According to SMM data, as of August 18, the average price of domestic polysilicon dense and recharge material stood at RMB 40.5/kg, representing a 26.96% increase from July 31. Some leading producers were quoting as high as RMB 43/kg to external buyers.

Global coal markets generally strengthened over the past week, although performance varied across regions and grades. European thermal coal indices rose above $124/t, supported by firmer oil and gas prices, geopolitical risks and weaker renewable and nuclear generation during the heatwave. South African 6,000 kcal/kg high-CV coal exceeded $109/t, with additional support from Indian enquiries and a 12 August train derailment that disrupted deliveries to Richards Bay Coal Terminal. China’s Qinhuangdao 5,500 NAR spot price strengthened above $126/t. Coal stocks at nine major ports declined by 0.87 mnt week on week to 26.51 mnt, while inventories at six major coastal thermal power plants fell by 0.25 Mt to 14.01 Mt. Lower inventories and tighter mine safety inspections supported domestic prices and increased Chinese traders’ interest in imported blending coal. Indonesian 5,900 GAR coal rose to $104.5/t, while 4,200 GAR material approached $64/t. Australian thermal coal prices were mixed, with 6,000 high-CV coal falling below $128/t while 5,500 mid-CV material strengthened to $95–96/t. Meanwhile, limited availability of premium metallurgical coal, renewed purchasing and improved Chinese market sentiment lifted the Australian HCC index to $224/t.

India’s average daily maximum power demand increased by approximately 9.4% year on year during the first half of August 2026, while total electricity generation rose by around 7.6%. Renewable generation surged by approximately 39% to 17.3 TWh, but hydropower output fell by around 17% to 11 TWh, requiring coal-fired generation to increase by approximately 6% to 58.1 TWh. Higher coal-fired output accelerated the drawdown of power plant inventories. Coal stocks monitored by the Central Electricity Authority declined from 38.01 mnt on 31 July to 34.71 mnt on 16 August, a reduction of approximately 3.31 mnt, or nearly 9%. However, the number of plants with critical stocks increased only from 31 to 32, while daily coal receipts of around 2.42 mnt on 16 August marginally exceeded consumption of approximately 2.40 mnt. The situation therefore indicates localised logistical and inventory pressure rather than a nationwide coal shortage.

[Macro Expectations Repeatedly Disturb, Aluminum Prices Consolidate with Upside Encountering Resistance] Overall assessment: Short-term aluminum prices are expected to mainly consolidate, with upside room somewhat capped by expectations of production resumptions.

Futures: Overnight, the LME lead 3M contract drifted higher throughout the day on August 18, opening at $1885.5/mt. It moved sideways in a range of $1883-1890/mt during Asian hours, briefly surged toward the end of European hours to touch a high of $1896.5/mt, then subsequently pulled back, ultimately closing at $1888.0/mt, up $3.0/mt or 0.16% from the previous trading session. The daily trading range was $1883.0-1896.5/mt, with a swing of $13.5/mt. The daily candlestick was a small bullish candlestick with a long upper shadow. Trading volume was 4,729 lots, open interest was 178,938 lots, and intraday open interest fell sharply by 5,863 lots. Overnight, the SHFE lead 2610 contract night session opened at 15,965 yuan/mt. After the open, it quickly surged to a high of 16,025 yuan/mt, subsequently consolidated lower to dip to 15,905 yuan/mt, then rebounded to trade around 15,955 yuan/mt, up 50 yuan/mt or 0.31% from the previous session’s closing price. Night session trading volume was 33,162 lots, open interest was 79,286 lots, down 892 lots from the previous session. On the macro front: The US-Iran conflict continued to escalate, Trump said there were no negotiations with Iran, the blockade of the Strait of Hormuz remained fully effective, the UAE suspended trade with Iran, and geopolitical uncertainty in the Middle East continued to intensify. The US dollar index traded sideways above 99 for nearly two weeks, and the 10-year Treasury yield briefly rose to 4.75%, a new high since January 2025. On the domestic front, a super-strong El Niño event could form this winter, likely the strongest on record, potentially disrupting power supply and smelter operations. The A-share market was mixed, with the Shanghai Composite Index closing up 0.19% and the Shenzhen Component Index falling 0.56%, as combined turnover on the two exchanges reached 2.4 trillion yuan. Housing provident fund policy adjustments now allow withdrawals for home decoration and property fee payments, with no income thresholds for rental withdrawals, benefiting post-cyclical real estate consumption. Spot fundamentals: SHFE lead pulled back slightly, continuing to consolidate at highs. The SMM 1# lead price fell 25 yuan/mt. Suppliers' selling sentiment became more divided, with some holding firm on quotes or suspending sales due to limited inventory, while others sold at prevailing prices. Quotations from major producing regions were at discounts of 20 yuan/mt to premiums of 50 yuan/mt against the SMM 1# lead average price, delivered basis. Secondary lead smelters showed only modest selling interest, tradable material in the market was limited, and secondary refined lead was quoted at discounts of 100-0 yuan/mt against the SMM 1# lead average price, delivered basis. Downstream enterprises had limited restocking needs, and inquiry interest declined from yesterday, leaving spot market trade somewhat sluggish. Although lead-acid battery consumption relatively improved, demand for lead ingot purchases remained limited. Inventory: As of August 18, LME lead inventory was 409,000 mt, down 1,975 mt from the previous trading day; total SHFE lead ingot warrant inventory was 65,564 mt, down 325 mt from the previous week. Today's Lead Price Forecast: Downstream enterprises had limited rigid demand, inquiry activity declined compared to the previous day, and spot market trading was sluggish; lead-acid battery consumption improved somewhat, but procurement demand for lead ingots remained limited, providing insufficient upward momentum for lead prices. Supply side, suppliers showed divergent attitudes toward shipments: some maintained firm offers or suspended shipments due to limited supply, while others sold at market prices; secondary lead smelters had moderate enthusiasm for shipments, leading to limited circulating sources in the market; coupled with declines in both LME and domestic lead inventories, this provided some support for prices. Overall, lead prices maintained a fluctuating trend.

