The biggest change in U.S. solar in 2026 may not be how much solar is being built.
It is how many decisions have to be made before a project can be built.
For C&I EPCs, developers and procurement teams, equipment selection now sits alongside tax-credit eligibility, construction timing, prohibited foreign entity requirements, domestic content, tariffs, equipment origin, inventory location, lead times, warehousing and job-site delivery.
None of those issues is completely new on its own.
What has changed is how often they now overlap.
The United States added 7.8 GW of solar capacity in the first quarter of 2026. Solar remained the leading source of new generating capacity, while solar and energy storage together represented 91% of all new capacity installed during the quarter.
So the U.S. solar story is not simply about whether demand remains.
It does.
The more useful question for the rest of 2026 and into 2027 is:
Which projects can get the economics, equipment, compliance requirements and construction timeline to work at the same time?
That is increasingly where projects are won or lost.
The U.S. Solar Market Is Still Moving, but the Path Is More Complicated
The first quarter numbers show the tension clearly.
Solar added substantial capacity and remained the country’s largest source of new power, but installation levels were lower than the same period in 2025. Meanwhile, contracting for utility-scale solar increased 15% year over year, helped by technology companies seeking additional electricity supply.
That makes simple descriptions such as “solar is growing” or “solar is slowing” increasingly unhelpful.
The market is becoming more segmented.
Project outcomes depend heavily on:
- Location
- Customer electricity economics
- Utility and interconnection conditions
- Tax-credit eligibility
- Construction timing
- Financing
- Equipment sourcing
- Project execution
For C&I solar in particular, national installation numbers provide context, but they do not tell a project team whether a specific facility makes economic or operational sense.
The better question is always:
What does this market mean for the project in front of us?
July 4 Changed the Solar Project Timeline
One of the most important dates for U.S. solar project planning is July 4, 2026.
Under changes enacted in 2025, applicable solar and wind facilities generally must either have begun construction on or before July 4, 2026, or be placed in service before 2028 to remain eligible for the applicable clean electricity credits under Sections 45Y and 48E.
That distinction is important.
Projects that established construction by July 4
These projects may have a different path forward, subject to applicable continuity and other requirements.
The critical task now is documentation.
Project teams should know how construction was established, what work occurred, when it occurred and what records support the project’s position.
Projects beginning after July 4
For applicable projects beginning construction after the deadline, December 31, 2027 becomes particularly important.
Those projects generally need to be placed in service before 2028 to avoid the applicable credit termination provisions.
That puts much more pressure on development schedules.
Permitting delays, interconnection issues, long equipment lead times or construction slippage can now affect more than project COD.
They can affect project economics.
The Physical Work Test matters
IRS Notice 2025-42 also changed how beginning of construction is determined for purposes of these rules.
For most applicable solar and wind projects, the Physical Work Test is now the primary method. The test focuses on physical work of a significant nature rather than a specific percentage of total project cost, with a limited exception for certain low-output solar facilities.
For EPCs and developers, the broader lesson is straightforward:
Tax planning, construction planning and procurement planning can no longer be treated as separate conversations.
Timing has become part of project strategy.
FEOC Is Becoming a Procurement Issue
Another major 2026 development is the implementation of prohibited foreign entity restrictions.
In February, Treasury and the IRS issued Notice 2026-15, providing interim guidance on material assistance from prohibited foreign entities and introducing rules around the Material Assistance Cost Ratio, or MACR.
The guidance applies to certain clean electricity facilities, energy storage technologies and eligible components.
For Sections 45Y and 48E, the rules can apply to facilities or energy storage technologies beginning construction after December 31, 2025.
This changes the sourcing conversation.
A project team may now need to know more than:
Who manufactured the module?
It may need to understand:
- Where key components originated
- Which entities supplied those components
- How material assistance is calculated
- What supporting information the supplier can provide
- Whether alternative sourcing exists
- Whether documentation will be available when the tax position is reviewed
That makes FEOC more than a tax-team issue.
It is increasingly a procurement qualification issue.
A supplier that cannot provide adequate sourcing information may create risk even when its equipment price and technical specifications are attractive.
The question needs to be asked before the purchase order, not after installation.
Domestic Content Also Needs to Move Earlier
Domestic-content planning creates a similar challenge.
The IRS framework does not simply ask whether a finished product carries a “Made in America” label.
Domestic-content qualification involves specific requirements for iron, steel and manufactured products, along with applicable cost calculations and certification requirements. Notice 2025-08 updated elective safe-harbor tables and assigned cost percentages for solar PV and BESS components.
For projects beginning construction in 2026, the manufactured-products threshold reflected in current IRS instructions is higher than for projects beginning in earlier periods.
That means procurement teams should understand the project’s domestic-content strategy before equipment selection becomes difficult to change.
Ask early:
- Which project components matter?
