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Mexico’s Sep inflation slows with energy prices

  • Market: Agriculture, Coal, Crude oil, Metals, Natural gas
  • 10/10/24

Lower energy prices supported an easing in Mexico's consumer price index (CPI) in September for a second consecutive month.

The CPI slowed to an annual 4.58pc in September, down from 4.99pc in August, Mexico's statistics agency Inegi said on 9 October.

This was lower than both Mexican bank Banorte's own 4.59pc estimate and its analysts' consensus estimate of 4.61pc.

Energy inflation eased for a second month, dropping to 6.9pc from 7.9pc in August and 9.2pc in July, with LPG prices — the largest component — slowing to 14.7pc in September from 16.8pc in August and 25.6pc in July.

Seasonal rains, now ending, have largely reversed the price spikes in farm goods caused by extreme drought earlier this year, with fruit and vegetable inflation slowing to 7.65pc in September from 12.6pc in August, making it the first single-digit rate since November 2023.

"Despite the positive performance of agricultural items since August, lingering risks could turn them negative again," Banorte said in a note, emphasizing that above-normal rainfall will be needed in the coming months to avoid a return to drought and price spikes next year.

For now, Mexican weather agency Conagua still estimates relatively heavy rains in October, but "more adverse" conditions for November and December, with no state forecast to exceed the upper range of historical rainfall.

Core inflation, which strips out volatile food and energy, eased in September to 3.9pc from 4pc, moving within the central bank's 2pc to 4pc target range for the first time since February 2021.

Inside core, said Banorte, packaged and manufactured goods continue to improve, standing at 2.9pc from 3pc in August. Services also moderated, adjusting to 5.1pc from 5.2pc. "A downward trend in the latter is needed to corroborate additional gains for the core," Banorte said. "This will still take some time, especially given that the margin for additional declines in goods may be running out."

The Mexican bank added that within this context, it maintains its estimate for full-year 2024 core inflation to hold to 3.9pc.

Though less weighted than core inflation, the bulk of September's easing in the headline was due to non-core inflation, including prices on more volatile items such as fuels and farm goods. Inegi reported non-core moving to 6.5pc in September from 8pc in August.

Despite two months of better-than-expected price improvements, Banorte warned that "risks remain," with energy prices susceptible to gains amid "geopolitical tensions in the Middle East and economic stimulus in China."

Still, there is "room to adjust gasoline subsidies" to cushion these effects, it added.