[SMM Cast Aluminum Alloy Morning Comment: Night Session Weakens, Cost-Supported Consolidation] Overnight, the Aluminum Alloy 2610 contract opened at 23,025 yuan/mt, reached a high of 23,040 yuan/mt, a low of 22,920 yuan/mt, and closed at 22,965 yuan/mt, down 120 yuan/mt from the previous settlement, a decline of 0.52%.

Polysilicon, wafer and cell price spikes lifted supplier offers in August, while weak international demand kept China-port FOB transactions near their early-month lows.

SMM Morning Meeting Minutes: Overnight, LME copper opened at $14,045/mt, hit a high of $14,106.5/mt early in the session, then its price center descended and fell to $13,958/mt, before finally closing at $13,961.5/mt, down 1.2%. Trading volume reached 21,000 lots, and open interest stood at 270,000 lots, a decrease of 276 lots from the previous session, indicating long liquidation. Overnight, the most-traded SHFE copper 2609 contract opened at 107,630 yuan/mt, immediately hitting a high of 107,770 yuan/mt, then the price center plunged straight down to hit a bottom of 106,820 yuan/mt, finally closing at 107,020 yuan/mt, down 0.89%. Trading volume reached 42,000 lots, and open interest stood at 186,000 lots, a decrease of 6,652 lots from the previous session, indicating long liquidation.

SMM, August 19: Overnight LME copper opened at $14,045/mt, hit a high of $14,106.5/mt at the opening, then the price center moved lower and dipped to $13,958/mt, eventually closing at $13,961.5/mt, recording a decline of 1.2%. Trading volume was 21,000 lots, and open interest was 270,000 lots, down 276 lots from the previous trading day, reflecting long liquidation. Overnight, the most-traded SHFE copper 2609 contract opened at 107,630 yuan/mt, touched a high of 107,770 yuan/mt at the opening, then the price center moved sharply lower and hit bottom at 106,820 yuan/mt, eventually closing at 107,020 yuan/mt, posting a decline of 0.89%. Trading volume was 42,000 lots, and open interest was 186,000 lots, down 6,652 lots from the previous trading day, also reflecting long liquidation. On the macro front, geopolitical risks in the Middle East remain uncertain. Trump stated that he had no intention to restart negotiations with Iran, and Iran’s parliament speaker also said that the Strait of Hormuz would remain closed, as the risk of regional conflict has not fully eased. In addition, LME inventory increased for two consecutive days, gradually alleviating market concerns over tight supply in non-U.S. regions for the time being. This expectation exerted some bearish pressure on copper prices. From the fundamental perspective, on the supply side, with some arrivals of domestic and imported cargoes, the tight supply situation marginally improved. On the demand side, affected by the intraday pullback in copper prices, downstream enterprises’ willingness for just-in-time procurement was released to some extent, driving some spot transactions. Overall, copper prices are expected to consolidate on a subdued note within a narrow range today.