- Which products are domestically manufactured?
- What supporting documentation exists?
- Which cost calculation will the project use?
- Will the supplier provide the information needed later?
Domestic content is increasingly something to design into procurement rather than verify after the fact.
Lowest Equipment Price Is Not Always Lowest Project Cost
Solar procurement has traditionally focused heavily on equipment price.
Price still matters.
But in 2026, comparing two quotes based only on cents per watt can miss a large part of the actual project economics.
A more useful equation is:
Equipment price + tariff exposure + availability + lead time + freight + warehousing + compliance + schedule risk = actual procurement cost
Consider two module offers.
One is slightly cheaper but dependent on future imports, uncertain pricing and a longer delivery schedule.
The other costs slightly more but is already located in a U.S. warehouse near the project.
The lower equipment price may not produce the lower project cost.
The same applies to inverters, storage systems and other critical equipment.
Project teams increasingly need to understand:
- Where the product was manufactured
- Where it is physically located
- Whether inventory is allocated or truly available
- How long pricing is valid
- The actual delivery lead time
- Freight requirements
- Tariff exposure
- Documentation availability
- What happens if the schedule moves
The procurement decision is no longer just:
What does it cost?
It is:
What will it cost to get this product into this project at the right time and with the required documentation?
Section 232 Creates Another Major Procurement Date
Trade policy added another important deadline in August 2026.
On August 6, the White House announced a Section 232 action covering polysilicon and specified derivative products.
The proclamation established minimum import prices of:
| Product | Minimum Import Price |
|---|---|
| Polysilicon | $21/kg |
| Polysilicon ingots and wafers | $100/kg |
| Solar cells | $0.22/W |
| Solar modules | $0.38/W |
The measures apply to covered products entered for consumption, or withdrawn from warehouse for consumption, beginning December 4, 2026.
The proclamation also establishes an additional 15% ad valorem duty on specified downstream products, subject to detailed country-specific treatment and other provisions. Products from the United Kingdom receive different treatment, while Japan, Korea, Taiwan, Switzerland, Liechtenstein and EU members are also addressed specifically in the proclamation.
This means the headline module price floor alone does not tell a project team what a particular shipment will cost.
Project-specific questions matter:
- What product is being imported?
- Where was it manufactured?
- When will it enter the United States?
- Which duties apply?
- Is the product already in U.S. inventory?
- Is there a qualifying pre-existing contract?
- How is the supplier changing pricing?
- How long will today’s quote remain valid?
The proclamation also allows Commerce to establish an onshoring program intended to support additional U.S. production of polysilicon, ingots, wafers and cells.
For procurement teams, December 4 is therefore not simply another tariff date.
It is a reason to revisit sourcing assumptions before 2027 purchasing plans are finalized.
Solar and Storage Are Becoming One Conversation
Battery storage is also moving closer to the center of commercial energy planning.
Solar and storage represented 91% of all new U.S. generating capacity installed in Q1 2026.
For C&I projects, storage is increasingly being evaluated around more than backup power.
Depending on the site and tariff structure, BESS can potentially support:
- Peak-demand management
- Demand-charge reduction
- Solar self-consumption
- Load shifting
- Resilience
- Power-quality objectives
- Facility expansion
- Energy management
That does not mean every commercial solar project needs a battery.
It means storage deserves to be evaluated before the system design becomes difficult to change.
The project conversation increasingly moves from:
How much solar can we install?
to:
What combination of generation, storage and controls makes sense for this facility?
That is a better question for a market where customer loads and electricity costs are changing quickly.
Electricity Demand Is Becoming Part of the Solar Story
While solar policy has become more complicated, the underlying demand for electricity continues to move in the opposite direction.
EIA expects U.S. electricity use to increase approximately 1% in 2026 and another 3% in 2027.
If realized, that would produce the strongest four-year period of U.S. electricity-demand growth since 2000.
Large computing facilities, including data centers, are a major driver.
Manufacturing growth, electrification and other industrial loads add to the broader need for new electricity supply.
That matters for solar because the long-term market is not driven only by incentives.
It is increasingly being driven by a fundamental question:
Where will the next increment of electricity come from?
Solar and storage remain two of the technologies that can respond relatively quickly to new demand.
For C&I customers, rising power demand can also affect utility rates, resilience planning, grid constraints and the value of managing energy behind the meter.
Interconnection Will Continue to Separate Projects From Pipelines
Having equipment available does not mean a project is ready to build.
Interconnection remains one of the clearest examples.
Berkeley Lab reported approximately 8,200 active projects seeking transmission interconnection at the end of 2025, representing roughly 1,312 GW of generation and 749 GW of storage.
Those numbers primarily describe transmission-connected projects rather than ordinary behind-the-meter commercial systems.
But the broader execution problem applies across the market.
