Austin Energy Raised Its Residential Solar Rebate by 60% – now $4000 – and increased the solar buy-back (Value-of-Solar or “VoS”) rate by 30%
By Adam Glick, Solar Sherpa, NATiVE Solar

Here’s some local news we’ve been waiting on for a while: Austin Energy (the City of Austin) has increased its solar incentives! The residential rebate rose from $2,500 to $4,000 for eligible projects, commercial and nonprofit incentives rose 25% to 66%, and the Value of Solar monthly “solar buy-back” utility bill credit increased 30% to 12.89 cents per kW/hour. If you live in Austin and shelved a solar project in the past, the new numbers may make it worth a second look.

What Changed

Three things moved in the customer’s favor in the past few months:

• 60% increase on Residential solar rebate: $2,500 to $4,000 per eligible projects.
• 30% increase in Value of Solar (VoS or monthly solar energy buy-back) credit: Austin Energy now lists the rate at 12.89¢ per kWh for systems under 1 MW, up from 9.91¢.
• Commercial and nonprofit incentives: higher capacity-based and performance-based payments, detailed below.

For new solar owners, these new numbers matter -both up-front and over time. Let’s dig in here with a quick run-down, folks.

Who May Qualify for the $4,000 Rebate

Austin Energy’s published requirements for the residential solar rebate are specific:

• You have an Austin Energy residential electric account, and the system is installed at that address.
• The solar system is new and was not installed before you submit the rebate application.
• The solar system is 3 kW (DC) or larger and mostly free of shading.
• You use an Austin Energy participating solar contractor. A non-participating installer cannot offer the rebate.
• You receive a Solar Rebate Confirmation Letter before installation begins.

*That last point is important. If panels go on the roof before the confirmation letter arrives, you lose the rebate. (Don’t let that happen!) Eligibility varies by project, and Austin Energy makes the final determination. Our advice: do the paperwork up-front! If you have questions, we’re here to help make sure you  can get the credit. :)

How the Application Works

1. Take Austin Energy’s Solar Rebate Quiz. You’ll need your contact information, address, and utility account number. You receive a rebate reference number when you finish.
2. Collect proposals. Austin Energy recommends at least three quotes from participating contractors.
3. Give your reference number to your contractor, who applies for the rebate on your behalf.
4. Sign the interconnection agreement and customer agreement form.
5. Wait for the confirmation letter, then proceed with installation. *Be sure to choose your selected installer wisely :)
6. Pass the final solar inspection. Austin Energy checks the new system and new solar meter -and then grants permission to operate (aka “PTO”).
7. Quality assurance review. Once approved, Austin Energy mails the rebate check.

The rebate check is cut and sent to homeowners who have satified the requirements. It’s pretty easy money if you ask us.

What the Rebate Does Not Do

A few limits are worth stating plainly:

• It does not replace the federal residential tax credit, which expired at the end of 2025.
• It does not cover batteries. Solar panels alone shut off during a grid outage. If resilience is the goal, the design needs to include battery energy storage (which would allow solar power to feed the property during grid outages). Austin Energy runs a separate pilot, Power Partner Battery, that rewards battery owners for supporting the grid during high demand –we covered this program recently here. More here on our Texas-wide battery incentive programs page.
• Residential power purchase agreements are not allowed in Austin Energy territory. If a new system has been structured/acquired as a “PPA”, ya can’t get the credit.

The Newly Increased Value of Solar (‘Vos”) Rate Deserves Equal Attention

Austin Energy handles your excess harvested solar energy under a “buy all, sell all” strcuture. In other words, it meters everything your system produces and credits 100% of that production at the Value of Solar rate. You continue to pay standard residential rates for the electricity your home consumes, and then that VoS credit is applied against electricity charges on your monthly bill. So you buy all your energy from AE at the standard rate, then sell back all your solar-harvested power to the grid at the VoS rate, which is then credited against your utility bill each month.

The credit effectively lowers your utility bill each month the system operates.

As a rough illustration: an average-sized solar harvesting system of 8 kW would likely generate (at minimum) about 10,400 kWh annually. At 12.89¢, that is roughly $1,340 per year in projected bill credits, compared with about $1,030 at the previous rate. This can add up over years to considerable utility bill savings.  (Take these numbers as an illustration only please. Every system is different and will produce differently)

Commercial and Nonprofit Incentives Also Increased

The City is really getting serious about recognizing the benefits of solar power from all sources. This applies to business and nonprofit customers as well; Austin Energy has also raised both of its commercial and institutional incentive structures.

Performance-based incentives are paid per kWh produced over five years, in addition to Value of Solar credits. For a facility with a large roof and/or covered parking structures fitted with solar panels (aka solar carports), these energy production payments can meaningfully shift a project’s projected payback.

Nonprofits should take note of the $1.00 per watt figure. Churches, schools, and community organizations with smaller systems saw the largest percentage increase of any customer group.  We’re jumping for joy over this one here at NATiVE!

Federal tax credit rules for commercial projects have tightened this year, with construction-start and placed-in-service deadlines now in effect. (*You’ve got to complete the project and have the new system up and running by the end of December, 2027*). Now we are not tax experts – we want you to please consult a tax advisor and/or your finance team on how those rules apply to your project and organization.  Our commercial solar page covers how we can help our clients evaluate project economics for Texas facilities planning to add solar harvesting capacity.