Since the beginning of August, China’s solar cell market has staged a sharp reversal. TOPCon cell prices bottomed out in late July and rebounded rapidly. Compared with the lows seen from late July to early August, mainstream prices as of August 18 had risen by more than 20% across major formats, with gains in some specifications approaching 30%. The rally was initially supported by a rising cost floor. Since mid-August, however, the pace of price increases has clearly exceeded what can be explained by cost recovery alone. Following the rollout of the U.S. Section 232 measures, expectations for front-loaded procurement across supply chains serving the U.S. market have intensified. Traders have increasingly become marginal buyers of higher-priced cells, further amplifying gains in the spot market. In contrast, domestic module manufacturers remain reluctant to accept current high cell prices. This means that while the market is being supported by the policy window and export-related stockpiling, whether the rally can evolve from a short-term move into a more sustainable uptrend will ultimately depend on whether higher cell costs can be passed through to module prices and whether domestic demand can take over once the policy-driven export window begins to close. Current Market: Cost Recovery Sets the Floor, Export Stockpiling Amplifies the Rally The market began to reverse rapidly in August. According to SMM data, as of August 18, mainstream price ranges for TOPCon G12R, M10 and G12 cells had risen to RMB 0.316-0.367/W, RMB 0.316-0.367/W and RMB 0.319-0.352/W, respectively. Offers for some G12R and M10 cells briefly reached around RMB 0.38/W. Costs provided the initial foundation for the rebound. Since late July, stronger expectations for higher polysilicon prices, a rapid recovery in wafer prices, and rising costs for silver paste and other auxiliary materials have jointly lifted the cost floor for solar cells and strengthened producers’ willingness to hold firm on offers. However, cost movements can largely explain why prices were able to rebound from low levels; they do not fully explain the pace of gains since mid-August. The stronger driver behind the acceleration has been rapidly rising expectations for advance procurement following the rollout of the U.S. Section 232 measures. On August 6, the United States formally announced Section 232 measures covering polysilicon and its derivatives. The measures set minimum import prices of $0.22/W for solar cells and $0.38/W for solar modules. They will take effect at 12:01 a.m. U.S. Eastern Time on December 4, 2026, for covered products entered for consumption or withdrawn from warehouse for consumption. Certain polysilicon derivatives listed in the announcement will also be subject to additional ad valorem duties. The transition period between the announcement and implementation has prompted front-loaded procurement and inventory building across the Asian solar supply chain serving the U.S. market. Based on current transaction patterns, this incremental demand is becoming an increasingly important marginal driver in the spot market. According to feedback from supply-chain traders surveyed by SMM, the market could see around 15-20 GW of solar cell stockpiling demand during the policy window, with traders also emerging as key buyers of some higher-priced material. It is important to stress that the 15-20 GW figure remains an industry survey estimate and market expectation. It does not represent volumes that have already been contracted, prepaid, assigned shipping schedules or exported. Only if a substantial portion of this expected demand is ultimately converted into actual purchase orders will it materially affect near-term cell shipment flows and spot inventories. Module Makers: Domestic Demand May Take Over, but Acceptance of High Cell Prices Remains Limited Compared with traders, domestic module manufacturers remain cautious about purchasing high-priced cells. On the one hand, domestic project demand is expected to improve in Q4, which could support a sequential recovery in module production schedules and cell procurement. On the other hand, module producers remain constrained by end-market tender prices, project returns and their own inventory positions. At present, module makers generally view RMB 0.33-0.35/W as a more acceptable procurement range for solar cells. In terms of cost pass-through, solar cells have responded relatively quickly in the current round of price increases, but whether module prices can rise in tandem remains uncertain. If module selling prices fail to absorb the increase in cell costs, module producers are more likely to delay procurement, reduce safety inventories, prioritize internally produced cells or adjust production schedules rather than continue chasing higher-priced external supply. This is likely to lead to greater market segmentation. Cell producers with well-secured export orders may be able to maintain firmer offers, while standard domestic orders and more abundantly supplied formats may remain subject to pricing pressure from module makers. As a result, the current rally is more likely to remain structural rather than develop into a synchronized increase across all formats and all producers. Why Could Mid-October Become a Key Turning Point? It is worth noting that the Section 232 measures do not provide an unrestricted window for imports ahead of implementation. The U.S. presidential