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.

Buckle up, folks. Texas set a new all-time electricity demand record this week. Then it broke that record again the next day. Here’s what actually happened, why the grid held without issuing conservation alerts, and what it signals for anyone consuming energy from the Texas grid this summer.

What Happened

As temperatures across the state pushed well past 100°F, ERCOT recorded 87,403 megawatts (MW) of demand on Tuesday, July 21. This surpassed the previous all-time record of 85,508 MW set during the August 2023 heat wave. And then on Wednesday, demand climbed again to 91,308 MW, a new record less than 24 hours after the last one fell!  Yikes.

We should note here that both figures are preliminary, and ERCOT did not issue a conservation appeal or declare an emergency at any point. That last detail is arguably the more interesting point and we’re hopeful that ERCOT can stay ahead of the coming energy demands that are being forecasted for our state (think datacenters here). There’s a bit more detail below.

The Numbers Behind the Numbers

A few other records fell alongside peak demand:

• Maximum net load: 75,733 MW
• Maximum battery discharge: roughly 11,980 MW -nearly 12 gigawatts pulled from energy storage at once
• Maximum solar production: 34,665 MW

The battery discharge number is hugely relevant. Two years ago, when ERCOT hit its prior 5-minute demand peak, the state had about 4,000 MW of batteries online. This week it was nearly 12,000 MW. So, this was roughly a 3x increase in two years. ERCOT grid data shows solar carrying the bulk of daytime load while batteries stepped in to shave the late-afternoon/evening peak, which is pretty much the textbook use case that battery energy storage was built for.  It’s so cool (for this guy, anyway) to see this working at-scale when the grid gets squeezed.

Why the Grid Held

We have started seeing massive investment in our grid infrastructure. Texas has aggressively added grid-scale solar and storage capacity since the 2021 Winter Storm Uri failure exposed how much the grid needed both. Per the Solar Energy Industries Association, the state now has roughly 53,568 MW of installed solar capacity and 29,163 MWh of storage capacity, with projected growth of another 39,053 MW over the next five years. Texas is currently the fastest-growing state for solar and storage deployment.

That buildout is a big part of why ERCOT’s own risk modeling has stayed low so far this summer -it put the odds of a grid-wide emergency at 0.09% in June and 0.21% in July, though that risk rises to roughly 6% in August and 4% in September as the hottest stretch of summer continues.

The bigger long-term variable isn’t heat -it’s load growth based on datacenters, industrial parks, and large residential projects in the works. ERCOT is currently tracking more than 438,000 MW of large-load interconnection requests, nearly 89% of it from data centers. The Public Utility Commission of Texas recently approved ERCOT’s new “Batch Zero” process to study these requests in groups rather than one at a time, specifically so large users connect “in quantities and locations the Texas grid can reliably support.”  This adds more risk. It also almost surely means that electricity prices for both commercial and residential subscribers are going to climb as ERCOT and the electric utilities across Texas try to keep building out enough grid capacity to keep up with demand.

What This Means If You’re on the Texas Grid

For commercial and industrial facilities, records like this one are a telling preview of what’s going to drive demand during peak events.  ALso, we can clearly see the kind of exposure that demand charge mitigation strategies are designed to soften. “Behind-the-meter” solar and battery energy storage can help reduce a facility’s exposure to peak-driven costs and grid stress, particularly for manufacturers, healthcare facilities, and other high-electricity-cost operations where a few peak-demand days can disproportionately affect the annual energy bill. (NATiVE Solar can help commercial and institutional operators with this aspect of their energy spend)

This week has also been a real-world demonstration of what battery storage is actually for: shifting load away from pollution-emitting power plants during the hours when the grid is under the most strain. As ERCOT continues to lean harder on distributed batteries and virtual power plant programs to manage peak events like this one, the value of having storage on your own property  -rather than relying solely on the grid to hold- keeps growing.

Texas isn’t going to get less hot, and based on the data center queue alone, the grid isn’t going to get less loaded. Records like this week’s are likely to become a summertime pattern. If you want to understand what that means for your facility or home specifically, talk with our team about a system sized and spec’d for the (still very fragile) Texas grid.

Thanks for reading, Ya’ll!

**For reference, dear readers, I just built a little tool that shows the real-time ERCOT stats.

(Here’s the ERCOT grid status panel on their website : https://www.ercot.com/gridmktinfo/dashboards )

Sources

• As Texas temperatures soar, ERCOT crushes demand and generation records without incident — Renewable Energy World / Factor This, July 23, 2026
• Texas Heat to Challenge State Grid’s Power Demand Record — Bloomberg
• ERCOT grid hits 90,000 MW of demand amid extreme heat — Community Impact
• ERCOT prepares for record demand during Texas heat wave — Houston Public Media

Amid continued strong momentum in Texas for the embrace (despite political and supply-chain headwinds) of solar and renewable energy, Austin Energy (AE) is in the middle of its own solar buildout. The city is currently in the process of installing solar energy harvesting capability on more than 90 City of Austin buildings -and 30+ MW-AC of new capacity. At the same time, incentive programs for solar capacity for commercial customers are filling up -Austin Energy’s own program data from June 2026 shows several incentive tiers already 44–50% subscribed. As the city just announced increased incentives and options, I wanted to post a rundown of what’s currently available to commercial and nonprofit customers -and what the capacity numbers mean for timing.

Two incentive paths: businesses choose one

Austin Energy offers commercial and nonprofit customers a choice between two solar incentives -you can’t take both. A Performance-Based Incentive (PBI) pays out over time as production occurs; a Capacity-Based Incentive (CBI) pays out once, based on system size. Eligibility across both programs is based on converted kW-AC

Third-party Power Purchase Agreements (PPAs) are not eligible anywhere in Austin Energy’s service territory, for either program.