Next Step

If you’re an Austin Energy customer weighing a project for your home, business, or nonprofit, we can walk through what you may be eligible for and what a system would realistically produce. Start a conversation with our team.

ERCOT 12CP: What the End of 4CP Means for Texas Facilities’ Electrical Demand Charge Assessment
By Adam Glick, Solar Sherpa, NATiVE Solar

For more than twenty years, large commercial power users in Texas have cut a big piece of their electric bill by using less power on four specific summer afternoons -by which the utility bills’ “demand charge” is set for each customer. State regulators now plan to replace that system, known as 4CP, with ERCOT 12CP, which counts a peak in every month of the year. Here is what is proposed, who it affects, and where solar + battery energy storage fits.

One note before we start: as of early October 2026, this is a proposed rule. The Public Utility Commission of Texas (PUC) expects a final decision in December.

*Heads up: This article is a bit longer and more in-depth than most here at The Feed. Here’s the short version before we get started:

• What is changing: Texas plans to divide the cost of upgrading and maintaining our state’s transmission grid using calculations based on twelve monthly grid peak measurements instead of four summer ones.
• Who it applies to: Every utility in ERCOT. The rule changes how the statewide grid bill is split among them. How that cost reaches your bill depends on your utility and your size.
• Affected most directly: Facilities over 700 kW in the Oncor, CenterPoint, AEP Texas and TNMP areas. They are billed today on their own usage at the grid’s four summer peaks, so twelve peak measurements would change how their charge is calculated.
• Smaller businesses in those areas: You are billed on your own monthly peak, and that method is not changing. This said, your rate could shift as costs are re-divided among customer groups.
• In Austin, San Antonio or a co-op area: Your utility’s share of the grid bill would be set by twelve peaks instead of four. The city or co-op board decides how to pass that on to you.
• When: A final decision is expected in December 2026. Nothing is final yet.
• What to do now: Perhaps find out how your utility bills you for transmission, and look at your power use in every month, not just summer. Also, maybe be open to new ways your site might be able to reduce grid power draw during those times. (hint: adding solar and BESS (battery energy storage) could be one way. :)  )

What 4CP is, in plain English

Everyone in Texas helps pay for the high-voltage transmission grid. For large users in much of the state, the share is set by a method called “four coincident peak,” or 4CP.

First, one definition. Demand is how much power you draw at one moment, measured in kilowatts (kW). Energy is how much you use over time, measured in kilowatt-hours (kWh). Think of demand as your speed and energy as the miles you drive. 4CP is about demand.

Here is how it works. In each of June, July, August and September, the ERCOT (Electric Reliability Council of Texas) grid hits one highest 15-minute moment. “Coincident” means at the same moment. What counts is how much power your facility was drawing at the grid’s peak, not at your own.

The average of those four readings sets your transmission charge for the entire next year, as Oncor’s delivery-charge guide explains. So if you use less power during those four 15-minute windows, you pay less (by way of lower “demand charges” on your utility bill) for the next twelve months.

Who is on 4CP billing? In the competitive areas served by Oncor, CenterPoint, AEP Texas and TNMP, meters with peak demand over 700 kW are billed on 4CP. Smaller commercial accounts are billed on their own monthly peak instead. Austin Energy works differently, and we cover it in its own section below.

What it is worth. Each kilowatt you are drawing during those four peaks costs about $68.55 over the following year. That rate is up 121% since 2013. A facility that cuts 1,000 kW (one megawatt) during the peaks avoids about $68,550 a year at the full rate, or about $40,740 at Oncor’s rate, according to a joint filing by Base Power, Octopus Energy and Tesla.

Bottom line: under 4CP, four short windows each summer set a full year of transmission charges.

Why regulators are moving on from 4CP

Three things are pushing the change to ERCOT 12CP.

The law requires it. Senate Bill 6, passed in 2025, tells the PUC to revisit how transmission costs are divided and to change its rules by December 31, 2026 (K&L Gates summary).

The grid’s stress points have moved. 4CP only looks at summer afternoons. According to the same summary, PUC staff found the grid now runs tightest on summer evenings, after solar output drops, and that 4CP ignores winter shortages entirely. Staff also found 15 minutes too short a window. ERCOT’s independent market watchdog has recommended dropping 4CP since 2015, according to an ERCOT board presentation from September.

Households are paying more than their share. In 2024, homes used 34.5% of the electricity but paid 46.7% of transmission charges, according to PUC staff figures cited in the retail-provider filing. The reason is simple. When a large user cuts back during the four peaks, its share of the bill does not disappear. It moves to everyone else. As PUC Chairman Thomas Gleeson put it on the Energy Capital Podcast in June, “those transmission costs have to be paid by someone.”

The bill itself is also growing. ERCOT endorsed about $14.0 billion of transmission projects in 2025, compared with $3.8 billion in 2024.

What the ERCOT 12CP proposal would change

On July 9 the PUC voted to publish a proposed rule, Project 58000. It appeared in the Texas Register on July 24. The core change replaces 4CP with ERCOT 12CP:

The proposal also sets a minimum charge, lasting at least 20 years, for “large loads.” ERCOT defines a large load as 75 megawatts or more at a single connection point. That piece is aimed at data centers, not at a typical plant, hospital or distribution center.  This seems like a fine idea to us here at NATiVE. :)

None of the ERCOT 12CP proposal is final. Public comments closed August 11. In a July 17 letter to Gov. Abbott, Chairman Gleeson wrote: “The PUCT expects to make a final decision on the rulemaking in December 2026.” He has also said the commission may count some months more heavily than others, or group the peaks in summer and winter. The details could still change.

