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New Fortress slashes 2025 'Fast LNG' production

  • Market: Natural gas
  • 01/03/23

New Fortress Energy has severely cut its forecast LNG output from the development of new Fast LNG (FLNG) liquefaction units, expecting just one unit to be operational from mid-2023 to 2025 compared with around five previously.

The firm expected output from FLNG projects under development to rise to 63 trillion Btu/yr (1.2mn t/yr) in 2024-25, up from 29 trillion Btu (555,400t) in 2023. This is well down from previous estimates for an increase to 350 trillion Btu (6.7mn t) for 2025 in the firm's third-quarter 2022 results published in November (see table).

The latest figures suggest that only one 70 trillion Btu/yr (1.4mn t/yr) FLNG unit would be operational from mid-2023 to 2025, which is likely to be located at Mexico's Altamira, where New Fortress expects first LNG in July and the start of commercial operations in August.

The firm previously said in November that it expected the first unit at its planned FLNG project in the US' Louisiana to begin operations in late 2023. It then anticipated a further FLNG unit to be deployed at the site by early 2024. And New Fortress has previously said that it planned to add a third unit in Louisiana.

Supply from other sources was revised upwards, but only by 7 trillion Btu (134,000 t) to 121 trillion Btu (2.3mn t) for 2024-25. This leaves expected total liquefaction output from New Fortress 17 trillion Btu (326,000 t) lower than previously expected in 2023, 152 trillion Btu (2.9mn t) less in 2024 and down by 280 trillion Btu (5.4mn t) for 2025.

New Fortress was not immediately available for comment.

New Fortress expected liquefaction, 2023-25trillion Btu
202320242025
Nov '22 output forecast
Current supply114114114
FLNG volumes47222350
Total161336464
New output forecast
Current supply114121121
FLNG volumes296363
Total144184184
Difference
Current supply077
FLNG volumes-18-159-287
Total-17-152-280

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12/03/25

Brazil's Marquise Ambiental invests in 6 RNG plants

Brazil's Marquise Ambiental invests in 6 RNG plants

Sao Paulo, 12 March (Argus) — Brazilian landfill company Marquise Ambiental will invest R400mn ($68mn) in six biogas plants with an estimated total output of around 40.8mn m³/yr. The six plants will be in southeastern Sao Paulo state, northeastern Ceara and Rio Grande do Norte states, and northern Rondonia and Amazonas states, the company said. The Amazonas state plant, in the capital Manaus, is set to produce up to 18mn m³/yr of biogas and should prevent 300,000 metric tonnes (t) of CO2 equivalent (CO2e) from being released into the atmosphere. The Sao Paulo plant is forecast to produce 4.6mn m³/yr, while the Ceara plant is set to produce 2.8mn m³/yr. Meanwhile, the Rio Grande do Norte state plants, Braseco and Potiguar, are forecast to have output of 9mn m³/yr and 4mn m³/yr, respectively. The Rondonia plant is set to have an output of 2.1mn m³/yr, according to the company. The investment will happen in the next three years, but the company did not disclose when operations at each plant will begin. Marquise Ambiental has one 36.5mn m³/yr plant operating in Ceara , dubbed GNR Fortaleza. It is a joint venture between the firm and gas company Ecometano. By Maria Frazatto Planned Marquise biogas plants m³/yr Name State Capacity Osasco Sao Paulo 4,687,000 Braseco Rio Grande do Norte 9,007,000 Potiguar Rio Grande do Norte 4,097,000 Aquiraz Ceara 2,853,000 Manaus Amazonas 18,092,000 Porto Velho Rondonia 2,160,000 Total 40,896,000 Marquise Ambiental Send comments and request more information at feedback@argusmedia.com Copyright © 2025. Argus Media group . All rights reserved.

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Low gas storage bookings may drive German stockdraw


