Global Solar Module Prices Firm Up as Policy Intervention Overrides Deep Oversupply
Epignosis Insights, a Global Market Research and publishing firm, today released its latest Global Solar Module Price Tracker, documenting how module pricing is exiting one of the most severe down-cycles in the industry's history — a recovery proving as regionally uneven as the collapse that preceded it.
Module Prices Climb Off a Multi-Year Floor
According to the report, blended global module prices peaked near $0.30 per watt in 2022 before a wave of Chinese capacity additions pushed China-origin Tier-1 TOPCon modules down to a floor of $0.085–$0.095 per watt FOB by the first quarter of 2026. That floor is now firming: a 48% jump in Chinese component prices between September and October 2025 has been attributed to a coordinated set of government interventions, including factory utilization cuts of up to 70%, a pivot away from legacy PERC technology, and the cancellation of a 13% VAT export rebate. China's own industry body recorded a more modest 2.3% year-to-date rise in module prices through November 2025, alongside a much sharper 38.9% increase in upstream polysilicon prices — evidence that the recovery so far has been concentrated upstream rather than fully passed through to finished modules.
China's Price Trajectory: Peak, Floor, and Recovery
China still accounts for roughly 85% of nameplate module manufacturing capacity worldwide, making its domestic and export price trajectory the anchor for the entire global market. The market found a firmer floor around the PowerChina 2026 tender, one of the most closely watched domestic demand signals, which cleared at CNY 0.735–0.748 per watt equivalent to roughly $0.103–$0.105 per watt suggesting Chinese manufacturers are maintaining pricing discipline in large domestic tenders even while continuing to accept losses on some export volumes. Market commentary expects China's export module prices to stabilize around $0.12 per watt in the second half of 2026, though China's market regulator complicated the picture in January 2026 by halting a proposed $7 billion industry plan to consolidate polysilicon overcapacity, leaving the pace of further price support genuinely uncertain.
The Policy Catalyst Behind the Price Floor
China's April 1, 2026 elimination of the 9% VAT export rebate on solar products has functioned as the single most consequential policy lever in this cycle, removing exporters' ability to sell below variable cost and still recover margin through the tax credit. Procurement guidance ahead of that deadline showed buyers accelerating orders in January 2026 at $0.086–$0.092 per watt to beat the change, versus a post-stabilization price of $0.108–$0.112 per watt for deliveries from May 2026 onward — an 18–24% pricing gap tied directly to the policy's timing. Layered on top, silver costs have surged more than 200% year-over-year, adding materially to cell production costs since silver paste can account for $0.005–$0.008 per watt of module cost, on par with or exceeding the polysilicon contribution at current, much-reduced polysilicon prices.
Regional Divergence: US, India, and China Pricing Tiers
Trade policy has fragmented what was once a reasonably unified global module market into at least three distinct pricing tiers. In the United States, First Solar's second-quarter 2026 earnings call disclosed U.S. gross bookings of approximately 1.9 gigawatts at an average selling price of $0.36 per watt — roughly four times the concurrent China FOB level — a premium sustained by U.S. antidumping and countervailing duty orders on solar cells and modules from China and several Southeast Asian countries, with some individual company duty rates finalized above 3,400%. India occupies a middle tier: First Solar's India bookings for the first half of 2026 totaled approximately 1.1 gigawatts at an average selling price of $0.20 per watt, reflecting India's Basic Customs Duty structure of 25% on cells and 40% on modules layered onto Chinese-origin imports.
“Module pricing in 2026 is being engineered by policy rather than restored by scarcity, and procurement teams should treat the current $0.085–$0.12 per watt China FOB range as the realistic near-term band rather than a signal that oversupply has resolved.”
Producer Economics and the Oversupply Backdrop
First Solar's own investor disclosures provide the clearest window into how the tariff-protected U.S. market is actually pricing. The company ended the second quarter of 2026 with a contracted backlog of 45.1 gigawatts and an aggregate transaction value of $13.6 billion, net sales of approximately $1.06 billion, a gross margin near 57%, and net income of $423 million, up roughly 24% year-over-year. Management flagged that a pending Section 232 investigation into polysilicon and derivative tariffs remains a source of policy uncertainty, holding back an estimated 1.8 gigawatts of already-finished capacity in Malaysia and Vietnam pending clarity.
None of the recent price firming changes the structural reality that the industry remains dramatically oversupplied. Global module manufacturing capacity is estimated at roughly 1,100 gigawatts against forecast 2026 installation demand of just 649 gigawatts — itself a year-over-year decline from 655 gigawatts in 2025, and the first drop in global solar demand in 24 consecutive years of growth. Polysilicon inventory has been separately estimated at over 570,000 metric tons in early 2026, equivalent to roughly 300 gigawatts of latent module supply sitting upstream of the finished-goods market.
Outlook: Policy-Engineered Stabilization Through 2026
The trajectory into the fourth quarter of 2026 depends on three overlapping variables: whether China's market regulator resumes its paused polysilicon consolidation effort, the outcome of the pending U.S. Section 232 investigation into polysilicon and derivative products, and the pace of demand recovery in China's domestic market relative to the PowerChina tender benchmark. Taken together, the data across government tariff schedules, industry association price indices, company earnings disclosures, and independent consulting-firm forecasts point toward the same conclusion from different angles: 2026 is a year of policy-engineered price stabilization layered on top of genuine structural oversupply, not a return to either the scarcity pricing of 2021–22 or the unrestrained price collapse of 2024–25.
The regional demand mix is shifting in ways that matter for pricing power over the longer run. India is projected to overtake the United States as the world's second-largest solar market in 2026, adding over 50 gigawatts of new capacity, while the Middle East, North Africa, and Sub-Saharan Africa are emerging as a meaningful next wave of demand. That diversification should, over a multi-year horizon, reduce the market's sensitivity to any single country's trade policy — even though in 2026 itself trade policy remains the dominant price driver.