Who ERCOT 12CP applies to

The rule applies to every utility in ERCOT, but it does not reach every customer the same way. Think of a restaurant bill split among several tables. The rule changes how the bill is split among the tables. How each table divides its share among the people sitting at it is a separate question.

First, the grid bill is split among utilities. This part applies to everyone. Oncor, CenterPoint, Austin Energy, CPS Energy and the electric co-ops would all have their share set by twelve monthly peaks instead of four summer ones.

Then each utility bills its own customers. This is where it differs. The PUC sets customer rates for the investor-owned utilities, such as Oncor, CenterPoint, AEP Texas and TNMP. City-owned utilities and co-ops set their own.

Bottom line: everyone is affected, but large facilities in the investor-owned utility areas are affected most directly.

What ERCOT 12CP could mean for your facility/site:

The biggest unknown is your own bill. The proposal explains how the cost is divided among utilities and among customer groups. It does not yet say how each utility will calculate an individual large customer’s charge. That answer comes after the final rule, when each utility files its new rates. (We’ll try to cover this in a timely manner with updates published here at The Feed.)

Twelve peaks to manage instead of four, and each counts for less. Today, each summer peak sets about a quarter of a large facility’s transmission charge. With twelve equally weighted peaks, each would set about one-twelfth. The retail-provider filing estimates that power used during a 12CP peak would effectively carry more than $5,000 per megawatt-hour in transmission line cost.

Sites that cut back in summer have more to cover. A facility that has reliably reduced its power use for four summer peaks would now have eight more months to watch. The forecasting firm Amperon notes that the months nobody used to watch have the weakest track record.

The shift between customer groups looks modest. A draft PUC staff analysis shows 12CP lowering the residential share of transmission cost by about 3.1 percentage points, from roughly 46.3% to 43.1%. The retail providers call that “meaningful but still relatively small.”. Yeah, it’s small, but it ain’t nothin’ -plus other parts of the new PUC rules should mean that the additional cost burden of new data centers should also largely be kept away from us “normal” residential and commercial rate-payers that aren’t gobbling up so much energy as those gargantuan facilities.

The total does not shrink. ERCOT 12CP changes how the transmission bill is divided, not how large it is.

What ERCOT 12CP means for Austin Energy customers

Austin Energy customers are not billed on 4CP. Commercial customers at 10 kW and above pay a Regulatory Charge on their own highest 15-minute peak each month. That charge covers Austin Energy’s ERCOT transmission costs and related fees, according to its tariff. In other words, Austin businesses already pay for transmission on twelve peaks a year. They are their own peaks, not the grid’s.

That charge just went up. On October 1, 2026, it rose from $3.73 to $5.03 per kW for secondary-voltage customers, about 35%. Austin Energy’s budget shows transmission and ERCOT expenses rising from $217.7 million to $234.8 million. Add the demand charge, and a secondary customer at 300 kW or more now pays $18.22 for each kW of monthly peak, based on Austin Energy’s posted rates.

Summer still matters in Austin, but not the way 4CP does. Your demand is measured every month, and each bill is based on that month’s own highest 15 minutes. What summer decides is your rate class. Once a year, Austin Energy averages your June through September demand to place you in a class, such as 10 to 300 kW or 300 kW and up, and that class sets your per-kW rates for the next calendar year. Separately, Austin Energy pays businesses $50 to $80 per kW to cut load during summer peak events through its Commercial Demand Response program.

4CP also shapes how Austin Energy values solar. The formula in Austin Energy’s tariff for valuing solar production includes a credit for avoided ERCOT transmission charges. That credit is based on how much solar was producing during the hour of ERCOT’s peak in each of June, July, August and September. In other words, solar earns part of its value in Austin by showing up at the four summer peaks. If Texas moves to twelve peaks, including winter mornings and evenings when solar produces little, that formula may need to change. Austin Energy has not said how it would handle that.

ERCOT 12CP would reach you indirectly. Austin Energy’s own share of the statewide grid bill is set by the city’s load at the four summer peaks. Under 12CP it would be set by twelve. How that changes the Regulatory Charge is a City of Austin decision that has not been announced.

Bottom line: in Austin, your own monthly peak already drives what you pay for transmission. Lowering it, with load management, solar or solar + storage, may reduce both your demand charge and your Regulatory Charge.

When ERCOT 12CP peaks are likely to land

ERCOT 12CP counts one peak per month, so the time of day those peaks tend to fall matters for planning.

Summer peaks are moving later, past solar’s best hours. ERCOT’s highest peak of the year fell at 5:00 p.m. every year from 2008 through 2022. It then fell at 6:30 p.m. in 2023 and 6:00 p.m. in 2024, according to a table in NRG’s filing. This summer’s all-time record of 91,134 MW, set July 22, came between 6 and 7 p.m. (ERCOT summer review).

Winter peaks come early and late. ERCOT says winter risk is highest from 6 to 9 a.m. and 6 to 9 p.m., hours with “the highest loads and low or no solar production” (ERCOT Monthly). Winter peak demand has grown about 30,000 MW in ten years.

Bottom line: many of the twelve peaks are likely to fall when the sun is low or down.

