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Mexico industrial production contracts in March

  • Spanish Market: Crude oil, Metals, Oil products
  • 13/05/25

Mexico's industrial production contracted by 0.9pc in March from the previous month, as declines in mining and manufacturing were only partly offset by continued growth in construction.

The drop was not enough to undo the 2.2pc increase in February — the sharpest monthly expansion in four years — as manufacturers ramped up output ahead of incoming US tariffs.

The March industrial production index (IMAI), published by statistics agency Inegi, was higher than Mexican bank Banorte's forecast of a 1.4pc decline. Banorte noted signs of volatility affecting manufacturing and other sectors because of a complex trade outlook.

Manufacturing contracted 1.1pc in March after expanding 2.9pc in February. The impact varied across subsectors, with metal goods down 5.5pc and transportation, including auto production, down 1.1pc.

Volatility may ease in the coming months as US tariff policies become clearer and Mexican officials push to preserve the country's trade edge under US-Mexico-Canada (USMCA) free trade agreement rules, Banorte said.

Construction expanded 0.8pc in March, following increases of 3.4pc in February and 0.5pc in January, driven by higher public investment tied to President Claudia Sheinbaum's economic plan, "Plan Mexico."

Analysts see the plan as a catalyst for continued growth in construction this year, with measures including greater domestic content in public purchases, public-private participation in infrastructure projects and a target of $100bn in private infrastructure investment for 2025. These effects could be amplified by aggressive interest rate cuts from the central bank.

Mining contracted by 2.7pc in March, returning to negative territory after a slight 0.1pc uptick in February. Oil and gas output also contracted 2.7pc after rising 1.0pc the month before, while non-oil mining contracted 4.3pc in March after a 0.6pc increase in February.


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12/06/25

EPA readies new biofuel blend mandate proposal

EPA readies new biofuel blend mandate proposal

New York, 12 June (Argus) — President Donald Trump's administration is close to releasing two regulations informing oil refiners how much biofuel they must blend into the conventional fuel supply. The two rules — proposed biofuel blend mandates for at least 2026 and most likely for 2027 as well as a separate final rule cutting cellulosic fuel mandates for last year — exited White House review on Wednesday, the last step before major regulations can be released. Previously scheduled meetings as part of the process appear to have been cancelled, another signal that the rules' release is imminent. The Environmental Protection Agency (EPA) has said it wants to get the frequently delayed Renewable Fuel Standard program back on its statutory timeline, which would require volumes for 2027 to be finalized before November this year. Any proposal will have to go through the typical public comment process and could be changed. A coalition of biofuel-producing groups and feedstock suppliers, including the American Petroleum Institute, has pushed EPA to set a biomass-based diesel mandate of 5.25bn USG for 2026, hoping that a record-high target will support biorefineries that have struggled this year. Many plants have idled or run less recently, as uncertainty about future blend mandates, the halting rollout of a new clean fuel tax credit, and tariffs that up feedstock costs all hurt margins. EPA administrator Lee Zeldin also told a House subcommittee last month the agency wanted "to get caught up as quickly as we can" on a backlog of small refiner requests for program exemptions. Courts took issue with EPA's exemption policy during Trump's first term and again during President Joe Biden's tenure, leaving officials now with dozens of waiver requests covering multiple compliance years still pending. It is unclear whether the rule will provide clarity on EPA's plans for program waivers — including whether the agency will up obligations on other parties to make up for exempt small refiners — but biofuel groups have worried that widespread exemptions would curb demand for their products. The price of Renewable Identification Number (RIN) credits used for program compliance have been volatile this year on rumors about these exemptions, which EPA has called market manipulation. RIN trading picked up and prices rose on the news as Thursday's session began. Bids and offers for 2025 ethanol D6 RINs, the most prevalent type currently trading, began the day at 96¢/RIN and 98¢/RIN, respectively. Deals were struck shortly after at 98¢/RIN and 99¢/RIN, with seller interest at one point reaching 100¢/RIN — well above a 95.5¢/RIN settle on Wednesday. Biomass-based diesel D4 RINs with concurrent vintage followed the same path with sellers holding ground as high as 107¢/RIN. By Cole Martin and Matthew Cope Send comments and request more information at feedback@argusmedia.com Copyright © 2025. Argus Media group . All rights reserved.