proclamation also states that if the Secretary of Commerce determines that a company has stockpiled polysilicon or its derivatives before the measures take effect, the department may coordinate with U.S. Customs and Border Protection to impose import restrictions. Advance procurement by traders therefore should not be viewed as risk-free front-loading. How U.S. authorities distinguish between normal inventory preparation and policy-avoidance stockpiling, as well as how strictly the provision is ultimately enforced, could also affect actual shipment flows. The Section 232 measures are scheduled to take effect on December 4, 2026. According to trader feedback, arranging shipments from China or other major Asian production hubs, completing ocean freight and clearing U.S. customs generally requires at least around 40-45 days. Working backward from the implementation date, shipments intended to enter the U.S. before the new measures take effect may therefore need to depart by around mid-October to provide a more comfortable logistics buffer. From a procurement perspective, the closer the market gets to mid-October, the less time remains to arrange new export orders, which could gradually reduce traders’ willingness to chase higher prices. Assuming no major changes in logistics conditions, trader purchasing patterns or subsequent U.S. implementation rules, the market could follow a baseline pattern in which export-related stockpiling continues to support orders and prices through August and September. As the available shipping window narrows and compliance risks rise in October, new inquiries may gradually decline. If incremental export procurement weakens materially by mid- to late October, domestic module producers could once again become more influential in setting solar cell prices. Q4 Outlook: Domestic Demand May Provide a Floor, but Correction Risks Rise After October From a supply-demand perspective, the solar cell market could see two distinct phases of demand in Q4. The first phase is concentrated procurement linked to front-loaded exports. Such orders tend to be released quickly and are highly sensitive to delivery timing. Traders may be willing to pay a certain premium to secure product within the available policy window, helping reduce inventories at cell producers and providing continued support to prices. The second phase would depend more heavily on domestic demand. Q4 project deliveries could lift module production schedules and, in theory, increase solar cell consumption. However, domestic module producers are much more cost-sensitive than traders purchasing against a time-limited export window. Their procurement is more closely tied to immediate production needs, and they are less willing to absorb elevated prices. In other words, stronger domestic demand could provide downside support, but may not be sufficient to sustain the high prices created during the export-driven procurement window. Based on this logic, SMM expects solar cell prices to remain relatively firm through August and September, while upward momentum could gradually weaken after entering October. If new export orders begin to decline from early October while module producers continue to resist higher prices, the probability of a downward shift in transaction prices will increase in mid- to late October. The scale of any correction will depend on the actual volume purchased by traders, incremental production at cell manufacturers and the strength of domestic module demand. At the same time, if a substantial portion of the expected 15-20 GW of stockpiling demand is converted into trader purchases but downstream consumption ultimately lags the pace of earlier inventory building, stock pressure could increase once the policy window closes. If part of the material remains in trader inventories or overseas warehouses, subsequent channel restocking demand may effectively have been pulled forward, potentially weakening export orders further in November and December. Three Indicators to Watch First, changes in the volume and pricing of solar cell purchases by module manufacturers. If higher-priced transactions remain concentrated among traders while module makers continue to procure only on a low-inventory, just-in-time basis, the rally will still lack sustained downstream support. Second, cell producer inventories and production schedules. If manufacturers rapidly increase output in response to stronger export orders, but the additional production encounters weaker export demand after October, inventories could begin building again and amplify downward price pressure. Third, order divergence among different cell formats. High-efficiency products and formats better suited to export demand may remain relatively firm, while more abundantly supplied products primarily serving the domestic market could feel pricing pressure from module makers earlier. Overall, the impact of the current Section 232-driven market on China’s solar cell sector can be summarized as “near-term export-led destocking, a shift in demand drivers around October, and a return to domestic fundamentals in Q4.” With traders still driving a significant share of high-priced procurement and module producers yet to broadly accept current cell prices, the rally remains clearly cyclical and structural in nature. As the front-loading window narrows after mid-October, the risk of a correction in solar cell prices is likely to rise materially.