Capacity-Based Incentive (CBI): a one-time payment

CBI pays a flat rate per watt of installed capacity, issued as a single check after the system passes final inspection and is energized. Current published rates:

• Nonprofits, any system size: 70¢ per Watt-DC, with the total incentive capped at $168,675 per project. [REVIEW: financial claim — qualify as “eligible nonprofit projects may receive up to…”]
• Businesses with systems 100 kW or smaller: 50¢ per Watt-DC, capped at $60,240 per project. [REVIEW: financial claim]

For a modestly sized commercial solar array of 250kW-AC, this would mean the city would cut a check to the property owner for $168,675 -which is the CBI hard cap for nonprofits. -Not a small short-term recovery of value. This can be a desirable option for system sizes into the 200-250kW range for 501(c)(3) public interest organizations.

Performance-Based Incentive (PBI): a five-year bill credit

The other option is to take the PBI incentive. PBI pays out monthly, as a bill credit (or a check, if requested), calculated by multiplying that month’s production by the applicable rate. The rebate runs for five years and requires one application per interconnection point. As of July 2026, the incentives are based on the following scale:

• Nonprofit tiers: under 400 kW, 8¢/kWh; 400–999 kW, 6¢/kWh; over 1 MW, 4¢/kWh
• Business tiers: under 100 kW, 8¢/kWh; 200–999 kW, 6¢/kWh; over 1 MW, 4¢/kWh

Larger commercial projects (over 1 MW) also need to comply with Section D of Austin Energy’s Distribution Interconnection Guide, which is worth flagging early to a facilities or engineering team rather than discovering it mid-application. (We here at NATiVE don’t gloss over the small details. We design and build strictly to code -from the beginning!)

Good so far?  Ok now stay with me folks.

Value of Solar (VoS): the credit every system earns, regardless of which incentive you pick

  On top of whichever incentive a business selects, all commercial solar production earns a separate monthly bill credit under Austin Energy’s Value of Solar (VoS) rate: currently 9.91 cents/kWh for systems under 1 MW-AC, and 7.24 cents/kWh for systems 1 MW-AC and larger as of July ’26.  Solar energy production and site consumption are metered at the site separately. A business is billed for everything it draws from the grid, then credited for 100% of what its system produces. Unused credit rolls forward month to month, though it isn’t transferable between accounts. (*This is the same basic math that happens for residential solar subscribers on their monthly bill, BTW)

A real project, for scale: Austin Energy’s own published case study on the Mothers’ Milk Bank at Austin describes a 269 kW system (656 panels) that received a CBI payment of $268,960 at a the $1.00-per-watt rate that was in effect at the time of that installation. (The current CBI plan now pays out @ 70¢/W nonprofit rate.) The facility also reported average monthly VoS credits of roughly $2,900, covering close to 98% of its electricity costs. It’s a useful illustration of how the incentive stack works in practice, and a good reminder that rates move over time.

An option that requires no capital outlay: the Solar Standard Offer Program

For commercial property owners with a large roof or parking lot who don’t want to own or finance a system themselves, Austin Energy’s Solar Standard Offer Program offers a different structure: host a Community Solar project -either self-owned or leased to a third-party System Owner- and the system owner gets paid for some of the electricity generated on their land.

Eligible system sizes run from 50 kW-AC to 10 MW-AC. In this plan, the system owners are paid a cash rate (not a bill credit) currently set at 11.24 cents/kWh for systems under 1 MW, and 8.41 cents/kWh for larger systems (*this rate was set in January 2025 and is next scheduled to update in November 2026). As of April 2, 2026, qualifying projects can also receive a Guaranteed Minimum Price incentive of $0.11/kWh (under 1 MW-AC) or $0.08/kWh (1 MW-AC and up), applied as needed over the first 10 years of production. There’s no utility bill impact to the property owner hosting the system -they get a monthly check for the energy produced by the system being hosted at their site. This can become a really nice cash-on-hand offset for the company’s ops spend. It’s a structure most commercial property owners haven’t encountered before, and worth a closer look if capital outlay is the main obstacle to going solar.

Why timing matters right now

Austin Energy’s incentive programs draw from a limited, first-come-first-served pool of funding. Per the utility’s own June 2026 contractor update, current subscription levels stood at roughly 50% for PBI Tier 2, 44% for CBI Tier 4, and 50% for the Standard Offer Program. There’s still time, but the mechanics of the process matter more than usual at this stage: Austin Energy won’t approve a project without a signed contract and an approved Distributed Generation Planning Application (DGPA), installation can’t legally begin before the customer and contractor receive a Letter of Intent or Letter of Approval, and if a project’s scope grows after that letter is issued, the incentive amount does not increase. Accurate system sizing before submitting the paperwork is the difference between capturing the intended incentive tier and leaving money on the table. Reputable commercial solar firms like NATiVE will work with you and your leadership team to navigate the administrative red tape, as well as handle all permitting, inspections, etc. with the city.

Whew. OK. We know it’s a lot to consider. Take a breather….

So here’s how the process actually works in a nutshell :

1. Decide between PBI, CBI, or the Standard Offer Program. Your Ops and Controller’s office will need to run the numbers. We (NATiVE) can help validate the analysis.
2. Work with an Austin Energy participating contractor and get multiple bids.
3. The contractor submits the application and a Customer Agreement Form on your behalf.
4. Austin Energy issues an Encumbrance Letter if the project is eligible, then requests supporting documentation (DGPA, interconnection agreement).
5. Once fully approved, Austin Energy issues a Letter of Intent or Letter of Approval -installation cannot begin before this step.
6. The contractor handles permitting, installation, and coordinates Austin Energy’s final inspection.
7. Once energized, PBI credits begin appearing on the monthly bill; CBI payments are mailed as a check.