By James Young


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21/05/25

Phillips 66 shareholders split board vote

Phillips 66 shareholders split board vote

Houston, 21 May (Argus) — Activist hedge fund Elliott Investment Management is set to win two seats on Phillips 66's board of directors, short of its goal of four seats, according to preliminary results. Two Phillips 66 nominees were also elected in the vote, a positive result for the US refiner and midstream operator. Elliott, which has amassed a $2.5bn stake in Phillips 66, had put forth four nominees for the board in a proxy fight which culminated today at an annual meeting of shareholders. Both sides declared victory after the split vote on the four open seats. Phillips 66 said the vote reflects a belief in its integrated strategy of holding assets in different sectors, while Elliott said the vote "sends a clear message" that shareholders demand meaningful change at Phillips 66. The two Elliott nominees elected to the 14-member Phillips 66 board are Sigmund Cornelius, former chief financial officer of ConocoPhillips and Michael Heim, former chief operating officer of Targa Resources, according to preliminary voting results. The two Phillips 66 nominees elected to the board are Nigel Hearne, a 35-year veteran of Chevron, and Robert Pease, a former Motiva and Cenovus downstream executive who was appointed to the board in 2024 to address Elliott's concerns about a shift in focus from refining to midstream. Phillips 66 also said today that shareholders "overwhelmingly" rejected an Elliott proposal requiring annual director resignations, according to the preliminary results. The voting tally will be tabulated and certified by an independent inspector and final results will be reported to the US Securities and Exchange Commission. The two Elliott nominees for the Phillips 66 board who were not elected are Brian Coffman, former chief executive at Motiva, and Stacy Nieuwoudt, former energy analyst at Citadel. The two Phillips 66 nominees to the board that were not elected are current director John Lowe, who was up for re-election, and Howard Ungerleider, a former Dow president and chief financial officer. Long-running battle over direction Elliott contends that Phillips 66 has consistently trailed its industry peers and needs to streamline operations, including spinning off or selling its midstream business, selling its 50pc stake in Chevron Phillips Chemical (CPChem), and possibly other assets. Elliott has waged an aggressive campaign, launching a website dubbed "Streamline 66" with power point presentations, podcasts, biographies of its dissident board nominees, press releases and information on how shareholders can vote. Phillips 66 has told shareholders that its board and management team are implementing a transformative strategy that has delivered results. The company has expanded its NGL business, improved its refining cost structure and continues to position CPChem as the lowest cost producer of ethylene, Phillips 66 said. Phillips 66 told shareholders that Elliott was pushing "an aggressive short-term agenda" that would cause disruption, slow momentum and jeopardize shareholders' investment capital. Phillips 66 has made some adjustments since Elliot started to agitate for change. In addition to adding Pease to the board, the company recently agreed to sell off some of its European retail business , and expects about $1.6bn in pre-tax cash proceeds from the sale that it will use toward debt reduction and shareholder returns. But the refiner has resisted the other major Elliott recommendations to divest its midstream business and sell its 50pc share of CPChem, saying earlier this month that the Phillips board has evaluated them and "came to the conclusion that neither action is in the best interest of long-term shareholders at this time". Meanwhile, Chevron has advised Phillips 66 of its interest in acquiring the other half of CPChem "at a reasonable value for both parties", Chevron chief executive Mike Wirth said on 2 May. Three top shareholder advisory firms [backed the Elliott nominees] (https://direct.argusmedia.com/newsandanalysis/article/2687988) in the proxy fight. Institutional Shareholder Services (ISS) and Egan-Jones recommending all four of Elliot's dissident nominees, while Glass Lewis backed three of the four. By Eunice Bridges Send comments and request more information at feedback@argusmedia.com Copyright © 2025. Argus Media group . All rights reserved.

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Nigeria's Dangote to import 9mn bl WTI crude in June


21/05/25
News
21/05/25

Nigeria's Dangote to import 9mn bl WTI crude in June

London, 21 May (Argus) — Nigeria's 650,000 b/d Dangote refinery has bought 9mn bl of US light sweet WTI for delivery in June, according to traders, the most for any month since it started up in early 2024. Trading firm Vitol sold three 2mn bl shipments, and trading firm Petraco sold one 2mn bl cargo and a Suezmax-sized shipment. Only one 2mn bl cargo of WTI has arrived at Dangote in May to date, after three in April, according to Vortexa. Dangote was built to run Nigerian crude, but its share of local grades has been 50pc or less in recent months. Nigeria's state-run NNPC allocated six June-loading cargoes to Dangote — two of medium sweet Escravos, and one each of light sweet grades Brass River, Bonny Light, Okwuibome and Yoho — for a maximum of 6mn bl. Market participants expect NNPC to slightly increase its official crude formula prices for June supplies, which should surface before the end of May. Even small increases to official prices would erode the appeal of Nigerian grades compared with WTI. WTI for front-month delivery averaged a 90¢/bl premium to North Sea Dated on a delivered-Europe basis in the 1-20 May period. The deals to Dangote were struck at similar levels on a delivered-Nigeria basis, although price levels were unconfirmed. Escravos' official price was a $1.63/bl premium to Dated for May, and Bonny Light was 48¢/bl above the benchmark on a fob basis — already close or higher than delivered WTI prices, without freight. Dangote has provided an outlet for US light sweet crude at a time of subdued demand from Europe. Around 1.5mn b/d of WTI is booked to arrive to Europe in June, which is lower than typical amounts, according to traders. Tracking data do not always capture the amount of WTI accurately. Relatively cheap Caspian CPC Blend has been weighing on European demand for WTI, according to traders. The Caspian light sour grade has been on average $3.20/bl cheaper on a cif Augusta basis than WTI on a cif Rotterdam basis in May to date. Taking CPC Blend to northwest Europe would incur some additional freight costs, and narrow its discount relative to WTI, but the grade would be still priced below the US crude. Europe is grappling with a glut of light crude grades, partly because of far higher Kazakhstan production an muted Asia-Pacific demand for it, as well as lower demand in Europe due to permanent closures of some refineries. By Lina Bulyk and Sanjana Shivdas Send comments and request more information at feedback@argusmedia.com Copyright © 2025. Argus Media group . All rights reserved.