Where solar + storage fits

Solar still does what it has always done. It reduces the amount of grid energy you buy and lowers your demand through the sunny hours, including many summer afternoons. ERCOT’s own review of this summer credits it at grid scale: “Solar growth outpacing large load additions helped make the daytime hours this summer uneventful.”

What solar cannot do alone is cover a January morning at 7 a.m. or a July evening at 7 p.m. That is the job battery energy storage is suited for. Covering a 30-minute window is short work for a properly sized battery. The harder part is knowing which half hour it will be, twelve times a year. That takes good forecasting and controls. Your company’s site energy plan(s) should comprehend this.

There is also a year-round reason to manage demand that has nothing to do with this rule. Under Oncor’s rates, you are billed for the higher of two numbers: this month’s peak, or 80% of your highest peak in the previous 11 months. One bad interval can follow you for a year. In Austin, each month’s charge is based on that month’s own peak.

NATiVE has treated commercial solar as a systems engineering problem since 2007, and our advice is the same under 4CP or ERCOT 12CP. Start with twelve months of your meter data. Find out when your facility peaks compared with the grid. Size the system from there. For some sites, that points to solar + storage now. For others, solar alone does the job and storage waits until the numbers support it. Either way, solar + storage may reduce exposure to demand-based charges. How much depends on your usage pattern, your rate and your utility.

What to do before December, perhaps

1. Ask your electricity provider or broker whether your meter is billed on 4CP.
2. If you are served by Austin Energy, CPS Energy or a co-op, ask how it plans to pass 12CP costs through to commercial rates.
3. Pull twelve months of interval data, your meter’s record of power use in 15-minute steps, from your utility or Smart Meter Texas.
4. Ask your provider how transmission charges pass through in your contract, and what happens if the method changes mid-term.
5. Look at your demand during each month’s grid peak, not just the summer ones.
6. Watch for the PUC’s final ERCOT 12CP rule, expected in December, and the utility rate filings that follow. (We’ll be reporting o that here at The Feed.)
7. If you are evaluating solar or storage, ask a competent solar+BESS design-construction firm (blatant NATiVE Solar plug here) to help with the modeling under both methods.

Not sure how your facility is billed for transmission, or what twelve peaks could mean for it? Talk with our commercial team. Bring a recent bill and we will start there.

Frequently asked questions

What is ERCOT 12CP?

ERCOT 12CP stands for twelve coincident peak. Under it, transmission costs would be divided using demand during the grid’s highest 30-minute window in each calendar month, instead of four summer windows.

When does ERCOT 12CP take effect?

No date is set. The PUC expects a final decision in December 2026. The proposal measures peaks from October 1 through September 30, with ERCOT filing the results by December 1 each year.

Does ERCOT 12CP apply to my business?

It applies to every utility in ERCOT, so every business is affected in some way. Facilities over 700 kW in the Oncor, CenterPoint, AEP Texas and TNMP areas are affected most directly, because they are billed on their own usage at the grid’s peaks. Smaller businesses, and customers of city-owned utilities and co-ops, are affected through how costs are shared and passed on.

Will ERCOT 12CP lower my electric bill?

Not by itself. It changes how the transmission bill is divided, not its size. Sites that relied on cutting back in summer may see their share rise unless they manage demand year-round.

Does solar still help with demand charges under 12CP?

Solar helps in daylight hours, including many summer peaks. Winter and evening peaks fall when solar output is low, which is where battery storage and load management come in to play.

Does 12CP apply to Austin Energy or CPS Energy customers?

Not directly. City-owned utilities and co-ops would see 12CP in what they pay for the grid, and they set their own customer rates. Austin Energy already bills commercial customers for transmission on their own monthly peak, through its Regulatory Charge. We’ll be watching from here at our Austin (Dripping Springs) HQ and will publish updates when/if anything changes for commercial sites within AE’s and CPS’s jurisdiction.

Sources and how we checked them

We referenced the proposed PUC rule itself, ERCOT’s own reports, and Austin Energy’s tariff and budget -among other sources. Yes, we used AI a bit to help us sort through all the data and its implications. We did not have direct access to some of the reporting and data on this topic, including a paywalled trade-press account of the July 9 vote, several filings in the PUC’s document system, and the PUC staff’s final report. Where that was the case, we worked around the edges to substantiate the facts through documents we could open: the Texas Register, ERCOT board materials, the PUC’s letter to the Governor, and public filings that quote the staff report’s figures. The staff numbers above come from the draft report, as quoted in those filings, and two of our sources (NRG and the retail-provider coalition) have a stake in the outcome.

• PUC Project 58000, proposal for publication (July 9, 2026)
• Texas Register, July 24, 2026
• PUC Chairman Gleeson, letter to Gov. Abbott (July 17, 2026)
• Energy Capital Podcast with Chairman Gleeson (June 10, 2026)
• K&L Gates, alert on the PUC staff draft report (March 30, 2026)
• NRG Energy, comments in PUC Project 58484 (September 2025)
• Base Power, Octopus Energy and Tesla, joint comments in PUC Project 58484
• ERCOT, staff response to the Independent Market Monitor (September 2026)
• ERCOT, Summer 2026 Operational and Market Review
• ERCOT Monthly, November 2025
• ERCOT, System Planning and Weatherization Update (February 2026)
• Oncor, Delivery Charges 101
• Amperon, 12CP explainer (August 2026)
• City of Austin Electric Tariff, FY 2027 (effective October 1, 2026)
• City of Austin Electric Tariff, FY 2026
• Austin Energy, commercial rates
• Austin Energy, FY 2027 proposed budget (July 20, 2026)
• Austin Energy, Commercial Demand Response program

It’s been a few weeks since we here at The Feed published our last newletter. There’s a ton happening and we’ve been super busy with both our commercial and residential projects! So here’s a digest of news bits gathered from (mostly) around the state- which we think are impactful and interesting for folks following the Texas solar (and battery storage!) marketplace.

