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CBAM 'successfully' in force since start of year: EU
CBAM 'successfully' in force since start of year: EU
London, 14 January (Argus) — The EU's carbon border adjustment mechanism (CBAM) has "successfully" been in force since 1 January, with a combined 1.66mn t of CBAM goods imports declared in the first reporting window on 1-6 January, the European Commission said on 14 January. About 98pc of the volumes were from the iron and steel sectors, 1.2pc from fertilizers, 0.5pc from cement and 0.3pc from aluminium. There were no volumes reported from the power and hydrogen sectors. The top non-EU countries from where such goods were delivered were Turkey, China, India, Canada, Taiwan and Vietnam, the commission said. Belgium, Spain, Romania, the Netherlands, France and Germany were the top importing countries of CBAM goods within the EU on 1-6 January. The "seamless" integration of systems at national and EU level ensured real-time data exchange, efficient validation of declarants and uninterrupted import procedures at EU external borders, the commission said. "National authorities report stable processing times" for CBAM goods at customs, it added. More than 12,000 economic operators submitted an application for CBAM authorisation on 1-7 January and just under 10,500 import customs declarations with CBAM goods were validated automatically and in real time through integrated customs systems during the period, the commission said. It added that over 4,100 CBAM economic operators successfully obtained the authorised declarant status in the EU prior to and immediately after 1 January. The commission urged all economic operators subject to the CBAM to submit their CBAM authorisation application via the CBAM registry "now", stressing that early submission would ensure uninterrupted compliance, access to automated validation and full integration with customs clearance processes. By Erisa Senerdem Send comments and request more information at feedback@argusmedia.com Copyright © 2026. Argus Media group . All rights reserved.
Viewpoint: Coal plant extensions not always easy
Viewpoint: Coal plant extensions not always easy
Houston, 14 January (Argus) — US generators are starting this year with more coal-fired power plants open than previously planned, following a series of US Department of Energy (DOE) emergency orders, but maintaining generation from these facilities might not be easy. Since late May, US energy secretary Chris Wright has signed orders to keep at least parts of five coal plants running beyond their planned 2025 retirement dates. These facilities have a combined generating capacity of 2,128MW. Wright also has indicated he may continue issuing such orders to address near-term reliability issues and potential energy supply shortages in the next few years. While some power plant operators may welcome the orders, others are more reticent. "I think the executive orders make for lots of questions in our current environment," one market participant said. "As with anything, there are lots of legal challenges that will arise, and it all could change again in a few years" under a new administration. The nature of the orders also raises logistical concerns that some power plant operators warned could affect their ability to comply. Last year, Wright issued the orders shortly before the facilities were scheduled to close. That kind of timetable can be challenging for plant operators who typically have spent months winding down fuel orders and making other preparations to permanently close a facility. The orders also have 90-day limits that can be extended, and Wright has not shied away from renewing directives to keep plants operating. Several coal plants that were either scheduled to close recently or are slated to be retired in the near future have not received adequate maintenance and upgrades in the last few years that would allow them to keep running sustainably long-term, one operator told Argus . That suggests operators could face higher rates of unexpected coal unit outages this year or more frequent planned outages as companies catch up on maintenance. For example, unit 1 of the Craig Station coal plant in Colorado, the most recent unit ordered to stay on line for another 90 days, has been out of service since 19 December, following a mechanical failure of a valve. The plant will need repairs and additional investments to continue running into 2026, Tri-State Generation & Transmission — one of the co-owners of the plant — said on 31 December. Some of the utilities that have received emergency orders to keep coal plants open also warned that delaying the facilities' closures could interfere with previous energy transition plans and investments. But Indiana utility NiSource, which received an order to keep its RM Schahfer coal plant on line until at least 23 March 2026, said "our long-term plan to transition to a more sustainable energy future remains unchanged". Other utilities also remain committed to transitioning from coal-fired generation. One operator said the recent emergency orders have merely put the coal industry on "life-support", rather than providing a substantial lifeline beyond the next few years. Many other coal market participants asserted that DOE's orders only require the plants to remain available during their extension periods and, at least so far, have not specified a minimum capacity factor at which they must run. Most of the plants operating in compliance with the emergency orders may just run as peaker plants, only operating at maximum capacity during extreme periods of generation demand. Still, the prospect of keeping the facilities open for an unknown period of time can be a challenge for planning fuel purchases. While some plants that received a DOE order still have a small quantity of coal stockpiled on site, those volumes will only sustain a few more weeks of coal burn, necessitating additional shipments. Other utilities are faced with buying more coal and deciding whether to purchase enough for just the extent of existing orders or to enter into longer-term agreements. Some operators have already opted into multi-year deals because they expect DOE's emergency orders on their plants will keep getting renewed well into the back half of this decade. Many utilities, especially by the end of 2025, found pricing in longer-term purchases to be more stable and economical because constrained supply in most US basins had prompted producers to offer spot coal at higher prices. Tight US coal supply also has led producers to be less willing to agree to options in newer coal contracts that would allow buyers to opt out of taking all of their volume commitments. Because of this, some utilities that have received orders from DOE have limited their additional coal purchases to deliveries only in 2026. Some utilities also said that they can not justify issuing longer-term requests for proposals to state regulators and ratepayers, since the DOE orders are only issued for 90 days. The US House of Representatives in mid-December passed a bill that aims to address some utility concerns. The Power Plant Reliability Act of 2025 would authorize the US Federal Energy Regulatory Commission (FERC) to require an owner or operator to continue running a power plant for up to five more years if the commission finds that its closure could threaten grid reliability. The bill would protect plant operators from penalties for potentially violating state or federal environmental laws while FERC's order is in place. And it would authorize FERC to renew an order by another five years if requested by a transmission organizer, state commission or public utility. The US Senate has not yet scheduled any action on the bill. And even if the measure is enacted, it will only address some of the uncertainties power plant operators face. By Anna Harmon Send comments and request more information at feedback@argusmedia.com Copyright © 2026. Argus Media group . All rights reserved.