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IEA warns of lithium and copper deficits by 2035


21/05/25
News
21/05/25

IEA warns of lithium and copper deficits by 2035

London, 21 May (Argus) — The Paris-based IEA has warned that global deficits of copper and lithium by 2035 could be exacerbated in some regions owing to concentration of supply and refining, leading to a potential "Opec moment" for critical minerals. In its new Global Critical Minerals Outlook report, the IEA said lithium could see a 40pc deficit by 2035, even if all current projects proceed, while copper is expected to reach a 30pc deficit by the same year. "Diversification is the watchword for energy security, but the critical minerals world has moved in the opposite direction in recent years, particularly in refining and processing," the report's executive summary said. "The average market share of the top three refining nations of key energy minerals rose from around 82pc in 2020 to 86pc in 2024 as some 90pc of supply growth came from the top single supplier alone: Indonesia for nickel and China for cobalt, graphite and rare earths." In the lithium market, demand tripled from 2020 to 2024, and will triple again by 2035. By then, the electric vehicle (EV) sector will make up 90pc of additional demand while 95pc of future demand growth comes from battery applications: EVs, grid-scale energy storage and battery backup systems, reaching 3.7mn t LCE by 2035. Three countries — Australia, China and Chile — will control up to 69pc of lithium mining by 2030, while China is expected to control 62pc of refining by the same year. "China extracts only 22pc of lithium — but controls 70pc of global refining and 95pc of hard-rock lithium processing," the report said. The copper market is also expected to grow rapidly, supporting the energy transition, but underinvestment and dwindling resource quality will limit supply. Copper demand rises by 30pc by 2040 under the IEA's base-case (STEPS) scenario, up from 27mn t in 2024 to 34mn t by 2040. The IEA predicts a sharp deficit in supply by 2035, up to a 30pc deficit in primary supply. China is expected to dominate refining of copper, responsible for 47pc in 2030. The report said investment of up to $150bn-180bn is needed to keep pace with the global energy transition. "Despite strong copper demand from electrification, the current mine project pipeline points to a potential 30pc supply shortfall by 2035 due to declining ore grades, rising capital costs, limited resource discoveries and long lead times," the report said. By Thomas Kavanagh Send comments and request more information at feedback@argusmedia.com Copyright © 2025. Argus Media group . All rights reserved.

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Thailand's Banpu adopts biomass co-firing in China


21/05/25
News
21/05/25

Thailand's Banpu adopts biomass co-firing in China

Singapore, 21 May (Argus) — Thailand's mining and power generation conglomerate Banpu plans to adopt biomass co-firing for all its combined heat and power plants (CHPs) in northern China. It has fully implemented 10pc biomass co-firing at its coal-fired Zhengding power plant. The plant has a total installed capacity of 139MW electrical (MWe), including a power generation capacity of 73MW and steam production output at 370 t/hr. The type of biomass used at this plant could not be immediately ascertained, and Banpu did not respond to a request for comment. Banpu's Zouping CHP, with a combined capacity of 233MWe, 125MW of power and steam output at 600 t/hr, is "undergoing commissioning", the company said. Its plans to co-fire with biomass at the 246MWe Luannan coal-fired plant is in the "bidding phase," the company added. The plant has a power capacity of 150MW and steam production output at 538 t/hr. The move to boost biomass co-firing at its operations in China is part of the company's plans to reduce carbon emissions and earn revenue from carbon emission allowances (CEAs)— a type of carbon credit or emission permit, giving rights to emit a certain amount of greenhouse gases within a carbon market. CEAs are part of a "cap-and-trade" system, designed to reduce overall emissions. Higher earnings from CEAs from its Chinese plants and cost management in the coal business lifted its net profit in the first quarter. Banpu reported a net profit of 574mn baht ($17.3mn) before interest, taxes, depreciation and amortisation in the first quarter, up by 19pc from the same period in 2024. By Nadhir Mokhtar Send comments and request more information at feedback@argusmedia.com Copyright © 2025. Argus Media group . All rights reserved.

