

LNG
Overview
LNG's role as a key feedstock is well established as it helps manage both input costs and carbon emissions. Heavy industrial users' drive to achieve net zero targets has added a new dimension to how and where it is being deployed. Overall, its use is expected to increase and is tipped to become the strongest-growing fossil fuel.
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Latest LNG news
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Shell vessel inbound to load LNG Canada’s first cargo
Shell vessel inbound to load LNG Canada’s first cargo
Houston, 27 June (Argus) — A Shell-chartered LNG carrier is set to arrive at the 14mn t/yr (1.87Bcf/d) LNG Canada export terminal in British Columbia late Friday or early Saturday as the facility prepares to load its first cargo. The BC Coast Pilots, responsible for guiding large vessels in and out of the province's ports, received a dispatch to board the 173,400m³ Gaslog Glasgow late 27 June, the pilotage firm told Argus . Two pilots will board the ship near Prince Rupert, and at least one will remain aboard for the voyage to LNG Canada in Kitimat. It will take about nine hours for the vessel to reach the facility from the pilot boarding station, assuming an average speed of 12.5 knots. The Shell-controlled LNG carrier began transiting inbound toward the terminal on 27 June after holding offshore British Columbia since 22 June, according to ship-tracking data from Kpler. A spokesman from LNG Canada did not respond to a request for comment detailing when the first cargo will load or depart the terminal. The plant began cooling the first of its two liquefaction trains on 16 June and produced its first LNG on 22 June. Shell will load the terminal's first cargo because shipments will be loaded in order of equity participation in the project, according to market participants. LNG carriers chartered by two other project stakeholders have declared for arrival at LNG Canada, Kpler data show. The 174,000m³ Puteri Sejinjang , chartered by Malaysian state-owned firm Petronas, and the 174,000m³ Diamond Gas Crystal , chartered by Japanese firm Mitsubishi, have declared arrival on 6 July and 14 August, respectively. By Tray Swanson Send comments and request more information at feedback@argusmedia.com Copyright © 2025. Argus Media group . All rights reserved.
EQT to ‘limit’ hedged volumes to 50pc of its gas
EQT to ‘limit’ hedged volumes to 50pc of its gas
New York, 25 June (Argus) — US natural gas producer EQT only plans to use financial derivatives to lock in prices for half of its output at the most in the coming years, a break from years' past when it was hedging the vast majority of its volumes. The second-largest US gas producer by volume would need to have "conviction" on its outlook for US gas prices in order for it to hedge a full 50pc of its volumes, EQT chief executive Toby Rice told Argus in an interview Wednesday in New York City. "I think that would be a limit," Rice said. EQT remains entirely unhedged for 2026, he said. Without a clear sense of the trajectory of the US gas market — a famously volatile market which has only become more volatile in recent years — EQT believes erring on the side of maximum exposure to spot prices will lead to higher average revenue. EQT made $68mn on its derivatives contracts in 2024 and $1.8bn in 2023, according to federal regulatory filings. This was after losing $4.6bn on derivatives in 2022 after Russia invaded Ukraine, sending US gas prices near $10/mmBtu, heights from which EQT was partly locked out because of its hedges. EQT's unhedged strategy is a departure from when Rice was appointed chief executive in 2019 in a bid by activist investors to overhaul the company's board of directors and change its strategy. At that time, EQT was hedging up to 80pc of volumes, largely due to its higher cost structure, Rice said. But now, with EQT able to break even with US gas prices as low as $2.45/mmBtu — excluding its interest payments on its debt — hedging has become an "entirely opportunistic" tool for EQT, rather than a defensive necessity, he said. The prompt-month settlement price for Nymex gas at the US benchmark Henry Hub so far this month has averaged $3.67/mmBtu. EQT is also able to hedge less of its gas because it has increased the amount of gas it can move to consumers outside its core operating area in Appalachia. EQT sells more than 4.6 Bcf/d directly to end users, including power companies and utilities, local distribution companies and LNG export terminals, according to a confidential investor slide obtained by Argus . Of that, 3 Bcf/d goes to power and utility companies including