43 GW: Solar tops new US power for the 5th year in a row

The US added 43 GW of new solar capacity in 2025, with solar and energy storage accounting for 79% of all new generation capacity; Texas led with 11 GW. Module manufacturing capacity jumped >50% to 65.5 GW and Wood Mackenzie/SEIA project another 490 GW of additions by 2036 (nearly 770 GW installed total if realized). State-level growth was strong (11 states set records; 12 states added >1 GW; Indiana rose to ~3 GW from 1.6 GW in 2024), but policy risks—ending the 30% residential tax credit, Foreign Entity of Concern guidance, trade actions, and permitting—could slow deployment and affect prices.

Analysis

The market is moving from a scarcity story (cheap modules) to a bifurcated industrial story where domestic manufacturing and project execution speed are the new arbitrage. Companies that own US fabrication capacity capture a margin premium not just from tariffs but from reduced logistics lead times and greater contractual certainty for utility-scale RFPs; that premium will compound as interconnection bottlenecks handcuff projects that rely on longer, riskier import chains.

A second-order effect is daylight price cannibalization compressing merchant energy returns and shifting value toward flexible services (fast-ramping gas, storage stacked with capacity and ancillary services, and transmission upgrades). Expect mid-day wholesale price floors to drift lower regionally where solar concentration is highest, which inflates the optionality value of storage that can arbitrage both intraday and seasonal spreads — but that optionality will be volatile as storage buildout accelerates.

Policy and trade actions remain the primary short-term swing factors: single regulatory guidance or a punitive trade ruling can turn a domestic supply advantage into a temporary short squeeze or, conversely, choke project economics if permits or components get delayed. On the margin, the consensus underestimates localized grid constraints — that means some developers will see project returns collapse while incumbent regulated utilities and transmission owners pick up excess T&D capex and predictable regulated returns.

Key Decisions for Investors

• Long FSLR (First Solar) — 12–24 month horizon: buy equity or buy-dated calls after any policy noise pullback. Rationale: US fabs earn a sustainable spread versus importers when tariffs/permits tighten. Risk/Reward: asymmetric — downside 25–35% on industry selloff vs 40–80% upside if domestic content becomes a de facto procurement requirement; set 25% stop-loss and scale in on permit/tariff headlines.
• Long ENPH (Enphase) — 6–12 month horizon: overweight stock or buy 9–12 month calls with limited size. Rationale: resilient software/recurring revenue and edge position on residential storage pairing even if ITC headwinds slow installs. Risk/Reward: 30–50% upside if residential storage rebounds; downside 20–30% if installs materially retrench.
• Pair trade — Long AES (AES) or FLNC (Fluence) vs Short NRG (NRG) — 6–18 months: equal notional long storage/integrator exposure vs short merchant generator. Rationale: storage captures stacking revenues and capacity markets; merchant baseload faces midday price cannibalization. Risk/Reward: target 2:1 reward/risk; cut pair if capacity market redesigns materially reprice firm capacity.
• Long NEE (NextEra) small core position — 12–36 months: buy-and-hold for regulated + merchant optionality. Rationale: regulated transmission/upgrades and scale in project execution give defensive exposure to grid capex. Risk/Reward: modest upside (20–35%) with low volatility; hedge with short solar developer exposure if transmission permitting outcomes worsen.