- ERCOT West Texas Load Study, June 2022
Analysis and advocacy — read with the source’s position in mind
- NRG, ERCOT Transmission Costs and Rate Design, Feb. 25, 2025 — the $178–268/year residential estimate
- Texas Public Policy Foundation, The Explosion of Transmission Costs in ERCOT, Jan. 2026, and the 765-kV STEP assessment, June 2026 — TPPF opposes both the plan and the renewable buildout
- Sierra Club, Texas’ $33 Billion Transmission Plan, June 2026
- Brattle Group, ERCOT Cost of New Entry for the 2026 Online Year
- Potomac Economics, 2025 State of the Market Report for ERCOT
- American Stewards of Liberty, Motion to Defer Determination of Need, Docket 59029
Reporting
- Texas Tribune — July 31 and Aug. 14, 2026 coverage of the hearing, Patrick’s intervention, and the PUC special meeting
- KUT — July 30, 2026, the fullest account of the 15-hour hearing
- E&E News — “$33B transmission build-out leaves Texas ranchers fuming” and “Texas regulators urged to halt $33B transmission plan”
- The Texan — official reactions to the July 29 hearing
- Texas Scorecard — the Gleeson “never explicitly approved” reporting (advocacy-aligned; the verb “admitted” is theirs, though the substance is independently corroborated by the Oct. 2024 order)
- Utility Dive and RTO Insider — the 2024–25 PUC approval sequence
- DailyTrib — Aug. 7, 2026, on the scheduling of the House hearing and PUC meeting
- San Antonio Express-News — “Century-old H-E-B-tied farm threatened by biggest-ever Texas transmission line,” July 26, 2026
- Polling: UT/Texas Politics Project (June 2026), Emerson College/Nexstar (Aug. 2026), Texas A&M Bush School/ReconMR (July 2026), UH Hobby School (Apr. 2026)
| One correction to carry forward The Express-News story the article links to describes Constanzo Farm in Atascosa, southwest Bexar County — the Adamek family. The H-E-B connection is a roughly 90-year supplier relationship dating to the 1930s, when the current owner’s grandfather drove produce to San Antonio’s Market Square in a Model T. The Butt family does not own the farm. Any summary saying “H-E-B’s farm” would be wrong. |
Confidence levels
Not everything in this document is equally well established. Three tiers:
- Verified against primary documents. All HB 5066 content and vote counts; Schwertner’s Senate sponsorship; the §37.057 and §37.056(c-1) statutory text; the ERCOT 345/765 cost comparison ($12.95B / $13.77B statewide $30.75B / $32.99B); the 434-mile right-of-way differential; the $229M and $28M savings figures; the April 2025 voltage selection; the December 2025 ERCOT board endorsements. Build on these freely.
- Corroborated across independent reporting but not re-read from the source. The July 29 hearing and its quotes; the Aug. 14 PUC meeting; Patrick’s and Schwertner’s statements; the docket details for Howard–Solstice and the other lines; the polling; the local data-center fights; the Texas Energy Fund figures. Solid, but cite the underlying source rather than this document.
- Single-chain sourcing — confirm before publishing. The Aug. 19 House hearing (probably wrong); the AECT president’s quote; the 1,340 / 2,105 MW per-path transfer figures; the NRG and CREZ bill-impact numbers; the flaring baseline; Jimmy Fair’s testimony; and the Campbell and Staples quotes carried over from the article itself. The PUC Interchange server and several news sites block automated retrieval, which is the reason for most of these gaps.