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.

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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

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 →

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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.

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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 →

As we’ve started doing every month, we’ve compiled interesting and/or important solar news from around Texas for April.

Here’s what’s happening around our state so far this month related to the solar and battery energy storage sector:

AG Paxton Launches Residential Solar Fraud Investigation

Our attorney general, Ken Paxton, has issued civil investigative demands to Freedom Forever, Sunrun, Lone Star Solar Services, and CAM Solar (reporting by Solar Power World,) investigating them for potential violations of the Deceptive Trade Practices based on the Consumer Protection Act. Over 100 complaints have been filed with the AG’s office against these companies, with allegations including misrepresentation of energy bill savings and equipment implementations. Office of the Attorney General

*NATiVE note* We knew there were some bad actors in our industry -everybody has heard or read about the horror stories. As a member of AMICUS Solar co-op and a trusted name in the Texas solar energy design/engineering/procurement/construction business since 2007, we’ve stayed far away from offering the shady system performance claims and opaque financing structures that are being investigated by the A.G. We have always aimed to lead with integrity and deliver that promise. This investigation -along with the new Texas solar industry regulations that passed last year- will hopefully go a long way as forcing the bad actors out of business -and keep the others trustworthy and professional. (reporting by  solarpowerworldonline.com)

Clean Earth Opens Solar Panel Recycling in Lancaster, TX

Clean Earth announced TCEQ-authorized solar panel recycling services at its Lancaster, Texas facility, capable of processing 600,000 panels annually. (GlobeNewswire reporting).   This new facility directly supports compliance with recent Texas legislation (HB 3228/HB 3229) requiring state-licensed recycling of all recyclable components at decommissioned solar facilities.

*NATiVE note*  – Most solar panels have a normal lifespan of about 25 years. Some panels become damaged and need to be replaced. We try to do our best to ensure that any panels we remove for replacement are disposed of by reputable reprocessing facilities. As good stewards to the planet we all share, NATiVE will continue to consider (and act with conscience!) the local and global impacts for all aspects of our work. Clean Earth (and other similar Texas solar recycling firms) are tremendously important resources for realizing our commitments here. This newly online facility will make it easier for companies like NATiVE to transport decommissioned solar panels -which do contain small amounts of heavy metals-  and ensure that hazardous waste won’t enter watersheds or contaminate soil.

New Solar Farm (and battery energy storage!) and Grid Expansion Projects Coming Online / Under Development

• Geronimo Power‘s 270-MW Blevins solar + 360 MWh BESS (battery energy storage) plant in Falls County started commercial operations, supplying Fujifilm (125 MW) and Bristol Myers Squibb (145 MW) under long-term PPAs. PV Tech   (*This is a ton of new solar-harvested electricity supply that is now flowing into our over-extended Texas grid. Promises made -promises kept. Now if we can keep the pressure on state energy operators to keep building out additional power line capacity that would be great*)
• ERCOT is launching a $33 billion grid expansion, including  over 2,400 miles of 765-kV “super highway” lines to address surging demand from data centers and the Permian Basin and the extra capacity coming online with the additional of new solar farms and clean gas generation plants. These high-capacity lines,, such as those proposed by Oncor and LCRA will deliver over double the voltage of current infrastructure.
• Meta and developer Zelestra are building the 850-acre “Skull Creek” 176-MW solar farm in Anderson County, with construction starting June 2026. KLTV   (*We reported recently on this a few months ago but there was no solid agreement in place or ground-breaking timeline. We now have a solid construction start date!*)
• Matrix Renewables’ 210-MW Stillhouse Solar Farm in Bell County started commercial operations, backed by a 15-year PPA with Hyundai Motor Group affiliates. Parliament Energy and Ideematec announced 1.2 GW of tracker agreements for three Texas solar projects. (reporting by Solar Builder Magazine)
• US Modules Opens Solar Panel Assembly Plant in College Station (Early April)   A new solar panel assembly facility is now operational in College Station, TX, with a first production line making 400 MW of PERC panels annually, room to scale to 1.4 GW. Solar Power World All panels are for the parent company’s own 3.5 GW development pipeline.  (*Domestic solar panel production has been slow to catch up with other countries around the globe. It’s important for us (NATiVE) to maximize the amount of domestically-sourced solar components for the solutions we build. Texas seems to be ramping up on this regard. We welcome this news!!*)

*REMINDER* One Big Beautiful Bill  -ITC (solar tax credit) Phase-Out Clock Is Ticking –   Commercial solar projects coming online after 2027 won’t qualify for IRA tax credits. New projects must begin construction before July 4, 2026 to remain eligible.