Cities push back on Abbott’s plan to open Austin Energy and CPS Energy to competition (Texas Tribune, Sept. 8)
Abbott says ending city-owned utilities would cut average bills about 10% in Austin and San Antonio, while city and utility officials argue the change would raise rates and cost a lot to implement. Austin Mayor Kirk Watson called it a multi-year process that would cost customers more than a billion dollars. We aren’t quite sure what to think about all of this yet, but we’re closely watching the progress…
https://www.texastribune.org/2026/09/08/texas-austin-energy-san-antonio-cps-abbott/

ERCOT (Texas grid operator) load keeps setting records (Utility Dive, ~Sept. 8)
EIA says average hourly load in the week ending Aug. 22 was 10% above any week last summer and 6% above the 2023 record, and six straight weeks beat that 2023 mark. The fact that we saw no widespread or extended grid outages during the summer peak loads makes us think that maybe the regulators and utilities are finally investing in the infrastructure needed to strengthen our stressed-out grid for coming years.  https://www.utilitydive.com/news/load-ercot-record-highs-eia/829801/

PUC approves Texas’s first 765-kV lines (Texas Tribune via TPR, Aug. 28)
On Aug. 28, regulators unanimously approved two Oncor projects covering more than 400 miles of 765-kV line, despite objections from lawmakers, landowners and the Attorney General. This seems ok to us here at NATiVE. “Repowering” existing high-tension utility poles for higher-capacity transmission lines seems like a no-brainer given the forecasted load demand growth.
https://www.tpr.org/news/2026-08-28/texas-regulators-approve-two-massive-west-texas-transmission-lines-amid-outcry-from-landowners

Study says reconductoring could save Texas $20B (pv magazine USA, Aug. 31)
Evolved Energy Research modeled a high-growth ERCOT scenario in which $10 billion of reconductoring avoids $30 billion in new-build transmission. About $35 billion of new lines would still be needed. This article provides more context to the related entry and link above.
http://pv-magazine-usa.com/2026/08/31/reconductoring-existing-transmission-lines-in-texas-could-save-20-billion-study-says/

Batteries are now setting evening power prices (Quartz, Aug. 21)
Batteries have started displacing gas peakers as the resource that sets wholesale prices. Energy trading made up 76% of Texas battery revenue by June 2025, triple the share a year earlier. Most of the battery capacity driving down the rate prices is coming from utility-scale BESS, but smaller commercial and residential grid-connected batteries are beginning to make a dent as well.
https://qz.com/batteries-set-electricity-prices-wholesale-markets-081726

Austin moves to regulate, and possibly ban, large data centers (CBS Austin, ~Aug. 28)
Council voted unanimously on Aug. 27 to start drafting rules, with binding regulations due by the end of 2026 and support for prohibiting larger facilities. For those of us who want to see more constraints placed on hyperscalers, this will be welcome news.
https://cbsaustin.com/news/local/austin-city-council-unanimously-moves-forward-with-new-data-center-regulations

Texas leads the U.S. in generation growth (Yahoo, ~Sept. 10)
Texas utility-scale generation grew 3.2% in the first half, versus 2.1% nationally. Solar output rose 35.2%, and in May solar out-generated coal for the first time on a monthly basis. We’ve officially taken the lead from California, ya’ll.
https://www.yahoo.com/news/us/articles/solar-powers-texas-fastest-electricity-161115125.html

EIA expects solar to pass coal in ERCOT (North American Dallas, Aug. 31)
EIA projects solar will out-generate coal most months of 2026, with ERCOT solar reaching 99 billion kWh in 2027 compared with 66 billion from coal. -More good news for those of us who care about the planet’s environment.
https://www.nadallas.com/2026/08/31/581544/solar-gains-ground-in-texas-energy-mix

Second-life EV batteries power a San Antonio-area BESS (Solar Power World, Sept. 9)
B2U’s Bexar Martinez project now provides 28 MWh of grid services to ERCOT in CPS Energy territory. The company plans 50+ MWh more over six months and says its sites qualify for the ITC domestic content bonus. Used batteries collected from crashed UV’s for the win here! We’re all for this! https://www.solarpowerworldonline.com/2026/09/repurposed-ev-batteries-now-delivering-28-mwh-of-grid-services-to-ercot/

Base Power launches commercial electricity plans (EnergyChoiceMatters, Aug. 25)
The plans are fixed-rate for business accounts. Base says pilot customers pay an average of 19% less, and it will cover up to $350 in early termination fees for small and medium businesses. [REVIEW: financial claim] The savings figure is company-reported, and Base also competes in residential batteries. Base Energy has a pretty compelling product and business model. We’re watching these folks closely
http://www.energychoicematters.com/stories/20260825c.html

Enphase builds solid-state transformer modules in Arlington (Transformer Magazine, Sept. 9)
The 4 kW modules combine into racks of up to 5 MW for AI data centers. Demonstrations are expected in November 2026, with pilots in 2027. As a Gold-level Enphase installation firm, we here at NATiVE see and appreciate the investment that ENphase has continued to make in helping Texas become a major centor of renewable tech manufacuring! https://transformer-magazine.com/news/enphase-starts-us-sst-module-production/

Well, there’s a lot more to report on, but we’ll save that for the next newsletter, folks.  Please be well and stay hydrated as we (hopefully) start to see temps dropping over the news few weeks!