12/03/25
News
12/03/25

Low gas storage bookings may drive German stockdraw

London, 12 March (Argus) — Low gas storage bookings for gas year 2025-26 may already be driving withdrawals and may continue to do so in the coming months. German stocks were at about 79.8TWh on Tuesday morning, filling 31.8pc of capacity. That was well below the 131TWh three-year average for this date and the 171TWh in storage a year earlier. Stronger withdrawals this winter were at least partly driven by higher heating demand as well as slower European imports of LNG and Russian pipeline gas compared with a year earlier. But market dynamics for upcoming storage years may also be encouraging withdrawals. A backwardated forward curve, with prompt prices holding substantially higher than contracts in winter 2025-26 and further along the curve, has incentivised the stockdraw over maintaining stocks. That said, prices for the summer quarters have risen above the prompt recently, so some firms could have a slight incentive to keep gas in storage past the end of this storage year. But the inverted THE summer-winter spread has disincentivised capacity bookings for the upcoming storage year. Summer prices holding above winter prices removes the commercial incentive to inject or book storage space profitably. And storage operators have struggled to sell space in recent months, with many auctions closing unsuccessfully as bidders cannot profitably hedge injections for the contract period. In the prevailing environment, only about 55pc of all German storage space has been booked for the 2025-26 storage year, leaving at least 103.5TWh of capacity unallocated, data show ( see data and download ). By contrast, firms had booked 99.7pc of German capacity for the 2024-25 storage year. Storage sites with low or no bookings might be driving withdrawals, as firms near the end of some storage contracts. At sites where some capacity is booked for the next storage year, firms could sell their stocks to other capacity holders if there is no financial incentive for withdrawing it. But at the six sites with no 2025-26 bookings yet — Rehden, Wolfersberg, Harsefeld, Frankenthal, the VNG-operated Jemgum caverns and SEFE's Speicherzone Nord — firms cannot sell gas in-store as there are no available buyers to transfer gas-in-store to, incentivising firms to empty stocks ahead of the summer 2025 filling season. Consequently, sites with no booked capacity for the upcoming storage year currently are filled less than most other German sites ( see graph ). The remaining sites suggests a correlation between 2025-26 bookings and stocks, as sites with a lower proportion of capacity booked for the next storage year tend to be less full, following stronger withdrawals this winter ( see withdrawals trajectory graph ). Stock dilemma Before the 2024-25 storage year ends on 31 March, any capacity holder left with stocks must decide either to withdraw that gas or sell it to a company holding 2025-26 capacity, if there is sufficient storage space booked at the individual site. Barring additional capacity sales, that suggests that about 7TWh may need to be withdrawn on contractual grounds alone, not accounting for weather or withdrawals from fully-booked sites. About 5.6TWh of that is stored at Rehden, Germany's largest storage site, whose operator SEFE Storage allows capacity holders to withdraw 10pc of their stocks up to two months after the storage year ends . Rehden was filled to 12.1pc of capacity on Tuesday morning, leaving about 1TWh to be withdrawn even if all capacity holders utilise that 10pc allowance. Four of the six sites with no 2025-26 bookings are depleted fields or aquifers, which have lower withdrawal and injection rates than salt caverns and offer capacity holders less flexibility to react to unusual price spreads. Caverns often offer faster injection and withdrawal speeds, so could still be used economically in summer by, for example, reacting to price volatility rather than seasonal spreads. Faster cycling also allows cavern capacity holders to wait longer before starting pre-winter injections, potentially allowing them to wait until the summer-winter spread normalises before injecting. Slower-cycling sites such as aquifers and depleted fields are usually drawn down more consistently in winter as their slower injections and withdrawals reduce their flexibility. That said, some operators might need to inject into caverns to maintain their structural integrity. This might stop withdrawals or possibly support a minimum of injections ahead of or early in the filling season. German storage operator Uniper Energy Storage bought some gas to store as de-facto cushion gas at its Etzel EGL and Etzel ESE sites last week to comply with German law. Restrictions on minimum pressure are enforced by mining authorities and can differ by site, storage operators have told Argus . By Lucas Waelbroeck Boix and Till Stehr Storage bookings next year vs current fill level % Fill level trajectories grouped by site type % Send comments and request more information at feedback@argusmedia.com Copyright © 2025. Argus Media group . All rights reserved.

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US gas CEOs declare victory over energy transition


12/03/25
News
12/03/25

US gas CEOs declare victory over energy transition

Houston, 12 March (Argus) — The energy industry is finally recognizing that more renewable resources will not deter demand growth for natural gas anytime soon, the chief executives of major US natural gas and LNG producers said today. Two years ago, renewables were the principle talking point of the energy industry, said Michael Smith, chief executive of Freeport LNG, at the CERAWeek by S&P Global conference in Houston, Texas. "That has completely changed," Smith said. "There is a recognition within the industry that the energy transition is not going to be using natural gas just as a bridge fuel." That recognition comes from growing overseas demand for US LNG, the desire by countries to convert coal-fired power generation to gas-fired generation, and more recently, booming power demand by planned data centers to run artificial intelligence software, said Toby Rice, chief executive of EQT, the second-largest US gas producer by volume. But despite growing demand, environmental and local opposition to the construction of new US interstate gas pipelines poses a challenge to the industry's ability to produce and transport enough gas to fulfill that demand, Rice said. "The biggest challenge that's facing our industry is this pipeline cancellation movement," Rice said. Construction of interstate gas pipelines in the US has become difficult in recent years as environmentalists and landowners pressure state governments to withhold air and water quality permits needed for those projects. Rice's controversial 2 Bcf/d (57mn m³/d) Mountain Valley Pipeline (MVP), which connects gas fields in West Virginia with markets 300 miles away in Virginia, is the only major greenfield interstate gas pipeline project in the eastern US that has overcome legal opposition in recent years. It was allowed to bypass federal permitting hurdles through an agreement in 2023 between former President Joe Biden and Republicans to raise the limit on the federal debt, provoking outrage from environmental groups and some Democrats. The pipeline began service in June 2024, six years behind schedule and with a price tag of $7.85bn, compared to an original estimate of $3.5bn. MVP "is a piece of infrastructure that they said was not needed", even though the pipeline was operating at maximum capacity this winter, Rice said. "Everybody should be incredibly concerned that it takes an act of Congress to get a pipeline built in this country." 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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Trump to declare power 'emergency' in some states