UK ETS emissions fell by 11pc on the year in 2024


12/06/25
12/06/25

UK ETS emissions fell by 11pc on the year in 2024

Seville, 12 June (Argus) — Emissions in sectors covered by the UK emissions trading scheme (ETS) declined by 11.5pc year on year in 2024, data published by the UK ETS authority show, slowing their decline slightly from the previous year. Stationary installations covered by the UK ETS emitted 76.7mn t of CO2 equivalent (CO2e), down by 12.9pc from 2023, the data show. But this was offset somewhat by a 2pc increase in aviation emissions to 8.99mn t CO2e. Overall UK ETS emissions now have declined for two consecutive years, having fallen by 12.5pc in 2023. Emissions under the scheme rose by 2.5pc in 2022, as a strong rebound in aviation activity following earlier Covid-19 restrictions outweighed declining stationary emissions. Stationary emissions have decreased in every year since the scheme launched in 2021. The majority of the decline in stationary emissions under the UK ETS last year took place in the power sector, where emissions dropped by 18.2pc to 30.6mn t CO2e. The country's last coal-fired plant, Ratcliffe-on-Soar, closed in September last year. And the share of gas-fired output in the generation mix dipped as wind, solar and biomass production and electricity imports edged higher. Industrial emissions also declined, by 8.9pc to 46.1mn t CO2e. The iron and steel sector posted the largest relative drop of 30pc to 6.54mn t CO2e. Emissions from crude extraction fell by 6.4pc to 6.0mn t CO2e, while emissions from gas extraction, manufacture and distribution activities decreased by 8.9pc to 5.3mn t CO2e. The chemicals sector emitted 2.28mn t CO2e, down by 5.2pc on the year. A total of 43 installations were marked as having surrendered fewer carbon allowances than their cumulative emissions since the launch of the UK ETS, as of 1 May. A further two installations failed to report their emissions by the deadline. "Appropriate enforcement action" will be taken against operators that fail to surrender the required allowances, the UK ETS authority said. Overall greenhouse gas emissions across the UK economy dropped by a smaller 4pc last year, data published by the government in March show. This decline also was driven principally by lower gas and coal use in the power and industry sectors, with smaller declines in transport and agriculture, not covered by the UK ETS, and an increase in buildings emissions, also out of the scheme's scope. Emissions under the EU ETS in 2024 dipped by a projected 4.5pc from a year earlier, based on preliminary data published by the European Commission in April. The UK and EU last month announced that they will "work towards" linking the two systems together. By Victoria Hatherick UK ETS emissions mn t CO2e Send comments and request more information at feedback@argusmedia.com Copyright © 2025. Argus Media group . All rights reserved.

Ice gasoil backwardation widens as supply tightens


12/06/25
12/06/25

Ice gasoil backwardation widens as supply tightens

London, 12 June (Argus) — The premium of front-month Ice gasoil futures against the second-month futures has widened over the past two weeks, reflecting tighter supply. The premium of Ice June futures against the July contract settled at $9.50/t on Wednesday, 11 June. The backwardation — where prompt prices are greater than forward prices — has steepened in the past two weeks, peaking at a premium of $16/t on Tuesday, 10 June, the joint-widest in 14 months along with 11 March. Two weeks ago, on 23 May, the premium settled at $6.50/t. The June contract expires today, which could have contributed to the steepening backwardation as traders close their open positions, according to market participants. But the size of the premium suggests a tightening market. A closed arbitrage from the Mideast Gulf and India since April has reduced supply to Europe, European traders have said. Only 2.97mn t of diesel and other gasoil has arrived in Europe from the Mideast Gulf and India in April and May, according to ship-tracking service Vortexa, compared with about 5.72mn t in the same period last year. The arbitrage has been closed because of relative weakness in European prices compared with those in Singapore. The premium of front-month Ice gasoil futures against Singaporean equivalents averaged $18.65/t in May, compared with $23.81/t in May 2024. Singaporean middle distillate stocks fell to a nine-month low in the week ending 23 April, increasing demand for imports. European diesel values fell sharply at the start of April in response to the implementation of US tariffs, largely because of dampened expectations of industrial performance, and have not recovered. The start of the Mediterranean emissions control area (ECA) at the start of May has also placed strain on European supply of diesel and other gasoil. The ECA requires ships in the Mediterranean to use fuel with a sulphur content of 0.1pc, rather than the previous requirement of 0.5pc. Marine gasoil (MGO) fits the new requirement, as does ultra-low sulphur fuel oil (ULSFO). With supply of the latter limited in Europe, the majority of shipowners have switched to MGO. Refineries have probably increased MGO production to meet this new demand, but MGO supply is still "very tight" , a Mediterranean-based marine fuels trader said. Most of the gasoil used for blending in MGO is suitable for desulphurisation and use as road fuel, and so it diversion into marine fuels restricts supply of diesel. Independently-held inventories of diesel and other gasoil at the Amsterdam-Rotterdam-Antwerp (ARA) hub have dropped since the start of April. The four-week average came to about 2.1mn t on 5 June, lower on the year by 8.5pc, according to consultancy Insights Global. On 3 April the four-week average was 5.1pc higher than a year earlier. A recovery in Rhine river water levels in recent weeks , after lows that restricted barge movement inland from ARA, contributed to the stockdraw. By Josh Michalowski Send comments and request more information at feedback@argusmedia.com Copyright © 2025. Argus Media group . All rights reserved.