You’ve got questions -we’ve got answers.  Call the state-certified solar practitioners here at NATiVE at 855.234.3131 to discuss your commercial or residential project.

A bombshell piece of investigative reporting dropped this week from Heatmap News, and if you care at all about the integrity of corporate climate claims -whether you’re a homeowner researching solar or a CFO weighing a commercial energy investment- it’s worth understanding what happened.

Here’s the short version: the Greenhouse Gas Protocol, the nonprofit that sets the rules for how companies worldwide measure and report their carbon emissions, just got caught in a credibility crisis. Whistleblowers, suppressed pilot studies, industry interference, and a final standard that essentially tells companies to calculate their forest carbon however they want -it’s not good news for those who care about this stuff. More than 22,000 companies rely on this framework. Here’s the bomb, though -according to the people who helped build it, the process was compromised by secrecy and bias.

We’re a solar and energy storage solutions provider, not a carbon accounting firm. But this story matters to many people making energy decisions right now because it exposes a fundamental question: when someone tells you their product, project, or company is “good for the climate,” how do you know if that’s actually true? 

What Actually Happened

The GHG Protocol spent five years developing its first-ever Land Sector and Removals Standard. This is basically the rules for how companies should account for the carbon impact of forests, agriculture, and land use in the shareholder and regulatory reporting. This matters enormously because forests can both absorb carbon and emit it, and depending on how the numbers get calculated (err tinkered with based on loopholes) determines whether a corporation on paper looks like a climate hero or a significant emitter.

A technical working group was assembled to hash out the methodology used for calculating a company’s carbon footprint. According to Heatmap’s reporting, the group couldn’t reach consensus on a critical question: should companies be allowed to count all carbon absorbed by their managed forests (a method called the “managed land proxy,” or MLP), or should they only count the carbon sequestration that resulted from actual human intervention beyond what nature would have done on its own?

Hmm. Interesting. Under the managed land proxy approach, almost all of the forest product companies that participated in a pilot program reported huge amounts of net carbon removals, making them appear to have a beneficial impact on the climate, contributing nothing to global emissions. In other words, the accounting method that industry preferred made logging companies look carbon-negative on paper.  This wasn’t faithful to the facts.  They actually generated a net-positive amount of carbon emisions.

The scientists on the working group pushed back. A formal complaint was filed against them challenging their expertise. The Protocol had conducted a real-world pilot program that tested this methodology, but the outcomes were not published or shared with the working group -even though the results reportedly demonstrated exactly the problems the scientists were flagging.

In the end, the GHG Protocol finalized its standard in January 2026 without any definitive guidance on forest carbon accounting -telling companies to use whatever method they wanted as long as they disclosed their approach (ie legal mumbo jumbo). Meanwhile, a new academic paper from a member of the Protocol’s own Independent Standards Board argues that the transparency problems are systemic and getting worse.

Why This Matters Beyond Carbon Accounting

You might be thinking: I’m not a timber company. Why should I care?

Fair question. Here’s why.

The GHG Protocol is the foundation for virtually all corporate sustainability reporting, ESG (environmental, sustainability, governance) disclosures, carbon offset markets, and “net-zero” pledges. When a company tells you it’s carbon neutral, or that its products have a lower carbon footprint, or that it’s on track to meet its climate targets -the math behind those claims almost certainly runs through GHG Protocol standards.

And what this reporting just exposed is that the math can be gamed.