A C&I project can still be delayed by:
- Utility studies
- Distribution upgrades
- Permitting
- Engineering revisions
- Financing
- Owner approvals
- Construction availability
- Site-readiness issues
That creates a procurement balancing act.
Procure too early: the project may incur warehousing, carrying-cost and inventory risk.
Procure too late: it may face higher pricing, unavailable equipment or construction delays.
The answer is not always “buy sooner.”
It is to connect procurement decisions to the actual development schedule.
Equipment Location Matters More Than It Used To
“Available” is no longer specific enough.
For project execution, teams should ask:
- Is the equipment already in the United States?
- Which warehouse is holding it?
- Is it physically available or already allocated?
- Can inventory be reserved?
- Can it be staged?
- What is the freight cost to the project?
- Can deliveries be sequenced?
- What happens if construction slips 60 or 90 days?
- Is there backup inventory?
- Is an approved alternate available?
A product sitting thousands of miles from the project presents a different execution profile than the same product already staged regionally.
This is where procurement, inventory management, warehousing and logistics increasingly overlap.
For C&I projects in particular, smaller project sizes do not necessarily make logistics easier.
Delivery schedules, site access and storage space can make careful coordination more important.
What C&I EPCs and Developers Should Do Now
The second half of 2026 is a good time to reopen project assumptions that may have been established under very different conditions.
1. Reconfirm the project timeline
Know when construction began, which tax rules apply and which milestones determine project eligibility.
2. Connect procurement to the actual schedule
Identify the items that truly need to be secured now and the items that can reasonably wait.
3. Review FEOC exposure
Understand the sourcing chain behind critical products and what documentation suppliers can provide.
4. Define the domestic-content strategy
If domestic content matters to the project economics, evaluate it before equipment selection is final.
5. Review Section 232 exposure
Determine whether planned equipment or future imports may be affected by the December 4 measures.
6. Confirm actual U.S. inventory
Do not rely only on broad supplier statements such as “in stock.”
Know the quantity, warehouse and allocation status.
7. Stress-test lead times
Ask what happens if today’s quoted delivery date changes.
8. Build the logistics plan early
Warehousing, staging, freight and job-site delivery should be considered before equipment starts moving.
9. Identify alternate products
A procurement strategy should include a realistic Plan B.
10. Evaluate storage
For C&I projects, determine whether BESS changes demand costs, resilience, energy-management value or the system design.
11. Review pricing validity
A good quote is only useful if it remains valid when the project is ready to buy.
The objective is not to predict every market change.
It is to build a project that can still work when something changes.
What to Watch at RE+ 2026
RE+ 2026 arrives at a useful point in the market.
The event takes place at the Las Vegas Convention Center, with full conference education scheduled for November 16 through 18 and the exhibit floor open November 17 through 19.
For EPCs and procurement teams, the most useful conversations may not be about the newest product.
They may be about whether products can actually support the projects being planned for 2027.
Ask suppliers:
- Manufacturing: Where is the equipment actually manufactured?
- Components: Where are critical components sourced?
- FEOC: What supporting documentation can you provide?
- Domestic content: What project-level information is available?
- Inventory: What is physically available in the United States?
- Lead times: Is the quoted lead time based on inventory, production capacity or a forecast?
- Section 232: How are the December 4 measures expected to affect pricing?
- Pricing: How long can today’s price realistically be held?
- BESS: How is the C&I storage offering changing?
- Logistics: Can equipment be staged regionally or delivered directly to the job site?
- Schedule risk: What happens if our project moves three months?
Those answers may be more useful than another specification sheet.
ESAS will be exhibiting at Booth C4581.
2027 Solar Market Outlook: Execution Becomes the Story
If 2026 is the year project teams adjusted to a new set of rules, 2027 is likely to be the year those rules show up more clearly in project execution.
Substantial solar activity should continue.
There are projects already in development, projects that established construction under earlier rules and projects being planned around rapidly growing electricity demand.
But 2027 could also create a sharper divide between projects that have preserved tax and sourcing flexibility and projects operating within much tighter timelines.
December 31, 2027 will shape project decisions
For applicable solar facilities that did not begin construction on or before July 4, 2026, the requirement to be placed in service before 2028 can make the end of 2027 a critical deadline.
That means a project cannot be evaluated only on equipment economics.
Teams need confidence that equipment can be procured, delivered, installed, commissioned and placed in service within the required schedule.
For some projects, schedule certainty may be worth more than another small reduction in equipment price.
FEOC will become operational
During 2026, much of the market has been working to understand the new PFE and material-assistance framework.
In 2027, those rules are likely to become more embedded in day-to-day project procurement.
Expect more detailed questions around:
- Supplier relationships
- Manufacturing origin
- Component origin
- MACR calculations
- Documentation
- Alternative sourcing
This may change how project teams qualify suppliers before pricing is even compared.