Get in touch with us if you have any questions or concerns around solar for your own commercial or residential property. For any service-related issues, we’re always available to get your system running at top performance.

In 2011, a small rural district in Wise County put solar panels on its high school roof. Nobody called it a blueprint at the time. It kind of turned into one. In this short entry here @ The Feed, let’s take a look at how adding solar harvesting capacity is impacting a few independent school districts around the state.

Start with Eanes ISD, just outside Austin. The district was staring down a $3.3 million budget shortfall when it approved a districtwide solar initiative as part of its 2023 bond program. Solar arrays now cover 8 campuses, totaling 4.75 megawatts -the largest educational solar installation in the Austin area, bigger than anything that either the University of Texas or Austin Community College have put up individually to date. The district leveraged $3.5 million in Austin Energy rebates and $2.5 million in federal incentives to build it, and the projected result is about $700,000 in annual operations savings. Here’s how Eanes ISD’s own CFO put it (via CBS Austin):

“The solar energy program represents a win for both our district and our community… we’ve expanded our solar capacity and are now saving approximately half of the district’s annual electricity costs. It’s a clear example of fiscal responsibility and innovation working together to benefit our schools.” — Chris Scott, Eanes ISD CFO

Solar arrays installed at Westlake High School in Eanes ISD 

That’s half the district’s electric bill -way over half a milion bucks/year- redirected somewhere else -classrooms, staff, whatever the board decides is the next priority to support thousands of kids’ education. It’s impactful.

Zoom out and Austin ISD is playing a different game entirely. It’s the only Texas district to land a $15 million U.S. Department of Energy grant — one of 24 nationwide, chosen out of more than 1,000 applicants — and per the EPA, AISD already produces more solar power than every other Texas school district combined. The grant takes the district from 2 megawatts to 7, adding rooftop arrays and building-automation controls across 14 campuses through 2029. AISD’s sustainability director put the logic plainly (via Community Impact):

“Lowering our operating expenses for energy means increased financial stability for the school district.” — Darien Clary, AISD Director of Sustainability

That’s good stuff. But now go smaller and more rural, because this isn’t just an Austin-suburbs story. Bridgeport ISD, out in Wise County, used a grant from the State Energy Conservation Office (SECO) back in 2011 to put a 170 kW rooftop array on a brand-new energy-efficient roof at Bridgeport High School. Result: a 30–40% cut to the district’s overall utility costs (via GoSolarTexas) -that’s extra cash a small rural district was probably never going to find anywhere else in its budget.

And then there’s Presidio ISD, all the way out on the Rio Grande in Far West Texas -about as remote and budget-strapped as Texas public education gets. While absorbing state budget cuts, the district turned to the one resource West Texas has in genuine abundance: sunlight. Superintendent Dennis McEntire put the district’s philosophy about as simply as it can be put (via NewsWest9):

“Solar PV is our goal.” — Dennis McEntire, Presidio ISD Superintendent

Four districts, four very different sizes and situations -a wealthy Austin suburb, the largest solar producer in Texas public education, a small rural ISD in Wise County, and a genuinely remote border district -and the same basic math shows up every time: Grant money for solar construction plus less money out the door for utility bills every month means more money available for literally anything else a school board decides matters more. That’s the actual case for solar in schools. Not a slogan. A line item that moves.

The mechanics here -long-term reducuction in operating costs so the savings can be redirected- are exactly what we talk to municipalities, healthcare systems, and manufacturers about when we talk through commercial-scale solar for institutional facilities. If a rural ISD with a shoestring budget can make this math work, it’s worth a real conversation about whether your facility can too.

Thanks for reading, y’all!

Sources

• Eanes ISD unveils solar program to tackle budget shortfall with $700K annual savings — CBS Austin (KEYE), October 31, 2025
• Austin ISD slated for “Solar for Schools” federal grant — Environment America
• School District Case Studies — GoSolarTexas / SECO
• Presidio ISD Saving Thousands of Dollars With Solar Energy — NewsWest9

If you’ve researched solar or battery storage recently, you may have come across “meter collars”  -small adapters with sensors that promise to cut installation costs and skip a panel upgrade. They’re a real shift in how residential solar gets connected. But whether you can actually use one in Texas depends entirely on which utility delivers power to your address. In fact, there are a few details worth understanding before you get too far into project planning. OK, let’s go!

What a meter collar actually does

A meter collar (aka  “meter socket adapter” or (MSA)) installs between your existing utility meter and the meter socket on the side of your house. Instead of routing new solar, battery, or EV charging circuits through your main electrical panel, the collar provides a dedicated connection point right at the meter.

That matters because many older homes have 100-A or 125-A electrical services that weren’t sized for solar, storage, and EV charging on top of everyday household load. Historically, the fix was a full panel upgrade or a new subpanel -a project that adds real cost and time, and in some cases requires trenching, permitting delays, and utility coordination on top of the solar installation itself. NATiVE Solar has done hundreds of these over the years. Meter collars from manufacturers like ConnectDER, Enphase, and Tesla are designed to reduce or avoid that step by tapping in to the utility/grid power ahead of the main panel.