This doesn’t mean all carbon accounting is totally worthless. But it does mean that claims built on complex, opaque accounting frameworks are only as reliable as the process behind them -and that process just got a very public stress test. Undisclosed loopholes and corporate accounting gamesmanship are the apparently problem.

We’re leery. Are you leery?

So what does this actually mean if you’re not a timber company or a carbon accountant — but you are someone making a real energy decision for your home or business right now?

What Does Current “Climate Action” Look Like in Practice?

On one end, you’ve got things like carbon offsets, renewable energy certificates (RECs), and corporate pledges built on accounting methods that -as we just learned- can apparently be secretly shaped by the industries they’re supposed to measure. These instruments have their place, but they’re abstractions. They exist on spreadsheets. Their impact depends entirely on the integrity of the methodology (and people) behind them, and that integrity just took a public hit. -Not a good look.

On the other end, you’ve got physical infrastructure that produces measurable energy. A solar harvesting array on your roof generates kilowatt-hours of emissions-free* electricity. Your utility meter records them. A battery energy storage system charges and discharges in response to real grid conditions. Your demand charges go down (or they don’t). The production data is logged by the inverter every 15 minutes. This is hard data.

That’s the difference between accounting-based climate claims and physics-based energy production. One depends on the rules staying honest. The other depends on the sun coming up.

*It should be noted that the manufacturing and shipping solar panel components, batteries, and control equipment does produce carbon-based byproducts. It’s a tradeoff. It should also be noted that there is a huge push to develop new solar tech that is increasingly planet-friendly. 

What This Means for Homeowners

If you’re a homeowner considering solar and batteries, you’ve probably encountered all kinds of environmental messaging: “go green,” “reduce your carbon footprint,” “offset your emissions.” And those things aren’t wrong, exactly. But they’re also not the main reason most Texans go solar.

The main reasons are practical: energy cost management, backup power during grid events, and long-term operational independence from a grid that -as we’ve written about at length– is under enormous strain.

What the GHG Protocol story reinforces is that the environmental benefits of rooftop solar and home battery storage are also more credible than most of the alternatives. Your system’s impact isn’t subject to accounting debates. It’s measured in real electrons that either power your home or they don’t. That’s a claim no methodology revision can take away from you.

What This Means for Commercial and Institutional Operators

For commercial clients -especially those with ESG reporting requirements, sustainability targets, or stakeholders who care about environmental performance- this story matters in a more immediate way.

If your sustainability strategy depends heavily on purchased offsets, RECs, or claims routed through third-party carbon accounting frameworks, the credibility question just got a lot harder to ignore. The scrutiny on these frameworks is only going to increase -and the organizations relying on them will feel it if ethical standards are being upheld.

Deploying on-site solar and battery energy storage don’t make you immune from reporting complexity. But they give your business something that offsets and certificates can’t: a physical asset producing measurable energy, documented by your own metering infrastructure, reducing your facility’s grid dependence in real time. That’s a sustainability claim that doesn’t depend on anyone else’s methodology holding up under investigation.

This is especially relevant for healthcare systems, municipalities, school districts, and other mission-driven organizations where public trust matters. When you tell your community that you’ve invested in clean energy, it’s a stronger statement when there are panels on the roof than when there’s a shady line item for carbon credits on a balance sheet.

Where NATiVE Stands

Part of our job is paying attention to what’s happening in the broader energy and policy landscape -reading primary-source reporting, following the latest from credible industry news shops like Heatmap, and sharing what we find with the people we work with. That’s what this post is.

If you’re thinking about solar or battery storage for your home or facility -and you want a conversation grounded in engineering and real-world data- we’re here and we’ve got answers to your questions.

If you build or own commercial facilities in Texas, you may have considered the thought: integrate solar during construction. But here’s the reality -the vast majority of commercial solar installations in Texas are retrofits, added to buildings that have already been issued their certificate of occupancy -maybe recently, or maybe years ago.