How NATiVE Solar approaches commercial projects

NATiVE Solar treats commercial solar projects as systems engineering and balance sheet challenges delivered as long-term energy infrastructure, not incentive-chasing exercises. That means sizing a system against a facility’s actual (and projected) load profile and demand charge structure first, then layering Austin Energy’s PBI, CBI, or Standard Offer incentives on top of a design that already makes sense for the building and business needs. For facilities managing high or volatile demand charges, pairing solar with battery energy storage can support a demand charge mitigation strategy -though outcomes depend on load patterns, utility rate structure, and system design -it’s not a fixed formula or one-size-fits-all process. NATiVE has been designing, building, and maintaining commercial-scale systems in Texas since 2007, which means navigating ERCOT interconnection requirements, AHJ permitting, and Austin Energy’s DGPA process is a known quantity and our permitting team is razor-sharp at getting paper and approvals pushed through the system. For more on where the Texas commercial market is headed, see NATiVE’s 2025 commercial solar and storage overview. It’s still pretty much up to date.

If your facility is evaluating solar or battery storage under Austin Energy’s current incentive structure, get started with a conversation about your specific site and load profile.

Sources:

1. Incentives for Solar Systems Available for Your Business — austinenergy.com
2. Value of Solar (VoS) Rate, commercial — austinenergy.com
3. Solar Standard Offer Program — austinenergy.com
4. Austin Energy Solar Contractor Administrative Meeting slide deck, June 18, 2026 (Customer Renewable Solutions)
5. Mothers’ Milk Bank at Austin case study, published on austinenergy.com’s commercial solar page

Austin Energy Residential Solar Incentives, Explained (Summer 2026 Update)\

Austin Energy is actively expanding its residential energy programs in 2026 — a new 40 MW battery capacity agreement with Base Power (announced May 19, 2026) and updates from AE’s June 18, 2026 solar contractor meeting both signal more (and better!!) homeowner options. Here we’re going to break down the current solar rebate, VoS monthly credit, and the new battery energy storage incentives Austin Energy residential rate payers.

The Austin Energy Residential Solar Rebate

For the past few years, Austin Energy (“AE”) has offered a $2500 rebate check for eligible new home solar installations (system-owned, not leased/PPA). But starting this month, they have raised the incentive to $4000. This is a pretty sizeable increase and moves the numbers for system ROI and payoff timelines.  Here’s the deets:

• Eligibility: system must be 3 kW-DC or larger, mostly free of shading, installed by an Austin Energy participating contractor (that’s us!), and the rebate confirmation letter must be issued before installation begins. *You will need to send AE a copy of the system design specs and performance projections we provide as a part of our process*
• Third-party Power Purchase Agreements (PPAs) are not allowed in Austin Energy’s service territory -only customer-owned or loan/lease-financed systems qualify.
• Process: Solar Rebate Quiz → rebate reference number → hire participating contractor → confirmation letter → install → inspection/PTO → QA review → rebate check mailed.

*Source: Rebates for Home Solar Systems, austinenergy.com  reviewed 07/07/2026)

Value of Solar (VoS): How the Bill Credit Works

Austin Energy credits residential solar production at 9.91 cents per kWh for systems under 1 MW-AC (effectively all residential systems)  -the rate has been in effect since March 2023, up from the previous 9.7 cents per kWh. Not a huge jump, but it’s not nothing. :) The next update is expected November 2026.

As everybody is expecting electricity costs (monthly bills) to increase (perhaps dramatically) over the next few years, we are expecting the VoS rate to likewise increase -but nobody is making bets on this quite yet.

Here’s a refresher on how residential VoS credits from Austin Energy work out on the monthly utility bill:

• Solar production and home consumption are metered separately; customers are billed for all consumption,
• then credited 100% of production at the VoS rate; unused credits roll month-to-month but reset each December billing cycle.

This isn’t nearly the deal that early solar adopters got with 1:1 “net metering,” which placed the same value on your solar-generated energy as the energy you got from the grid. It was a great deal. But those days are long gone. Still, the VoS credit provides a great incentive to go solar and save a ton on your energy costs over time.

Here’s the direct link if you feel the need to dig in to this a bit more : Value of Solar (VoS) Rates, austinenergy.com

Austin Energy’s “Power Partner” Battery Pilot Program

For those who install (or have already installed) battery backup with their solar system, AE’s Power Partner program can provide you with a sizeable return over time. The tradeoff here is that with enrolment into the program, you agree to let AE discharge some of your batteries’ stored energy back to the grid when it’s needed. (This helps reduce grid and power plant stress at peak consumption times.) The agreement in writing is that they cannot discharge your battery below 20%, and can’t touch it before or during severe storm events.  This is a type of VPP (virtual power plant) offering not terribly different in function than the others we’ve written about here recently 

So here’s how it works :

• The battery incentive pays $500 upfront per qualifying battery system (system must have received Permission to Operate on or after 2/18/25),
• plus an annual performance payment of roughly $75/kW of average demand reduction.  (AE’s own worked example (a single Tesla Powerwall, 13.5 kWh battery capacity, 20% reserve) nets ~$324/year.

• Eligible battery brands today: Tesla, FranklinWH, SolarEdge (Generac and Enphase listed as “coming soon” as of the June 2026 update).
• Enrollment cap: 1,500 customers program-wide; roughly 125 enrolled as of June 2026.

And here are some of the rules :

• no Third-Party-Owned/leased battery systems currently eligible; dispatch events run 2–3 hours, capped at 40/year (mostly hot summer afternoons),
• Reserve capacity (~20%) is maintained, no events during major storms, and customers can opt out per-event or unenroll entirely without penalty.*Note* VoS bill credits as discussed in the previous paragraph are unaffected by Power Partner enrollment -Austin Energy still credits 100% of solar production regardless of whether that energy charges a battery, powers the home, or is exported.

Source: Austin Energy Solar Contractor Administrative Meeting, June 18, 2026 (Customer Renewable Solutions), slides 14–19; corroborated by austinenergy.com/green-power/solar-solutions/for-your-home battery-backup section.