Newer meter collars also do more than provide a connection point. Because they sit at the point where utility power meets the home, they can read power flow for inverter control, support third-party ownership arrangements, and – if paired with the right hardware- act as a disconnect that automatically isolates the home from the grid during an outage so a battery system can power the house.

Some of the newest hardware assumes you’ll have one

This isn’t just a cost-saving option anymore  -some current battery hardware is built around it. Enphase’s 4th-generation Energy System, built around the IQ Battery 10C, System Controller 3M and IQ Combiner 6C, uses the IQ Meter Collar as the microgrid interconnect device (MID) that automatically and instantaneously isolates the whole home from the grid during an outage. For whole-home backup on a meter-main combination panel -the standard setup in many newer Texas homes, where the meter sits directly on the front of the main panel -Enphase’s own documentation treats the meter collar as essential to that configuration, since there’s no straightforward way to add a separate disconnect ahead of the panel otherwise.

In other words, the choice of battery hardware and backup configuration can quietly decide whether a meter collar is required, not just preferred. That’s a design decision that needs to be discussed before a system is proposed, not after a utility kicks back the interconnection application.

The catch: not every Texas utility allows them

This is a new technology which electric utilities are only now starting to catch up to. Meter collars require modifying the space around utility-owned metering equipment, which means each utility has to approve their use before an installer can put one in. That approval process isn’t uniform across Texas, and the differences are significant enough to shape how a project gets designed. Don’t worry, NATiVE’s in-house permitting department has you covered here.

Oncor, which delivers power across much of North and West Texas including the Dallas–Fort Worth area, explicitly does not allow meter collars. Oncor’s Electrical Service Guidelines reserve the space inside the meter socket for utility use only and instead require a Visible Lockable Labeled AC Disconnect (VLLD)  (a separate, accessible disconnect switch mounted within 10 feet of the meter) for every newly connected solar+battery distributed generation system. If a project is designed around a meter collar for an Oncor-served property, it will need to be redesigned around a VLLD instead.

CenterPoint Energy, serving the Houston area, similarly centers its interconnection requirements around a lockable, external-handle disconnect switch near the meter rather than a meter collar program.

Austin Energy, by contrast, references meter collar (aka “meter socket adapter”) configurations in its interconnection guidance, though projects still go through its standard PV meter grouping requirements and a variance process if equipment can’t be grouped as specified.

For other Texas utilities, including municipal and cooperative providers, policy varies and is worth confirming directly before a system is designed around collar-based equipment. Enphase’s own utility approval list, for example, currently includes Austin Energy along with several Texas electric cooperatives — but not Oncor or CenterPoint. NATiVE Solar has confirmed directly that other utilities including Bandera Electric Co-Op, Bluebonnet Electric Co-Op, Farmers Electric Co-op, and CoSersv are all supporting meter collars for new solar+battery installations.

What to do when the suggested system design needs a collar the utility won’t allow

WHat if you want the latest solar+battery components but your utility doesn’t allow for it? Well, you’ve still got options, folks: when a project’s battery configuration calls for a meter collar and the local utility doesn’t permit one, there are generally two paths forward, and which one applies depends on the utility.

Request a variance or alternate approval where the utility offers one. Some Texas utilities have a documented process for approving equipment that doesn’t fit their standard configuration. Austin Energy, for instance, has a formal meter variance process for equipment that can’t be grouped or located per its standard criteria, along with a meter collar consent form in its interconnection portal — meaning a project can be reviewed and approved on a case-by-case basis rather than rejected outright. Not every utility offers an equivalent path, and Oncor’s guidelines currently read as a flat prohibition with no published variance process specific to meter collars, so this route isn’t available everywhere. It’s also worth noting that a statewide standard is under active discussion: the Public Utility Commission of Texas is currently considering rule changes (Project No. 54233) that would establish a formal meter socket adapter approval process, with Tesla, Enphase, the Texas Solar + Storage Association, the Solar Energy Industries Association, and the Texas Advanced Energy Business Alliance all weighing in. That could eventually standardize approvals across utilities, but it isn’t in effect yet.

Install the collar as a standalone unit instead of behind the meter. Meter collar manufacturers, including Enphase, also support a standalone configuration where the collar sits in its own dedicated meter socket pan next to the utility’s meter rather than being installed behind it. Because a standalone unit doesn’t touch utility-owned equipment, it typically doesn’t require the utility’s sign-off the way a behind-the-meter installation does. This effectively functions as adding a second, customer-owned meter socket to the property -at the customer’s expense for the extra hardware and electrical labor- as a way to get the functionality of a meter collar even where the serving utility won’t approve one at the existing meter.

Which path makes sense depends on the utility, the battery hardware, and the home’s existing service -which is exactly the kind of question worth resolving during design, not during permitting.

Why this matters before you sign a contract

Here’s the bottom line, folks : The practical takeaway is that a meter collar quoted for a project in one part of Texas may not be usable at all in another, even though the underlying solar and battery equipment is identical. Getting this wrong late in the process can mean re-drawn one-line diagrams, a resubmitted interconnection application, and a delayed permission-to-operate date -all avoidable with the right groundwork up front.