That’s not because developers are broadly uninformed. It’s because commercial real estate has financial and operational dynamics that shape when and if solar makes sense in a building’s lifecycle -dynamics that developers, CGs (and even many other solar installation firms) either don’t understand or choose to ignore. Understanding those dynamics up front is exactly the type of consideration that separates the most efficient and elegant construction plans from the others.

We’re going to walk through the real considerations that drive timing decisions, when early integration delivers the most value, and what every new commercial project in Texas should be doing at a minimum -even if solar panels aren’t part of the immediate plan.

What Drives the Timing Decision for Commercial Solar

In residential new construction, the solar timing is relatively simple. One decision-maker (the homeowner or builder), one building, one utility meter. Pre-wiring during framing and “rough-in” often outweighs the costs of waiting until the structure is completely finished to add the solar infrastructure and active components. The builder and property owner gets a “solar-ready home.” Everyone’s happy.

Commercial construction is a bit of a different animal. The timing question is shaped by several factors that are unique to how commercial projects are financed, built, and operated:

The Split Incentive Question

This is often the first conversation. In the most common commercial lease structure -the triple-net (NNN) lease- the building owner pays for capital improvements, but the tenant pays the utility bills. So if you’re a developer putting up a speculative office building or warehouse, you’d be writing the check for a solar system… and your tenant would pocket the energy savings.

That math doesn’t work for many property owners without some creative structuring. And it’s not a fringe concern. Industry surveys have found that a majority of commercial property owners identify this split incentive as the primary reason they defer energy upgrades. The building owner bears the cost; the tenant gets the benefit. Solutions exist (green lease structures, C-PACE financing, direct ownership models), but they require early planning -and they don’t fit every project.  (Why does everything in life have to be so dang complicated…amiright?)

Value Engineering Pressure

Most commercial building contracts are won by the lowest bid. When a general contractor is running up against budget (and they almost always are) sustainability features are typically the first line items to get cut. Solar, EV charging, high-efficiency HVAC upgrades: these are “nice to haves” are often seen as amenities that get sacrificed to protect the project completion (ie Certificate of Occupancy) timeline and the core scope of work.

Even when a developer wants solar in the original design, it often gets value-engineered out before the foundation is poured. That’s not a failure of intent -it’s just a reality of how commercial construction gets delivered.

The Load Profile Isn’t Known Yet

Here’s one that doesn’t get discussed enough: during construction of a speculative commercial building, you often have no idea who will occupy it. And you can’t properly size a solar + storage system without knowing the building’s load profile. A cold-storage warehouse tenant running refrigeration 24/7 has completely different energy needs than a flex-office user. A manufacturing facility drawing heavy three-phase loads usually looks nothing like a medical office in this context.

So developers defer the decision. “We’ll figure out solar once the tenants are signed and the load profile is clear.” That’s often a reasonable call. But it also means the building gets designed and built without any provisions for solar, making the eventual installation more expensive and disruptive than it needs to be. (More on how to solve that in a minute.)

The Timeline Mismatch

Commercial leases typically run 3 to 10 years. Solar systems are engineered for 25 to 30 years. When the person paying for the system might vacate in five years, the payback math gets uncomfortable. This temporal mismatch compounds the variables to be considered for the split-incentive question -and makes it harder to justify the upfront investment during the construction phase. At least this is usually the case in multi-tenant scenarios.

When It Does Make Sense: Owner-Occupied and Code-Driven Projects

All of the barriers above share a common thread: they exist because of the landlord-tenant divide. Remove that divide, and the calculus changes entirely.

Owner-occupied facilities are the exception to every barrier we just listed. The building owner IS the energy consumer. There’s no split incentive. The load profile is known (or at least predictable). The time horizon is long-term. And the capital investment in solar directly reduces the owner’s own operating costs for decades.

This includes the exact types of projects NATiVE gets involved with every year: manufacturing plants, healthcare facilities, municipal buildings, institutional campuses, retail-owned properties, and mission-critical operations centers. If you own the building and pay the electric bill, integrating solar during construction is one of the safest net-ROI decisions you can make.

The Code Is Catching Up

There’s another force pushing solar into new commercial construction, and it’s regulatory.