A Second, Unrelated Battery Option: Base Power

Base Power is a private company headquartered here in Austin (at the old Austin-Stateman building across the river from downtown) offering its own battery lease program. They have an interesting business model: they manufacture and deploy home battery systems, then monetize them two ways -as a retail electric provider (REP) selling battery-backed power plans directly to consumers, and as a grid-services partner selling dispatchable battery capacity to utilities. In practice, they basically become your sole electric utility company after installation of their battery backup system.

Consumer offering: Customers can lease a Base-owned 20 kWh battery system rather than buying one outright. They charge roughly $695 install + $19/mo for one unit, or $995 + $29/mo for two, on a 3-year contract (per Austin Energy’s June 2026 contractor deck; Base sets its own current pricing at basepowercompany.com/pricing). Base also now sells a “battery-free” retail electricity plan in some territories. These are pretty big batteries, designed for “whole home” backup (depending, I guess, on your monthly electrical usage).  Just like other VPP offerings, they may discharge part of your battery back to the grid when utilities hit peak loads.

Utility partnerships (the other half of the business): Base contracts with utilities across Texas for grid capacity -the utility pays Base to keep a fleet of customer-sited batteries charged and dispatchable during peak demand, independent of what Base charges the homeowner. Deals so far:

• Austin Energy: 40 MW / ~2,000 homes, announced May 2026, targeting completion by end of 2027
• CoServ (Denton Co-op, North Texas): 100 MW, Base’s largest deal to date
• Guadalupe Valley Electric Cooperative (South Texas): 50 MW, announced April 2026
• El Paso Electric: pilot program, first install completed March 2026

*note* The Base Power program is not affiliated with Austin Energy’s Power Partner program and is currently ineligible for Power Partner incentives, which I wrote about earlier in this article.

Source: Austin Energy Solar Contractor Administrative Meeting, June 18, 2026, slides 8 and 18; and https://austinenergy.com/about/news/news-releases/2026/Austin-Energy-expands-local-battery-storage-to-support-reliable-affordable-power

Don’t Forget that Property Tax Exemption

This isn’t an Austin Energy thing, but the State of Texas offers a property tax exemption for on-site renewable energy systems (solar), which may apply to qualifying home solar installations.

We here at NATiVE don’t offer tax advice, but for those interested in this potential incentive, please visit or contact the Texas Comptroller.

Source: Texas Comptroller — Property Tax Exemptions

Choosing a Contractor

Here’s a bit more info worth mentioning -Only Austin Energy participating contractors (shameless plug for NATiVE Solar here) can be used for installation of solar/battery systems eligible for  AE’s rebates/incentives; customers can use a non-participating installer but forfeit rebate eligibility. Please don’t do that.  :)

Our Perspective

The majority of our residential clients are now choosing to add battery backup storage to their new (or existing!!) solar installation. The benefits are clear.

Yes, adding batteries can push the system price up considerably. No, batteries may not “pay for themselves” over time in the way solar panels do. But with a properly designed solar+battery infrastructure for your property, and new incentive options, you can reap the benefits and peace of mind that comes with on-site energy storage while putting a few bucks back in your pocket.

If you have questions about residential battery energy storage -or any solar-related matter- we’d love to be a local resource for helping to explore the options. Get in touch and let’s have a chat about it.

As this past week’s rain has nicely topped the little pond on my property, it (ironically) reminded me of something I’ve been thinking about more and more: Texas is apparently running out of fresh water faster than most people realize. The more one digs in to this topic, the dire implications become clear. The combination of declining supplies, population growth, infrastructure failures, and industrial demand is sucking down fresh water much more quickly than nature can overcome by itself.

Wars have been fought over access to fresh water. But I’m not going to go there for this blog entry. We also aren’t going to delve into the politics of water scarcity in Texas. It’s a whole other thing… Maybe i’ll write about this in future articles, but for now i’ll let you, dear reader,  do the research if you’re interested.

Here, we wanted to look at this issue from the solar angle -and talk a little bit about the increasingly solar-related tools that could help to slow the alarming trend of water scarcity here in our beloved state.

Lake Corpus Christi is currently sitting at just over 16% of capacity. Choke Canyon Reservoir is below 8%. Medina Lake fell to 2.5% during the 2025 drought. The Edwards Aquifer -which supplies drinking water for roughly 2.5 million Texans (including this human)- hit historic in 2025, triggering Stage 5 (the most severe) water restrictions in San Antonio and surrounding areas. These are symptoms of a kind of structural mismatch between water supply and demand that Texas has quite apparently been slow to address.

According to the Texas Tribune, if a severe drought were to occur in 2030, the state could face a shortfall of 4.7 million acre-feet of fresh water -more than 20% of projected demand. The Texas 2036 initiative estimates that without a diversified supply strategy, the economic impact of prolonged drought could reach $160 billion annually by 2030. And groundwater, which currently accounts for 54% of Texas’s total water supply, is projected to decline 32% by 2070.

Solar power won’t solve this alone. But it’s increasingly central to the technologies that can. So here we go…

The Water-Energy Problem Is Circular

Here’s the part most people don’t connect: water and energy are deeply interdependent. Conventional power generation -coal, natural gas, nuclear- requires enormous volumes of water for cooling. Meanwhile, moving, treating, and distributing water consumes significant electricity. The two systems stress each other. Yes, some of the water used for power generation is “reclaimed” – but not all. And merely reclaiming the water for other uses doesn’t address the supply issue -it doesn’t replenish water at the source.

Solar photovoltaic generation breaks that cycle. It produces electricity without water consumption. As Texas adds more solar to its grid (Texas is on track to generate more electricity from solar than coal in 2026 for the first time_) the grid’s overall water use intensity decreases. That’s a real, if indirect, contribution to water conservation.