Section 232 will move from announcement to market reality
The December 4, 2026 implementation date means 2027 should provide a much clearer view of how the Section 232 measures are affecting actual equipment pricing and sourcing.
The impact will not necessarily be uniform.
It can depend on product type, origin, existing U.S. inventory, contractual arrangements and supplier strategy.
That makes historical module pricing less useful as a procurement benchmark.
The relevant number is the delivered, compliant cost for the equipment available to the project now.
U.S. inventory becomes strategically important
Trade uncertainty and tighter project deadlines may increase the value of inventory that is already positioned in the United States.
That does not mean every project should buy equipment early.
It means the location of inventory should be part of the risk calculation.
For some projects, regional warehousing may help bridge the gap between when equipment should be secured and when the construction site can receive it.
C&I solar will remain highly regional
Commercial solar economics have always varied significantly from one utility territory to another.
That becomes even more important in 2027.
Electricity rates, demand charges, incentives, permitting, local interconnection conditions and customer load profiles can make two otherwise similar projects perform very differently.
For C&I teams, the national solar forecast matters less than the economics of the specific site.
The strongest commercial opportunities may emerge where rising electricity costs, suitable loads and favorable project conditions intersect.
BESS moves closer to the center
Storage should continue moving upstream in project development.
Higher electricity demand, facility load growth and resilience needs make the timing of energy use increasingly important.
For some customers, the question will no longer be whether solar makes sense by itself.
It will be whether solar, storage and controls together produce a better operating result.
Rising electricity demand supports the long-term market
The strongest underlying argument for continued solar and storage development may be electricity demand itself.
EIA expects U.S. electricity use to rise another 3% in 2027, driven significantly by large computing facilities and data centers.
That demand needs supply.
Solar will not solve every grid problem, but the need for new generation gives the market a fundamental driver beyond policy incentives alone.
The Bigger Outlook for 2027
The U.S. solar market is not simply becoming more expensive.
It is not simply becoming harder.
And the outlook is not best understood as a choice between growth and decline.
The market is becoming more dependent on planning.
Tax rules affect project timelines.
Project timelines affect procurement.
Procurement affects sourcing and compliance.
Trade policy affects equipment price and availability.
Interconnection affects when equipment is needed.
Storage changes system architecture.
Logistics determines whether equipment gets to the project at the right time.
Those decisions increasingly sit on the same critical path.
For C&I EPCs, developers and procurement teams, that changes what good execution looks like.
The teams with the most options in 2027 will not necessarily be those that always find the lowest equipment quote.
They will be the teams that understand the project early enough to make good decisions before those options disappear.
The earlier a project team understands its timeline, sourcing requirements, equipment alternatives and logistics strategy together, the more ways it can respond when the market changes.
Planning Projects for Late 2026 or 2027?
Before locking in equipment, it is worth looking at the full picture:
Sourcing. Compliance. Availability. Pricing. Warehousing. Logistics. Project timing.
ESAS works with C&I EPCs, developers and project teams to support equipment sourcing, procurement, inventory management and project execution.
Talk with the ESAS team about your project and procurement plan.
References & Sources
- U.S. Department of the Treasury & Internal Revenue Service. Notice 2025-42: Beginning of Construction Requirements for Wind and Solar Facilities under Sections 45Y and 48E. Internal Revenue Bulletin 2025-36.
- U.S. Department of the Treasury & Internal Revenue Service. Notice 2026-15: Guidance Regarding Material Assistance from Prohibited Foreign Entities. 2026.
- Internal Revenue Service. Domestic Content Bonus Credit Guidance and Elective Safe Harbor. Including Notice 2025-08 and related guidance for Sections 45Y and 48E.
- The White House. Adjusting Imports of Polysilicon and Its Derivatives Into the United States. Presidential Proclamation, August 6, 2026.
- Wood Mackenzie & Solar Energy Industries Association (SEIA). U.S. Solar Market Insight and 2026 U.S. solar market updates.
- Wood Mackenzie. Solar and Storage Account for 91% of New U.S. Power Capacity in Q1 2026. 2026.
- U.S. Energy Information Administration (EIA). Short-Term Energy Outlook and U.S. Electricity Demand Forecasts. 2026.
- Lawrence Berkeley National Laboratory. Queued Up: 2026 Edition, Characteristics of Power Plants Seeking Transmission Interconnection. 2026.
- RE+. RE+ 2026 Conference and Exhibition Schedule. Las Vegas Convention Center, November 16–19, 2026.
Note
This article is intended for general market and project-planning information. Tax-credit eligibility, FEOC requirements, domestic-content qualification, tariff treatment and other regulatory matters depend on project-specific facts. Project owners and developers should consult qualified tax, legal and trade advisors when evaluating specific projects.
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