The 2024 International Energy Conservation Code (IECC), Section C405.15, now includes a mandatory on-site renewable energy requirement for new commercial buildings. The prescriptive path calls for on-site generation capacity of at least 0.75 watts per square foot of gross conditioned floor area. If on-site generation isn’t feasible, the code provides pathways for off-site renewable energy procurement — but the default expectation is solar on the roof.

This isn’t hypothetical. Texas cities are already adopting these provisions:

• Austin adopted the 2024 IECC commercial provisions effective July 10, 2025, including the renewable energy and energy storage appendices.
• McKinney has adopted the 2024 IECC, with city documentation specifically referencing solar-ready provisions and the renewable energy requirements.
• At the state level, SB 783 (passed in 2025) directed the State Energy Conservation Office (SECO) to consider the 2024 IECC for adoption as the Texas state minimum energy code. That process is currently underway.

The 2024 IECC also requires that construction documents include designated areas for future energy storage systems and the routing of cables and raceways for future on-site renewable energy (Section C105.2). Buildings over 5,000 square feet must achieve renewable and load management credits under the expanded C406 point system.

If you’re building a new commercial facility in Austin, McKinney, or any jurisdiction that adopts the 2024 IECC  -the full list of municipalities is larger and growing- renewable energy provisions are no longer optional. They’re part of your code compliance checklist.

The Minimum: Spec the Electrical Switchgear, Even If You Skip the Panels

OK. So maybe you’re a speculative developer. You don’t know who the tenant will be. The lease structure doesn’t justify a full solar installation during construction. We get it.

But here’s what our operations and engineering team will tell you: at a minimum, every new commercial project falling under the new code provisions should include the PV (photovoltaic solar array) system disconnect (we call it “switchgear”) in the primary electrical / MEP design.

Why? Because adding the basic solar switchgear to the project’s stamped electrical scope removes the need to have the utility company SHUT OFF THE SITE’S POWER CONNECTION upon eventual completion of the solar system. It also helps ensure that the building’s physical footprint can be elegantly adapted for this before construction scope is locked-in.

We get it.  This can feel like a real risk to your project’s certificate of occupancy (CoO) timeline. GCs feel this acutely. Anything that touches the primary electrical infrastructure after the main panel is set is a change order, a potential re-inspection trigger, and a schedule risk. Nobody wants to explain to the ownership group why the CO got pushed because of a solar disconnect that should have been in the original spec.

So here’s the thing : The marginal engineering/cost/human effort of including PV-ready switchgear during primary construction is low.  The cost and inconvenience of retrofitting it later is disproportionately high.

While you’re at it, consider also including:

• Conduit runs from the electrical room to the roof or a designated ground-mount area
• Panel capacity in the main distribution board to accommodate future solar and storage circuits
• Structural provisions for rooftop or carport-mounted arrays (roof load design, mounting points)

This is the “solar-ready” minimum. And increasingly, it’s not just a smart move -it’s a code requirement in jurisdictions adopting the 2024 IECC.

Think of it like rough-plumbing a bathroom in a basement. You may not finish it today, but running the drain lines while the slab and walls are open costs almost nothing compared to jackhammering the concrete or knocking through drywall later.

What Changes When Solar Is Engineered In From Day One

For owner-occupied projects where integration does make sense, the advantages are significant:

Structural engineering happens once, not twice. Roof load calculations account for solar panels alongside HVAC units, skylights, and other equipment. Panel placement is optimized from the start — not crammed into whatever space is left after everything else is installed.

Electrical infrastructure is designed holistically. The main service panel, switchgear, metering, and conduit are all sized and routed for solar + storage from the beginning. No expensive panel upgrades, no re-engineering of the electrical room, no surprises during interconnection.

Permitting runs in parallel. The utility interconnection application can be submitted alongside building permits rather than as a separate, sequential process that adds months to the timeline after the building is occupied.

Design integration matters for facilities where appearance counts. Retail, healthcare, civic, and mixed-use buildings benefit from solar that’s architecturally integrated — not visibly bolted on as an afterthought.