But solar’s direct role in addressing scarcity is growing too.

Solar Desalination: Viable and Scaling

Texas sits atop enormous brackish groundwater reserves -this is water that’s too salty to drink or irrigate with without treatment. Desalination has long been the obvious answer. The problem is that traditional desalination is energy-intensive and expensive to run on grid power, especially when that grid power comes from fossil fuels.

Solar-powered desalination changes the economics. Two primary emergent technologies are relevant here:

Photovoltaic-powered reverse osmosis (PV-RO): Solar panels generate electricity that drives reverse osmosis membranes. The systems can be scaled from small community installations to utility-scale operations. Research published recently identified areas such as West Texas as a particularly strong candidate for this approach -the combination of abundant sunlight, shallow brackish aquifers, and limited freshwater supply makes it a natural fit. AI-enhanced optimization and new materials science further strengthens the viability of the approach here.

Solar-thermal distillation: Concentrated sunlight generates heat that drives evaporation-based desalination. This approach is more energy-efficient in high-solar-radiation environments and produces no carbon emissions in operation. Both commercial and academic inertia in this direction haven’t slowed much in 2026.

Neither technology is purely experimental at this point. Texas already operates desalination capacity at several municipal facilities -the economics are largely being worked out. Now the question is scale and speed of deployment.

Floating Solar on Texas Reservoirs

One really cool emerging intersection of the solar and water crises that i think deserves more attention: floating solar on Texas reservoirs, water treatment facilities, and irrigation ponds.

Texas reservoirs and water infrastructure represent a significant opportunity for floating solar installations. Beyond generating electricity, floating solar panels reduce water evaporation from reservoir surfaces. The panels shade the surface, reduce algae growth, and produce power simultaneously. Here’s a really good article that covers the details and benefits of floating solar in Texas (and in general).

This isn’t a distant concept. Floating solar deployments are already operating at municipal water facilities in other states and internationally. For Texas reservoir managers navigating both water stress and energy costs, the economics are worth a hard look. Here’s a link to an article detailing an enormous “floating solar” project planned for Port Arthur: https://cleantechnica.com/2025/11/17/a-texas-sized-391-megawatt-floating-solar-power-plant-is-coming-to-texas-of-course/ 

Solar-Powered Irrigation: Measurable Results

Here’s a fact: agriculture accounts for roughly 60% of Texas water consumption. Irrigation practices (many of them decades-old) are a major driver of groundwater depletion in the Panhandle and South Texas. Hard, real-world test data collected and analyzed recently show that solar-powered irrigation systems will reduce energy costs while they enable smarter, more efficient water use. A 2025 research study found that solar-powered smart irrigation systems reduced overall water use by 16–25% and energy consumption by 30–40% compared to conventional irrigation, with some implementations cutting greenhouse gas emissions by more than 57%. (https://pmc.ncbi.nlm.nih.gov/articles/PMC11973206/)

The mechanism is straightforward: solar-powered pumps with variable-speed drives and real-time soil moisture sensors can deliver water precisely when and where crops need it, rather than running on fixed schedules. Off-grid capability matters especially in remote agricultural areas where grid access is limited or expensive.

For Texas farmers managing both energy costs and water rights, solar-powered irrigation represents one of the most practical near-term investments available.

*side note* Here’s an overview published by GVEC (the electric utility) showing how solar is impacting Texas agriculture more broadly
*another side note*

Smart Monitoring and Leak Detection

Texas loses an estimated 88 billion gallons of water annually through aging and broken infrastructure. Ouch. Solar-powered remote monitoring systems -sensors, flow meters, pressure monitors- can identify leaks and anomalies in real time across water distribution networks, without requiring grid connectivity in remote areas. This makes obvious sense, yeah?

This isn’t glamorous technology, but the impact is significant enough to mention. Municipal water systems that deploy solar-powered IoT (“Internet of Things”) monitoring consistently report faster leak detection response times and measurable reductions in non-revenue water loss. (source)

The Commercial Opportunity

For Texas businesses, the water-solar connection shows up in practical ways.

Facilities with high process water use  -food and beverage manufacturers, data centers, industrial laundries, agricultural operations- are already dealing with rising water costs alongside rising energy costs. Solar + storage systems can reduce electricity bills and, in some configurations, support water heating, treatment, and pumping operations. Commercial solar and battery energy storage installations at agricultural, municipal, and industrial facilities in Texas are increasingly being designed with water system integration in mind.

Water utilities themselves are among the most natural candidates for solar. Treatment facilities run 24/7, have large flat roofs or adjacent land, face predictable demand curves, and are often municipal entities with access to favorable financing. The ability to offset energy costs with battery energy storage while maintaining operational continuity during grid stress events seems particularly relevant in a state like ours where the grid and the climate are both increasingly unpredictable.

NATiVE’s Perspective

We’ve been installing solar (and battery energy storage systems!) in Texas since 2007, through droughts, grid failures, and everything in between. The water-energy connection isn’t abstract for us. It’s on the RADAR.

And from here, it looks like Texas’s water crisis isn’t going away. If anything, the 2025 drought data suggests the projections from state water planners were optimistic. Solar power isn’t a single solution -but it can be an increasingly capable tool in the mix, and in several applications, it’s a largely practical, proven, and cost-effective paving stone into the future.

The projects that make the most sense aren’t always the ones with the cleanest payback math. Sometimes the value of energy resilience and reduced exposure to volatile input costs -water included- is a bit harder to quantify -but it’s also a very real aspect for us to think about. If you’re managing a facility where water and energy costs are both material, it’s worth a conversation about what solar and storage could look like for your operation.

Talk to our team to get started.