11/03/25
News
11/03/25

Trump to declare power 'emergency' in some states

Washington, 11 March (Argus) — President Donald Trump said today he intends to declare a "National Emergency on Electricity" in states that could be affected by Ontario's imposition of a 25pc surcharge on electricity exports and further threat to cut off exports entirely. The emergency declaration will allow the US to alleviate the "abusive threat" from losing electricity imports from Canada, Trump wrote in a post on social media. Trump said in response to the surcharge, he would double existing tariffs on Canadian steel and aluminum , and warned Canada that it would pay a high cost if Ontario cuts off the flow of electricity to the US. "Can you imagine Canada stooping so low as to use ELECTRICITY, that so affects the life of innocent people, as a bargaining chip and threat?" Trump wrote. "They will pay a financial price for this so big that it will be read about in History Books for many years to come!" On Monday, Ontario put a 25pc fee on its electricity exports to New York, Michigan and Minnesota in response to Trump's tariffs on Canada. Ontario premier Doug Ford said he was applying "maximum pressure" on the US over its tariff war, and threatened to cut off exports entirely if Trump increased tariffs further. Ontario was the largest exporter of electricity to the US in 2023, sending 15.2 TWh to the US. Trump already declared a national energy emergency on 20 January, unlocking emergency authorities to fast-track permitting and seek to retain production of baseload power plants. Trump has yet to offer more details on the electricity emergency, but the US Department of Energy (DOE) can issue emergency orders that would allow power plants to run at maximum capacity or waive some environmental regulations. DOE did not immediately respond to a request for comment. The New York Independent System Operator, which runs the state's electric grid, said it was analyzing the effects of Ontario's orders and expects to have "adequate reserves to meet reliability criteria and forecast demand for New York." By Chris Knight Send comments and request more information at feedback@argusmedia.com Copyright © 2025. Argus Media group . All rights reserved.

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EU push for tighter gas trading control faces criticism


10/03/25
News
10/03/25

EU push for tighter gas trading control faces criticism

London, 10 March (Argus) — Several industry associations have expressed concerns about the European Commission's intentions to toughen oversight over gas derivatives markets. Gas is a focus point of the commission's consultation launched in late February to assess trading practices in derivative commodity markets, as part of its clean industrial deal strategy. Several industry associations have pushed back against the commission's plans, arguing that gas derivatives markets provide liquidity and facilitate hedging for physical trades. Energy derivatives markets "play a crucial role in providing stability instruments" to allow the efficient management of price risks in volatile energy markets, the association of European energy exchanges Europex said. A central element of the consultation is the introduction of different position limits for physically-settled and cash-settled derivatives, in line with the laws governing futures trading at the US' Henry Hub. The commission also asks participants whether position limits should be differentiated depending on the type of trader or trading activity. Introducing broad position limits could significantly reduce market liquidity and make it harder for companies to manage risk, trade association Eurogas told Argus . "Position limits should only be considered for highly liquid benchmark contracts and should include a well-designed hedge exemption." The association also "strongly cautions against narrowing" the ancillary activities exemption (AAE). The AAE exempts energy from conduct and prudential rules applicable to investment firms for which gas derivatives trading is supplementary to their main commercial business. Ending the exemption "would likely reduce market participation, increase market concentration, and raise costs for end consumers", Eurogas warned. Eurogas argues that the existing regulatory framework already provides "extensive oversight". Fellow industry group Energy Traders Europe also advises against the end of the exemption, telling Argus that it would hamper liquidity and reliability of physical and financial energy trading markets. The commission is gathering comments regarding the creation of a database gathering all open positions held by market participants. Eurogas encouraged the commission to carefully assess any new reporting requirements to prevent unnecessary administrative burdens. Energy Traders Europe said that it is still considering its stance on position limits and the database idea, in general regulatory changes should be thoroughly reviewed "before potentially costly and counterproductive measures are implemented". Former European Central Bank (ECB) president Mario Draghi raised concerns about the disruptive effect of mounting activity and speculation in the gas derivatives market in a landmark report published in September . Most of Draghi's proposals to tighten supervision are included in the consultation. Financial institutions such as hedge funds have increased their participation in gas trading markets in recent years, as greater price volatility opened up new arbitrage opportunities. Investment funds' net long TTF position on the Intercontinental Exchange reached an all-time high of nearly 273TWh by 15 November . Net long TTF positions held by these funds have since fallen significantly in recent weeks following a drop in European gas prices. By Isabel Valverde Send comments and request more information at feedback@argusmedia.com Copyright © 2025. Argus Media group . All rights reserved.

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