And for the Texas ERCOT market specifically: systems should be designed for self-consumption and demand charge mitigation, not grid export. There’s no guaranteed net metering (1:1 solar export credits) in most of Texas. That -and other factors- fundamentally shape how commercial solar + storage systems are sized and operated.

The Incentive Timing Layer: Why 2026 Matters

We’d be remiss not to mention the federal incentive picture, because for projects currently in design or early construction, the timing is directly relevant.

The commercial Investment Tax Credit (Section 48E) remains at 30% (up to 40%) for eligible projects that begin construction before July 4, 2026. Projects starting after that date face a hard December 31, 2027 placed-in-service deadline -meaning you’d need to go from groundbreaking to energized system in roughly 18 months, which may be super tight (or impossible) for many commercial installations.

Safe harbor rules have also tightened. Under the OBBBA and IRS Notice 2025-42, the Physical Work Test is now the primary method for establishing beginning of construction for solar systems over 1.5 MW. The old 5% cost safe harbor is still available for smaller commercial systems, but the documentation and compliance requirements have increased.

New Foreign Entity of Concern (FEOC) sourcing restrictions also apply to projects beginning construction in 2026, adding a supply-chain compliance layer that affects equipment procurement decisions.

The point here isn’t to create urgency for urgency’s sake. Seriously. It’s that for owner-occupied projects already in the design phase, the incentive calendar aligns well with integrating solar into the build. Waiting means potentially leaving significant value on the table.

What NATiVE Brings to New Construction Projects

NATiVE Solar has been operating in Texas since 2007. We’re a commercial-first EPC  -meaning we approach every project as a systems consulting and engineering challenge, not a commodity solar installation. Our team has deep experience coordinating with general contractors, ECs, architects, and structural and electrical engineers during both the design abnd construction phases of new builds. NATiVE Solar delivers commercial-scale solar and battery energy storage solutions designed as long-term infrastructure.

The types of projects where solar integration during construction makes the most sense -municipal facilities, healthcare campuses, warehouses, manufacturing plants, institutional buildings, owner-occupied retail- are the projects we’ve been delivering for nearly two decades.

For developers building speculative or multi-tenant properties, we’re equally happy to consult on solar-ready provisions: system sizing, site design integration, switchgear spec, conduit routing, structural allowances, and code compliance for jurisdictions adopting the 2024 IECC.

If you’ve got a commercial project in design or early construction and want to evaluate solar integration or solar-ready provisions, let’s talk. We’ll give you the straight story and be there as a resource to discuss the whats, ifs, whens, and hows at any point in the projects construction.

When NATiVE’s consultants speak with facility managers and business owners across Texas about their energy strategy, the conversation often starts with month-to-month energy bill savings, tax implications and the balance sheet. But the discussion has shifted over time. It’s no longer just about trimming the utility bill -it’s becoming more about energy resilience and operational certainty.

And if you’re wondering why, you don’t just have to take our word for it. Major financial institutions are officially sounding the alarm on the future of the grid.

An Unprecedented Surge in Demand

We recently read through a newly published macroeconomic report from J.P. Morgan, and the numbers are pretty staggering. To keep up with the demands of our modern economy (think data centers/AI compute, industrial EV fleets, domestic re-industrialization, etc) they project that power generation needs to grow “more than 4x from today’s levels” over the next coupe of decades.

Compared to historical trends, this isn’t a slow, gradual increase. It’s a massive, immediate demand spike, and it’s heavily concentrated right in the commercial and industrial (C&I) sectors powering the Texas economy. As included recent industry data shows, Industry alone accounts for nearly 30% of new electricity demand between now and 2030.

A 20th-Century Grid for a 21st-Century Economy

And so here’s where the rubber meets the road, folks : this surging demand is crashing headfirst into an aging physical grid. The American Society of Civil Engineers (ASCE) recently gave the US energy grid a sobering D+ grade. This group gave Texas a “C-“.   It gets worse -the Electric Reliability Council of Texas (ERCOT) (our own grid) has received a D-  in the 2026 update from Americans for a Clean Energy Grid.