Malaysia’s oil, gas projects to emit 4bn t GHG: CREA


12/06/25
12/06/25

Malaysia’s oil, gas projects to emit 4bn t GHG: CREA

Singapore, 12 June (Argus) — Malaysia's continued extraction and use of its oil and gas resources could emit around 4bn t of greenhouse gases (GHGs), according to a report by the Helsinki-based Centre for Research on Energy and Clean Air (CREA). Malaysia holds about 9.84bn bl of oil equivalent (boe) in committed fossil fuel reserves, of which 82pc is gas, stated the report, which was written in collaboration with environmental think-tank RimbaWatch. This figure only includes projects with proven reserves that are covered by a production commitment such as production sharing contracts. These committed reserves would also emit an estimated 4.15bn t of CO2 equivalent (CO2e), which is equivalent to 13 years of Malaysia's annual emissions. The emissions will also consist of 10.9mn t of methane, which is a much more potent GHG than CO2. Malaysia's remaining commercially recoverable reserves are estimated at over 17bn boe over more than 400 fields, with gas comprising about 75pc of this. Malaysia launched its national energy transition roadmap (NETR) in 2023, detailing initiatives to achieve its 2050 net zero carbon emissions target, such as renewable energy development, hydrogen and carbon capture, utilisation and storage (CCUS). The country aims to reduce its economy-wide carbon emissions by 45pc in 2030 compared with 2005 levels, under its nationally determined contribution — climate plan — to meet the goal of the Paris Agreement. But at the same time, the country is seeking to maximise its fossil fuel production to ensure energy security. State-owned Petronas raised its total oil and gas production in 2024 to 2.4mn b/d of oil equivalent (boe/d), up by 1pc on the year. Of this, oil production fell by 4.4pc on the year to 813,000 boe/d, while gas output rose by 3.6pc to 1.64mn boe/d. More than 80pc of Malaysia's power was generated from fossil fuels in 2024. The NETR plans to increase the share of gas in total primary energy supply by 16pc from 2023 to 57pc in 2050, with gas viewed as a transition fuel for decarbonisation. But "referring to gas as sustainable, and claiming that Malaysia can achieve net-zero emissions through growing gas, are oxymorons," stated the report. Petronas' Scope 1 and 2 greenhouse gas emissions totalled 46.04mn t of CO2e across its Malaysian operations in 2024, surpassing its target of 49.5mn t of CO2e for the year. In comparison, the firm recorded 45.6mn t of Scope 1 and 2 GHG emissions in 2023. But the firm's net zero pathway excludes its Scope 3 emissions, which make up about 80pc of a fossil fuel entity's emissions, according to the report. Additionally, its CCUS plans are aimed at enabling sour gas extraction, hence exacerbating fossil fuel production and emissions. Malaysia should instead set a sectoral carbon budget for the domestic energy sector in line with its net zero goals, taking into account both production and consumption, and cement this budget in the country's upcoming Climate Change bill, stated the report. By Prethika Nair Send comments and request more information at feedback@argusmedia.com Copyright © 2025. Argus Media group . All rights reserved.

Philippines axes planned ban on nickel ore exports


12/06/25
12/06/25

Philippines axes planned ban on nickel ore exports

Beijing, 12 June (Argus) — The Philippines has removed a provision in its mineral bill that had banned the export of unprocessed nickel ore. The country's Senate on 3 February had passed a bill to ban unprocessed nickel ore exports by 2030 to promote domestic processing -- mirroring a similar policy in Indonesia. But this was not welcomed by the local industry. The decision to remove the ban was supported by the Philippine Nickel Industry Association (PNIA). "This is a prudent and forward-looking step that protects jobs, upholds investor confidence, and reflects a more realistic understanding of the challenges surrounding domestic mineral processing," PNIA said in a statement. The Philippines exported 44.97mn wet metric tonnes of nickel ore in 2024, up by 10.1pc year on year. Of this, 35.12mn wmt was exported to China, down by 12pc on the year. Indonesia received 9.55mn wmt, up from 215,000wmt it received in 2023. Rising demand and a lower approved mining quota, or RKAB, in Indonesia boosted the country's ore imports from the Philippines. While in China, weak demand resulted in the decline of imports. The Philippines' nickel intermediates output fell by 7.8pc on the year to 414,000t of nickel metal equivalent in 2024. Most of this production came from the Coral Bay and Taganito high-pressure acid leach plants owned by Nickel Asia, according to data from the International Nickel Study Group. Send comments and request more information at feedback@argusmedia.com Copyright © 2025. Argus Media group . All rights reserved.

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