This is really a subset of a broader landscape here in Texas : solar interconnection rules are set utility by utility, not statewide, and they change. ERCOT governs the grid itself, but Oncor, CenterPoint, Austin Energy, CPS Energy, AEP Texas, and dozens of municipal and cooperative utilities each maintain their own interconnection standards, disconnect requirements, and equipment approvals. A design that clears one utility’s review can bounce back from another’s.

We’ve been navigating these utility-specific requirements across Texas since 2007, which is part of why we treat interconnection as an engineering step, not paperwork to rush through after the equipment is chosen. Knowing in advance whether a given utility allows a meter collar, requires a VLLD, or has its own meter-grouping rules shapes the electrical design, the permit packet, and the project timeline — not just the equipment list.

If you’re planning a residential solar and battery project and want to know what your specific utility will and won’t allow, get in touch and we’ll walk through what applies to your address.

OK. I know many of our readers have been staying tuned in on this topic. So here’s the latest on how state legislators and regulatory agencies are pushing for constraints on how the coming wave of data centers operators (and their enormous expected power demands) will get access to the Texas grid.

On June 10, Governor Abbott directed the Public Utility Commission of Texas (PUC) and ERCOT (the Electric Reliability Council of Texas, which operates the state’s power grid) to keep the cost of data center growth off residential electric bills. On July 24, the two agencies reported back with specifics. Here’s what they actually committed to, what it doesn’t cover, and why on-site power harvesting/generation/stroage remains the one variable homeowners and businesses can control directly. (Governor’s office, June 10 directive; KVIA, July 24 response)

What the State Actually Committed To

Per the PUC and ERCOT’s joint response, the state is moving to:

• Require data centers to fully fund the transmission infrastructure built to serve them, and to contribute toward reducing residential electric bills -not just avoid raising them.
• Adopt rules preventing large data centers from diverting existing power away from residential and small-business customers during periods of grid stress.
• Implement a new interconnection screening process before large loads can connect to the grid.
• Mandate that data centers reduce power draw quickly when ERCOT instructs them to.
• Require data centers to register with the PUC and ERCOT so the state has accurate visibility into electricity and water use.

Both agencies also recommended legislative changes for the next session, including expanding the Lone Star Infrastructure Protection Act to cover large data centers and clarifying PUC/ERCOT authority to set additional reliability requirements. Governor Abbott said he’ll work with lawmakers to codify the protections. (KVIA)   

What This Doesn’t Do

These are regulatory and administrative actions, not law yet -the legislative pieces won’t move until the next session convenes. And the underlying pressure hasn’t gone away: ERCOT is currently tracking more than 438,000 MW of large-load interconnection requests, the vast majority from data centers, a queue NATiVE Solar covered in more detail after ERCOT’s record-breaking demand week earlier this month. Cost-allocation rules can slow how much of that growth lands on residential rates, but they don’t change the fact that Texas electricity demand is climbing faster than in past cycles — a dynamic Austin Energy itself flagged earlier this year. (NATiVE Solar)

Oh, then there’s the Texas energy lobby…we expect them to push back hard.   There’s an industry on the other side of this, and it hasn’t gone quiet. The Data Center Coalition -the sector’s main trade group — responded to the July 24 announcement by saying it “shares” Abbott’s commitment to responsible growth and will “work with” his office, the PUC, ERCOT, and the Legislature. That’s cooperative language, but the coalition has a track record worth noting: during the 2025 fight over SB 6’s cost-allocation rules, it argued that changing terms on data centers would make developers “rethink their investments in Texas,” and said afterward that the final law still didn’t address all its concerns. (KVIA) Separately, some Republican lawmakers are pushing to pause a related $100 billion transmission expansion tied to data center growth until the 2027 session can review it — a sign the fight over pace and cost isn’t settled, even inside the governor’s own party. (KSST Radio) The PUC’s actual rulemaking on cost allocation and curtailment mechanics is still in progress through the rest of 2026 — which is exactly where a well-resourced trade group has the most room to shape outcomes without ever staging public opposition.

Why On-Site Generation Still Matters Here

These rules govern who pays for new infrastructure. They don’t change how much electricity you pull from the grid, or when you pull it. That’s still on you — and it’s the part battery energy storage and solar actually affect, no matter how the cost-allocation fight in Austin plays out, or how the rulemaking ultimately lands.

For commercial and industrial facilities, that’s a demand charge mitigation story: behind-the-meter generation cutting exposure during peak-draw periods, especially for manufacturers, healthcare facilities, and other high-electricity-cost operations that feel rate volatility first. For homeowners, it’s energy resilience — less dependence on a grid now carrying an entirely new category of industrial load on top of everyday household demand.

None of this is a guarantee against rising rates; how much a given system reduces exposure depends on load profile, system sizing, and how a project is designed and dispatched. But it’s a lever you control directly, on a timeline you set — which is more than can be said for the outcome of next session’s legislative fights.

NATiVE Solar’s Perspective

We’ve watched this exact dynamic play out before: policy responds to a stressor after the stressor is already visible in the data. That’s not a criticism of the state’s approach here — fully funding data center infrastructure and requiring fast curtailment are genuinely useful tools. But we design systems for the property owners who’d rather not wait to find out how a future legislative session resolves cost allocation on a grid serving an entirely new category of industrial customer. Fifteen-plus years of working inside ERCOT’s interconnection and rate structures is what lets us size a system around your actual exposure, not a headline.

If you want to understand what rising data center-driven demand means for your specific facility or home, talk with our team about a system built for the Texas grid as it actually exists — not as the next legislative session might reshape it.