Why? Well, mainly because 70%+ of transmission lines are over 25 years old and more than half of all distribution transformers in the U.S. are nearing end of life according the JP Morgan’s report. (Here’s ERCOT’s Texas-specific data on aging infrastructure statistics which shows roughly the same numbers : https://www.ercot.com/files/docs/2025/03/14/ERCOT-2024-State-of-the-Grid.pdf)

Or, as one JPM analyst perfectly summarized it: “The grid was engineered for the 20th century. We’re asking it to power the 21st.”

The Texas grid is going to need to be transformed. It’s going to take a while and it’s going to be expensive for rate/tax payers. (This is covered a bit further down the page.) But Texas business can take action now.

What This Means for Texas Businesses

If you’re operating in Texas -especially if your business draws a lot of power), you may already know that navigating ERCOT market dynamics and transmission constraints can be tricky. The national infrastructure gap highlighted by J.P. Morgan is something we feel locally as manifested by rate instability, grid instability, long interconnection wait lists, and bureaucratic red tape. (NATiVE Solar helps our clients navigate some of this mess as well :) )

It all comes down to costs and risks. It’s going to be expensive to get this fixed. And the risks for not getting this fixed are higher than anyone wants to think about.

The multi-billion-dollar question is: who pays for all these necessary grid upgrades? The answer is simple: the ratepayers. Right now, it’s your utility company planning the rate hikes to cover that gap. For institutional, healthcare, manufacturing, and retail operators, that means a future of heavier demand charges, unpredictable rate escalations, and more vulnerability during grid stress events. The cost to update the Texas grid is estimated at over 33 Billion dollars. Let that sink in for a second…  Now imagine that the grid operators and state legislature aren’t simply going to eat that cost themselves. We’re all on the hook at this point.

And…waiting to address your facility’s energy strategy essentially means making a long-term bet on aging infrastructure, and absorbing the financial burden of those utility-led upgrades.

Building a Commercial-Grade Hedge

If the consensus from the world’s leading financial experts is that power demand will inevitably outstrip grid capabilities, installing commercial solar PV (photovoltaic) harvesting and a Battery Energy Storage System (BESS) isn’t just about “going green.” It’s a hard-nosed financial defense mechanism. It’s just common sense.

• Predictable Lifecycle Performance: With utility rate hikes practically baked into the future, locking in your energy costs is one of the best ways to protect your operating margins over the next 20 to 25 years.
• Demand Charge Mitigation: Turnkey solar and BESS deployments give you the power to actively manage your facility’s load profile. In Texas, this is huge for drastically reducing the demand charges that typically dominate commercial utility bills.
• Strategic Independence: Investing in commercial-grade renewables today means “you’re selling [or securing] a hedge against an inevitable future.” First-movers are going to secure the maximum lifecycle value.

A Partner for the Long Haul

Navigating Texas grid realities takes more than just a transactional installer. It requires a turnkey EPC-capable integrator who actually understands engineering, construction, and long-term operations and maintenance (O&M).

At NATiVE Solar, our firm’s practice is built around deeply understanding both the clients’ needs AND the quickly changing Texas energy market. Our own experience here at NATiVE has shown us that it takes operational and logistical discipline on top of world-class consulting, design, engineering, construction and services practices. We aren’t here to give you a hard sell on zero-down gimmicks; we’re here to help you build commercial-grade energy infrastructure that performs when you need it most -and delivers decades of reliable energy as a business-critical resource.

If you’re ready to get ahead of the curve, let’s sit down and discuss how a partnered approach to commercial solar and storage can protect your facility’s bottom line for decades to come.

If you want to dig deeper into the numbers and insights, here’s the direct link to the new JPM report: https://www.jpmorgan.com/insights/sustainability/climate/grid-resilience-neglected-no-more#:~:text=Global%20grid%20spending%20increased%20from,for%20digital%2Drelated%20grid%20capex.