More Sources we referenced for this piece:

• Texas Tribune: What to know about Texas’ looming water crisis
• Drought.gov: Drought in 2025
• Dallas Fed: Shoring up water supply, curbing demand key to Texas’ future growth
• Texas Water Journal: Floating Solar at the Energy-Water Nexus
• 8MSolar: Irrigation Systems and Solar Panels (2026)

Perhaps nobody will get slammed again this Spring/Summer season. But the statistical odds are against that notion. More folks in Texas will almost certainly encounter an extreme weather event with roof-damaging potential at their solar-equipped property. Dang.

The robot gave me the following odds based on published weather and insurance claim data/statistics:

• A Texas homeowner has roughly a 1-in-20 to 1-in-35 chance of filing any weather-related roof claim in a given year (the Texas rate is higher than the 1-in-36 national average because Texas leads the country in hail claims)
• Over a 20-year asphalt shingle roof lifespan, the cumulative probability of at least one damaging hail/wind event is somewhere around 45–65%
• Over 30 years (the rated lifespan of most common shingle products), you’re approaching 60–80%

Between April 24 and April 29, 2026, North and Central Texas experienced six consecutive days of severe thunderstorms. The NWS (National Weather Service) Fort Worth office recorded 287 reports of hail, wind damage, flooding, and tornadoes. Two people were killed. At least 11 were injured. Five confirmed tornadoes touched down -including an EF-3 near Mineral Wells that destroyed warehouses and damaged homes across a two-to-three-mile path.

For some property owners across DFW, Parker County, Tarrant County, Rockwall, Hunt County, and points south toward Waco, the aftermath means roof inspections, insurance claims, and decisions about what comes next.

If your property has solar panels -or if you’ve been thinking about adding them- this recent weather event reflects some important insights i felt it was important to share here, dear readers.

What Happened: Six Days of Severe Weather Across North Texas

The outbreak began Friday, April 24, with supercell thunderstorms pushing southeast out of Oklahoma into Northeast Texas. By Saturday the 25th, destructive storms had moved across the DFW Metroplex producing tornadoes, large hail, and straight-line wind gusts up to 89 mph near Springtown. This was basically equivalent to a Category 1 hurricane + big chunks of ice flying around.

Monday, April 27, brought another round. Supercells developed across the middle of the Metroplex during the afternoon, then tracked eastward through the evening. Hail up to teacup size was reported in northeast Dallas, Rockwall, and Hunt Counties. Oh man.

Tuesday, April 28, was the most intense day. Supercells again developed near Wichita Falls and moved southeast across North Texas. An EF-3 tornado struck Mineral Wells, injuring five people and severely damaging a wide swath of the city. Hail up to softball size -about 4 inches in diameter- fell across North Texas. Reports of 3-inch hailstones came in from as close as Mountain Creek Lake, between Grand Prairie and Cockrell Hill.

Across the six-day event, NWS Fort Worth issued 111 warnings for tornadoes, severe thunderstorms, and flash flooding. Even just based on our own internal data (NATiVE’s service teams are busy!), many homeowners are now scrambling to fix their damaged and leaking roofs. *Read-on to get to the solar panel stuff*

What This Means for Your Roof

Hail at 1 inch and above can damage asphalt shingles. At 2 inches and above (roughly egg-to-tennis-ballish size), damage to shingles, flashing, vents, and gutters is highly likely. At softball size, structural damage to decking and underlayment becomes a real concern. Some solar panels will likely meet their end in an event like this. :(  (It’s a good thing most folks are unlikely to ever witness this size of hail in their neighborhood.)

The April 2026 event produced 226 reports (to the NWS) of large hail across six days. If your property is located anywhere in the affected zone (and particularly in the western half of Fort Worth Parker County, Palo Pinto County, Rockwall, or Hunt County) you should have your roof professionally inspected, even if you don’t see obvious damage from the ground.

*Hail damage isn’t always visible to the untrained eye, ya’ll. Shingle bruising, micro-fractures, granule loss, and compromised flashing can all reduce your roof’s remaining service life without being obvious from street level.*

If You Already Have Solar Panels

Here’s the good news: tier-1 solar panels are tested to withstand hail impact up to 1-inch diameter stones at roughly 50 mph. In most hail events -even significant ones- the panels themselves survive while the surrounding shingles take the damage.

That said, solar panels aren’t invulnerable. At softball size and above, panel damage is possible (perhaps likely). And even when the panels are fine, if your roof underneath needs to be replaced, the panels have to come off first.

This is where “Detach and Reinstall” (“D&R”) comes into play.

What Is Solar D&R?

D&R -sometimes called “R&R” for “removal and reattach”- is the process of safely removing an existing solar array from a roof so that roofing work can be completed, then reinstalling the system once the new roof is in place. It’s a standard procedure that solar companies perform regularly, especially in hail-prone regions like North Texas.

A proper R&R involves:

Removal phase: Documenting and Disconnecting the system from the electrical service panel (aka breaker panel), carefully removing panels and racking hardware, and storing components safely on-site. Solar-related junction boxes and conduit typically remain in place.

Roofing phase: Your roofing contractor replaces the damaged roof with full access to the deck -no panels in the way. New flashing is installed at all mounting points during reinstallation.

Reinstall phase: Panels and racking are carefully remounted to the new roof, wiring is reconnected, and the system is tested and recommissioned to confirm it’s generating at its original design capacity.

The whole D&R process typically adds 1 to 3 days to the reroofing timeline. (Larger commercial systems installed over asphalt shingles (this is rare) may take proportionally longer depending on roof/array size and complexity.)

Insurance Coverage for D&R

If your roof replacement is the result of a covered insurance claim -which hail and wind damage typically are under Texas homeowners policies- the cost of solar D&R is often -but not always- a billable line item on the claim. *Assuming you had hail and wind damage covered and explicitly added the installed solar installation to your insurance coverage plan, your insurance should cover the labor and materials required D&R  as part of the roof replacement scope.