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US gas market expected to tighten in 2026


20/05/25
News
20/05/25

US gas market expected to tighten in 2026

New York, 20 May (Argus) — US natural gas producers and analysts are forecasting a tighter market in 2026 than previously expected because of rising LNG exports, a slowdown in crude production and a reluctance on the part of gas-focused producers to ramp up supply. The market has already tightened this year as cold winter weather balanced the previously oversupplied domestic market and Venture Global's Plaquemines LNG terminal ramped up faster than expected. Nymex gas delivery for 2026 at the US benchmark Henry Hub settled Tuesday at $4.30/mmBtu, up from $3.91/mmBtu at the start of the year. US LNG exports are expected to rise by 19pc to 14.2 Bcf/d this year, followed by a 15pc increase to 16.4 Bcf/d in 2026, the US Energy Information Administration forecasts. Meanwhile, tariff-induced economic uncertainty and plans by Opec+ to boost supply have lowered crude prices this year, which will probably throttle growth in the Permian basin, a prolific US oil field in west Texas and southeast New Mexico that accounted for 22pc of US gas supply in 2024. US onshore crude production has likely peaked as activity slows in response to the recent decline in oil prices, Diamondback Energy chief executive officer Travis Stice said earlier this month. US producer Antero Resources this week forecast a 5.5 Bcf/d supply growth shortfall from 2025-26 as producers fail to keep up with booming LNG exports, pipeline sales to Mexico and rising gas-fired power demand. Producers have so far been reluctant to ramp up activity in the Haynesville shale basin of east Texas and northwest Louisiana, the major marginal gas supplier to the US market and a key supplier to the coming wave of new US LNG export terminals, all of which are sited in Texas and Louisiana. Producers' hesitation might be linked to past experience, when they ramped up output for new LNG terminals only for those terminals' in-service dates to get pushed back, contributing to an oversupplied market that depressed prices. Haynesville operators' lack of response to higher gas prices in the first quarter of this year led analyst group Enverus to raise its 2026-30 US gas price forecast to $4/mmBtu. Some producers, including EQT, the second-largest US gas producer by volume, are holding off on locking in the elevated prices for 2026 production with financial derivatives, in part because they want exposure to the possibility of even higher prices. Those producers are "playing a little bit of a dangerous game", according to FactSet senior energy analyst Connor McLean. If a mild summer or delayed LNG terminal start-ups reverse expectations of a tighter market, producers might enter a weaker market in 2026 having "missed their chance" at more opportunistic hedges, McLean said. US LNG out the window Tudor Pickering Holt last week raised its "2026 base case forecast" for US gas prices from $4/mmBtu to $5/mmBtu. The Houston-based investment bank expects the US gas market to shift to a state of "material undersupply" in 2026, potentially pushing domestic prices so high that the price of producing LNG from US gas would exceed prevailing global LNG prices. Aside from short-term price spikes caused by storms or maintenance events, this would be the first instance of the US gas-to-global LNG price "arbitrage window" closing since pandemic-induced demand destruction caused more than 175 US LNG cargoes to be cancelled from April-November 2020, according to consultancy McKinsey. Energy Aspects head of North American gas David Seduski said he would not rule out the possibility of high US gas prices reducing exports, but that is not his "base case". According to Seduski, Europe is "in such desperate need of gas" that in the absence of some geopolitical development that boosts Russian gas sales to Europe, high US gas prices would probably just spur higher European gas prices and keep US sales to the continent profitable. Henry Hub prices would probably have to exceed $7/mmBtu given current global gas prices for US LNG cargoes to start being cancelled, FactSet's McLean said. By Julian Hast Send comments and request more information at feedback@argusmedia.com Copyright © 2025. Argus Media group . All rights reserved.

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