Brazil independents look beyond onshore fields
Brazil independents look beyond onshore fields
Sao Paulo, 14 January (Argus) — Adopting tieback practices alongside a more modern, less bureaucratic regulatory framework could transform the role of independent producers in Brazil beyond onshore, replicating the dynamism seen in the Gulf of Mexico. According to the president of Brazil's association of independent oil and gas producers (ABPIP), Marcio Felix, independents are looking beyond their traditional onshore operations — mostly concentrated in the country's northeast — and setting their sights on offshore opportunities, including the pre-salt polygon. Tieback projects, widely used in the Gulf of Mexico, are seen by ABPIP as a game-changer for Brazil's independent sector. This technique connects remote fields or marginal discoveries to existing production units, leveraging idle infrastructure and reducing the need for new FPSOs and processing systems. ABPIP advocates for a streamlined regulatory framework to enable these projects, including flexible fiscal rules, alternative measurement methods, and automatic royalty reductions for incremental production. ABPIP member companies increased production by 19pc in the first half of 2025 and are expected to close the year with growth near 20pc, outpacing Brazil's overall oil and gas production growth, which averaged 14.3pc year-on-year production growth in November 2025, according to hydrocarbons regulator ANP data. This performance underscores the strategic role of independents in boosting supply in more remote areas. Expanding offshore could amplify these benefits —provided regulatory adjustments make the environment more competitive and less bureaucratic. Regulatory agenda to unlock potential To make this vision a reality, ABPIP proposes updates to the current regulatory framework, including: Revising the production-sharing regime in the pre-salt, allowing concessions in less economically attractive areas. Modernizing the Permanent Offer system, with incentives such as lower royalties and flexible exploration phases. Updating SME (small and medium-sized enterprises) classification to reflect current market realities (up to 10,000 boe/day for small and 100,000 boe/day for medium operators). Defining mature and marginal fields clearly, coupled with royalty reductions and streamlined requirements. Advancing full implementation of the Gas Law, ensuring non-discriminatory access to essential infrastructure. Modernizing environmental licensing with defined timelines and risk-based criteria. By Betina Moura Send comments and request more information at feedback@argusmedia.com Copyright © 2026. Argus Media group . All rights reserved.
2025 was among hottest years on record: Global agencies
2025 was among hottest years on record: Global agencies
London, 14 January (Argus) — Global science and weather agencies found that 2025 was either the second- or third-hottest year recorded, according to eight different datasets consolidated by the World Meteorological Organisation (WMO). The global average temperature in 2025 was 1.44°C above pre-industrial levels, with a margin of uncertainty of 0.13°C either higher or lower, according to the synthesis of eight datasets. Of the eight datasets consolidated, two found that 2025 was the second-warmest year in the 176-year record, and the remaining six ranked it as the third-hottest year recorded, the WMO said. The Paris climate agreement seeks to limit the global rise in temperature to below 2°C above the pre-industrial average, and pursues a 1.5°C threshold. The past three years, over 2023-25, are the three hottest years in all eight datasets, the WMO found. The average temperature across 2023-25 was 1.48°C above pre-industrial levels — again with a margin of uncertainty of 0.13°C — the consolidated data show. The average global temperature in 2025 was 15.08°C based on the datasets, but the margin of uncertainty for this is much higher, at around 0.5°C, the WMO said. "The year 2025 started and ended with a cooling La Nina and yet it was still one of the warmest years on record globally because of the accumulation of heat-trapping greenhouse gases in our atmosphere. High land and ocean temperatures helped fuel extreme weather", WMO secretary-general Celeste Saulo said. The La Nina weather pattern typically leads to lower global temperatures, while the El Nino pattern has the opposite effect. These are naturally-occurring. But "the long-term increase in global annual average temperature is driven by the human-induced rise in the concentration of greenhouse gases in the atmosphere", UK Met Office climate scientist Colin Morice said. The WMO collates data from the EU's Copernicus , Japan's Meteorological Agency, the UK's Met Office, the US' National Aeronautics and Space Administration and National Oceanic and Atmospheric Administration, and US non-profit Berkeley Earth. It has also this year used a UK-US dataset, DCENT, and China's Merged Surface Temperature dataset. Science and weather agencies agree that 2024 is the hottest year on record . By Georgia Gratton Send comments and request more information at feedback@argusmedia.com Copyright © 2026. Argus Media group . All rights reserved.
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