A few things to be aware of:

Wind/hail deductibles in Texas can be high. Many Texas homeowners policies now carry a 1% or 2% wind/hail deductible, which is calculated against the insured dwelling value -not the repair cost. On a $400,000 home, a 2% deductible is $8,000. Make sure you understand your deductible structure before filing.

Not all policies explicitly cover D&R parts and labor. Some policies include “detach and reset” as part of the roof claim scope; others don’t address it. Review your policy language or ask your agent specifically about solar panel removal coverage.

Document everything. Before your roofer or solar company touches anything, photograph the roof, the panels, and any visible damage. If your system has monitoring (Enphase, SolarEdge, Tesla, etc.), pull production data showing output before and after the storm this can support your claim if the insurer questions whether the panels were functioning properly.

Texas homeowners have the right to choose their own contractor. Your insurance company may recommend vendors, but you are not required to use them -for roofing or for solar R&R.

If You Don’t Have Solar Yet -Here’s Why a Roof Replacement Is the Right Time

If you’re getting a new roof anyway, this is the single best time to add solar. Here’s why.

Your roof is brand new. Solar panels have a productive lifespan of 25+ years. Installing on a new roof means you probably won’t ever need to remove and reinstall the system for a mid-life reroof -the timelines align. Installing solar on a roof with only a few years of remaining expected life is one of the most common and costly mistakes homeowners and property managers make. We’re here to give you the straight dope, folks -not a manufactured rush to sell you a system. :)

What to Do Now

If your roof was in the storm path and you have solar: Get a professional roof inspection. If your roof needs replacement, contact your solar company (or contact NATiVE Solar) to coordinate the R&R before roofing work begins. Do not let a roofing contractor attempt to work around your panels or remove them without an experienced and qualified (licenced and insured) solar solutions firm involved.  Improper handling can void warranties, damage components, and otherwise risk full solar system restoration.

If your roof was in the storm path and you don’t have solar: Get the roof inspected and file your claim. Then, perhaps, consider whether this might be the right time to add solar to the new roof. A fresh roof, already being paid for by insurance, is the ideal foundation for a 25+year solar investment.  :) (ok that’s our sales pitch for today)

If you have solar and aren’t sure whether your panels were damaged: Check your monitoring dashboard. A sudden drop in production following the storm dates (April 24–29) may indicate panel-level damage. If you see reduced output, contact your solar provider for a site inspection. For NATiVE Solar customers (or well, any solar property owner, really,) reach out to our service team directly.

The NATiVE Solar Perspective

We’ve been installing and servicing solar in Texas since 2007. We know hail happens sometimes -and it’s a discussion that needs to be had. It’s part of the operating environment here, and we design and specify equipment accordingly. We only install teir-1 PV (photovoltaic) panels tested for high wind and hail impact, and we’ve performed D&R work ranging from small residential arrays to large commercial rooftop systems. Our techs know this terrain intimately and commonly work in conjunction with roofing contractors to help ensure quick completion of the entire project .

If you’re navigating a roof claim or weighing your options after the storms, we’re here to help -whether that’s coordinating an R&R, designing a new system for a freshly replaced roof, or connecting your roofing contractor with our partner program.

Start a conversation with our team →

Dear Readers – Your own insurance coverage, claims processes, and policy terms vary. This article is for informational purposes and does not constitute insurance advice. Review your specific policy or consult your insurance agent for guidance on your coverage. Please and Thanks, folks.

The Section 48E Investment Tax Credit for commercial solar projects has a hard construction-start deadline of July 4, 2026. With less than 60 days remaining, commercial property owners in Texas who have been evaluating solar need to understand exactly what’s required -and what changes for new solar projects in-flight if the deadline passes.

What Happened: The One Big Beautiful Bill Act Changed the Timeline

The Inflation Reduction Act (enacted August, 2022) originally extended clean energy tax credits through 2032. The One Big Beautiful Bill Act (OBBBA), signed into law on July 4, 2025, accelerated that timeline dramatically for solar and wind.

Under the new rules, Section 48E -the “ITC” or Investment Tax Credit- is no longer available for solar or wind facilities placed in service after December 31, 2027, unless construction begins on or before July 4, 2026.

So there’s now two paths for a commercial solar project to qualify for the 30% ITC (*it’s actually up to 40% with all domestically manufactured components) :

Path 1: Begin construction by July 4, 2026, then place the system in service within four years (by the end of 2030 under the continuity safe harbor).

Path 2: Miss the construction-start deadline entirely, but have the project fully placed in service by December 31, 2027.

THIS IS IMPORTANT : For most commercial projects in Texas –where permitting, interconnection, and construction timelines routinely stretch beyond 18 months for larger systems- Path 2 is not realistic. Path 1 is the viable option, and it hinges entirely on what “begin construction” means. (this gets into the legal weeds a little bit)

What “Begin Construction” Means in 2026 — and What Changed

Historically, the IRS offered two methods for establishing that construction had begun:

1. The Physical Work Test — begin physical work of a significant nature on the project.
2. The 5% Safe Harbor — pay or incur at least 5% of total project costs.

In August 2025, Treasury and the IRS released Notice 2025-42, which eliminated the 5% Safe Harbor for most solar and wind projects. This was a significant change. -And not in the good way, either.

The 5% Safe Harbor Is Gone for Most Commercial Projects

Under Notice 2025-42, the 5% Safe Harbor is no longer available for solar facilities with a maximum net output greater than 1.5 MW (AC). For all wind projects, it’s eliminated entirely regardless of size. The good news is the many (most) commercial solar sites are built at a size of less than 1.5Mwatts.  Keep reading!

The lovely exception: Lower-output solar installations- systems with a maximum net output of 1.5 MW (AC) or less -can still use the 5% Safe Harbor. This covers many rooftop commercial installations, but not larger ground-mount or multi-building projects on the same electrical service. *The IRS has made clear that facilities with “integrated operations”  -same owner, same tax year, same electrical utility interconnection point- will be aggregated for the 1.5 MW determination. You can’t slice a larger project into sub-1.5 MW pieces to stay under the threshold. Yep, they saw this loophole and closed it tight before the start.

