{"id":6020,"date":"2025-09-22T11:31:56","date_gmt":"2025-09-22T15:31:56","guid":{"rendered":"https:\/\/www.sunhub.com\/blog\/?p=6020"},"modified":"2025-12-04T04:24:13","modified_gmt":"2025-12-04T09:24:13","slug":"us-solar-policy-shifts-september-2025","status":"publish","type":"post","link":"https:\/\/www.sunhub.com\/blog\/us-solar-policy-shifts-september-2025\/","title":{"rendered":"U.S. Solar Policy Shifts in September 2025 \u2013 Navigating New Rules and Incentives"},"content":{"rendered":"\n

Introduction<\/h2>\n\n\n\n

September 2025 brought a wave of policy changes impacting the U.S. solar industry, from federal tax credit rules to state-level program expansions. Solar developers, manufacturers, and investors are now adjusting to new regulatory realities that will shape project economics. This policy roundup breaks down the major developments, including tighter federal guidelines for tax credits, fresh import tariffs, and notable state initiatives, and what they mean for solar businesses.<\/p>\n\n\n\n

Federal Moves: Tax Credit Guidance and Trade Tariffs<\/h2>\n\n\n\n

1. Stricter ITC \u201cStart Construction\u201d Rules<\/h3>\n\n\n\n

The U.S. Treasury issued new guidance on August 15, 2025, narrowing how large solar projects can qualify for the federal Investment Tax Credit (ITC). Previously, developers could meet a \u201c5 percent safe harbor\u201d by incurring at least 5 percent of project costs before a deadline.<\/p>\n\n\n\n

Under the new rules, projects over 1.5 MW must now use the Physical Work Test. For any solar farm above 1.5 MW that begins construction after September 2, 2025, the developer must demonstrate significant on-site or off-site construction work (such as foundation excavation or equipment assembly) to lock in the ITC, rather than simply spending 5 percent of the budget. Smaller projects at or below 1.5 MW may still use the 5 percent cost method until mid-2026.<\/p>\n\n\n\n

This shift, part of the \u201cEnding Unreliable Energy Subsidies\u201d order by President Trump, aims to prevent abuse of the safe harbor but raises compliance hurdles. Utility-scale developers now face tighter timelines to start tangible construction or risk losing tax incentives. EPCs and project owners must adapt by accelerating procurement and early-stage works to satisfy the Physical Work Test, potentially reshuffling project pipelines.<\/p>\n\n\n

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2. New Tariffs on Solar Imports<\/h3>\n\n\n\n

In a move with major supply chain implications, the White House imposed broad tariffs on imports from India effective August 27, 2025. A punitive 25 percent tariff was added to existing duties, doubling total U.S. tariffs on many Indian goods to roughly 50 percent. While primarily a geopolitical measure tied to India\u2019s Russian oil purchases, this directly impacts solar since India is a growing source of PV modules and cells for the U.S. market.<\/p>\n\n\n\n

Industry analysts warn that Indian-made panels, which many developers had turned to as alternatives to other Asian imports under tariff pressure, will now face steep price hikes. At the same time, antidumping and countervailing duty (AD\/CVD) investigations into solar imports from India, Indonesia, and Laos are advancing. In early September, the U.S. International Trade Commission ruled there is reasonable indication that underpriced imports from those countries are injuring U.S. manufacturers. The Commerce Department is expected to issue preliminary subsidy determinations in October 2025, with potential new import tariffs by year\u2019s end.<\/p>\n\n\n\n

For solar developers and EPCs, the takeaway is clear: imported panels may get more expensive and supply tighter. Many firms are now evaluating U.S.-made module options and revisiting project budgets.<\/p>\n\n\n\n

Implication for Solar Businesses<\/h3>\n\n\n\n

The federal policy shifts present a mixed bag. Stricter ITC guidance demands more upfront construction effort, which may favor well-capitalized developers that can mobilize quickly. Smaller or newer developers might struggle to meet the Physical Work Test, possibly leading to delays or partnerships with larger EPCs.<\/p>\n\n\n\n

On the other hand, the trade actions aim to bolster U.S. solar manufacturing by curbing cheaper imports. Domestic manufacturers could see a boost in demand as foreign panels face tariffs and duties. In fact, factories announced since the Inflation Reduction Act now represent more than 56 GW of new module capacity, a 700 percent increase from pre-IRA levels. However, policy uncertainty around incentive programs continues to cloud the outlook.<\/p>\n\n\n\n

Solar companies must stay agile, using supplier networks to source tariff-free components and engaging in advocacy for clarity on incentive timelines.<\/p>\n\n\n\n

State-Level Updates: Net Metering, Community Solar, and Storage<\/h2>\n\n\n\n

California Net Metering in Legal Flux<\/h3>\n\n\n\n

California\u2019s NEM 3.0 policy, which reduced export credits for rooftop solar, is back under judicial review. In early September, the state\u2019s Supreme Court ordered a rehearing of a case challenging NEM 3.0 on grounds it may conflict with laws supporting solar growth.<\/p>\n\n\n\n

Clean energy advocates argue that the current policy is slowing residential and commercial solar adoption. If the court modifies or rolls back NEM 3.0, installers and financing firms could see a resurgence in rooftop demand in the nation\u2019s largest solar market. For now, uncertainty remains, and providers are advising customers to lock in systems under existing rules while hoping for a more favorable outcome.<\/p>\n\n\n\n

New Jersey\u2019s Community Solar and Storage Push<\/h3>\n\n\n\n

On the East Coast, New Jersey enacted two major clean energy bills in August that took effect in September. First, the state authorized an additional 3 GW of community solar capacity, launching October 1, 2025. This expansion transforms New Jersey\u2019s community solar pilot into a full-scale program, creating major opportunities for developers.<\/p>\n\n\n\n

Second, the state established the Garden State Energy Storage Program, designed to add grid-scale batteries and boost resilience. This signals strong state support for pairing storage with solar, potentially multiplying project revenue through capacity payments and arbitrage opportunities.<\/p>\n\n\n\n

Arizona\u2019s Renewables Requirement Repeal<\/h3>\n\n\n\n

Arizona regulators voted to begin rolling back the state\u2019s Renewable Energy<\/a> Standard and Tariff, which since 2006 required utilities to source 15 percent of power from renewables by 2025. Proponents of repeal claim the mandate is outdated and burdens utilities, while opponents argue it is a step backward.<\/p>\n\n\n\n

If the standard is rescinded, utility-scale developers may lose a key policy driver. However, Arizona\u2019s strong solar resources and declining PV costs may sustain growth regardless. Utilities such as APS and SRP maintain voluntary clean energy goals that could continue to support development.<\/p>\n\n\n\n

Other Notable Updates<\/h3>\n\n\n\n