The Physical Work Test Is Now the Primary Path

For commercial solar projects above 1.5 MW, the Physical Work Test is the sole method for establishing that construction has begun before July 5, 2026.

This test requires that physical work of a significant nature is performed -either on-site or off-site- with respect to the solar facility. The work can be performed by the project owner directly or by another party under a binding written contract.

What counts as physical work of a significant nature:

• Excavation for foundations or mounting structures
• Installation of racking, piling, or mounting systems
• Pouring concrete for equipment pads
• Off-site manufacturing or assembly of custom components under a binding written contract (e.g., custom inverter skids, structural steel fabrication)

What does NOT count:

• Planning, designing, or engineering the system
• Securing permits or utility interconnection agreements
• Conducting environmental or geotechnical studies
• Ordering equipment without a binding written contract for manufacture
• Site clearing alone (in most cases)

The distinction matters. A signed engineering contract and a pile of permits do not constitute “beginning of construction” under IRS rules. Physical work must actually be performed.

The Continuity Requirement

Starting construction isn’t enough by itself. The IRS also requires a continuous program of construction after work begins.

The good news: there’s a Continuity Safe Harbor. If a project begins construction by July 4, 2026, and is placed in service by the end of 2030, the continuity requirement is automatically satisfied — no questions asked.

If a project takes longer than four years, the IRS will evaluate continuity based on facts and circumstances. Certain disruptions beyond the taxpayer’s control — severe weather, permitting delays, interconnection queues, supply chain disruptions — are explicitly excused and won’t break continuity.

For most Texas commercial solar projects, the four-year window (placed in service by end of 2030) provides ample runway.

What About Projects 1.5 MW and Under?

Good news for smaller commercial installations. Systems at or below 1.5 MW (AC) — which includes many rooftop C&I projects — retain access to both the Physical Work Test and the 5% Safe Harbor.

That means a qualifying project can establish beginning of construction simply by paying or incurring at least 5% of total project costs before July 5, 2026. This is a more straightforward path: sign a contract, make a deposit that hits the 5% threshold, and the clock starts.

However, aggregation rules apply. If you’re planning multiple small systems across several buildings and they share an owner, tax year, and interconnection point, the IRS may aggregate them — potentially pushing the combined output above 1.5 MW and disqualifying the 5% Safe Harbor.

What Happens After July 4, 2026?

If construction has not begun by July 4, 2026, a commercial solar project can only qualify for the Section 48E ITC if it is fully placed in service by December 31, 2027.

That’s an 18-month window from the deadline to full operation — a timeline that’s tight for even straightforward commercial installations, and likely impossible for larger or more complex projects in Texas, given current permitting and interconnection timelines.

For projects that miss both deadlines — no construction start by July 4, 2026, and not placed in service by end of 2027 — the Section 48E credit is simply not available.

What That Means for Project Economics

The 30% ITC is typically the single largest financial driver in a commercial solar project. When combined with MACRS accelerated depreciation (including 100% bonus depreciation restored by the OBBBA, remains available for qualifying property), the federal tax benefits can offset roughly 50–60% of total project cost for qualifying commercial entities. [Frankly this tax math isn’t my strong suit, and I (Adam) am not 100% sure about this, so ask your controller or tax attorney about this!]

Without those incentives, the payback math changes substantially. The project may still make economic sense (rising texas commercial electricity rates, abundant solar resource, and the statewide 100% property tax exemption under Tax Code §11.27 can still provide a pretty strong ROI) but the financial case is meaningfully different if you get the solar project built commissioned too late.

Battery Storage Is Treated Differently

One important note: the OBBBA’s accelerated termination of credits applies to solar and wind facilities. Battery energy storage systems (BESS) are not subject to the same July 4, 2026 construction-start deadline under the OBBBA’s termination provisions. OK. We like this. This helps.

That said, the ITC for standalone storage still exists under its own terms, and the economics of pairing storage with solar are strongest when the solar component qualifies for the full credit. A solar + storage system solution seems to capture the most value when both components are included.

What Texas Commercial Property Owners Should Do Now

If you’ve been evaluating commercial solar, the next 60 days matter. Here’s a practical framework for noodling on this with your team:

If your project is above 1.5 MW (around 3000+ solar panels): Physical work of a significant nature must begin before July 5, 2026. That means you need a binding construction contract and actual physical (or logical) activity -on-site or off-site- underway. Design, permitting, and procurement alone won’t satisfy the test. Talk to a trusted solar firm and tax advisor now about what specific work can be initiated and documented.

If your project is 1.5 MW or under: You have the additional option of the 5% Safe Harbor. A binding contract with a qualifying deposit may be sufficient to establish the construction start date. -Same as above I would encourage folks to discuss the potential project with a turnkey solar integration for (like NATiVE :) and the bean-counters *now* about what specific work can be initiated and documented. Seriously -do it soon.

Regardless of project size: Document everything. The redliners @ IRS will be taking an aggressive position on examining whether projects have genuinely begun construction. Contemporaneous records -contracts, invoices, photos of work performed, delivery receipts, all that stuff- are essential for getting these tax credits!

I’ll say it again here to reiterate : For commercial property owners in Texas who have been in the evaluation phase, the window to capture the full 30% ITC under Section 48E is narrowing. We’re (NATiVE Solar) not in the business of manufacturing urgency as a sales tactis- but the tax code is sorta doing that on its own.

If you’re weighing a commercial solar or solar + storage project, the most productive step right now is a to begin conversations about your project goals and criteria, timeline, site conditions, etc — so you can make an informed decision about whether the July 4 deadline is achievable for your project.

Start a conversation with our team →