NextEra Energy, Duke Energy, Southern Company and Constellation Energy; 1 Bcf/d goes to local distribution companies including Illinois-based Peoples Energy, Washington, DC-based WGL Holdings and New Jersey Natural Gas; and 600mn cf/d goes to LNG facilities including Venture Global, Sabine Pass, Cameron LNG and Berkshire Hathaway's Cove Point LNG. Moving gas from Appalachia to population centers elsewhere in the country, where gas prices are higher, has historically been a challenge for Appalachian producers because of opposition from state regulatory agencies to the construction of new interstate pipelines. EQT has been able to overcome this challenge in part by signing long-term supply agreements with southeast utilities Duke and Southern for 1.2 Bcf/d of gas, which will be shipped on EQT's Mountain Valley Pipeline, as Argus reported earlier this month. Gas buyers have become more interested in signing long-term supply deals with EQT as heightened volatility in the US gas market has increasingly lured in commodity traders who act as middlemen, Rice said. Switzerland-based commodity trader Glencore and New York-based quantitative trading firm Jane Street, among others, have been building up a US gas trading presence over the past year. IRA rollback could boost gas demand Rice also sees bright spots for gas amid an effort by Republicans in the US Congress to use a filibuster-proof budget bill to phase out clean energy tax credits from former president Joe Biden's Inflation Reduction Act. If Republicans get their way, this could slow the growth of US renewable energy generation, "easily" boosting US gas demand by 1.5-2 Bcf/d by 2030 as gas takes market share from what would have otherwise been occupied by renewables, Rice said. "If solar and wind investments decrease, that [energy] demand's not going away," Rice said. EQT also expects planned data centers running artificial intelligence software to increase US gas demand by 4-6 Bcf/d over the period, he said. EQT is in discussions with "roughly a dozen proposed power projects" in Appalachia on an expected surge in US power demand, only about 40pc of which stems from planned data centers, Rice said. Rice still expects to announce a gas supply agreement involving one of these projects by the end of the year. By Julian Hast Send comments and request more information at feedback@argusmedia.com Copyright © 2025. Argus Media group . All rights reserved.
Corpus Christi expansion’s train 2 produces first LNG
Corpus Christi expansion’s train 2 produces first LNG
Houston, 25 June (Argus) — The second of seven trains at US LNG producer Cheniere's 11.45mn t/yr (2.3bn ft³/d) Corpus Christi stage 3 expansion in south Texas produced its first LNG on 22 June, a spokesperson confirmed. The stage 3 expansion adds to the existing 17.4mn t/yr Corpus Christi LNG export facility. The first train produced its first LNG in late December and loaded its first cargo in February. Train 2 would load its first cargo in August, if it follows a similar timeline. The seven-train project is expected to ramp up production through 2026, with train 3 on track to begin production in the third quarter and train 4 potentially beginning its commissioning process by the end of the year. Cheniere reached a $2.9bn final investment decision on the 3.3mn t/yr trains 8-9 expansion at the Corpus Christi plant on 24 June. Along with debottlenecking projects, that expansion is expected to add 5mn t/yr of production. By Tray Swanson Send comments and request more information at feedback@argusmedia.com Copyright © 2025. Argus Media group . All rights reserved.
Tight supply slows European injections
Tight supply slows European injections
London, 25 June (Argus) — Europe slowed its stockbuild over the past two weeks, while a heatwave in southern Europe lifted gas-fired generation. EU countries net injected 3.9 TWh/d into storage on 11–23 June, down from 4.3 TWh/d on 29 May–10 June. Firms added 42.7TWh of gas to storage and left sites replenished at 56pc, or 637.7TWh. Northwestern Europe injected an average of 1.9 TWh/d over the past fortnight, down from 2.2 TWh/d in the previous two weeks. Germany, home to the largest storage capacity sites in Europe, accounted for nearly half, with injections averaging 869 GWh/d on 11-22 June. Private firms have booked only 64pc of German storage so far, or 158TWh. Central and eastern Europe injected 1.2 TWh/d, broadly in line with the past two weeks. The slowdown was driven mainly by tighter supply, with planned maintenance and disruptions across gas facilities limiting the gas available for injections. Maintenance at Norway's Kollsnes and scheduled works at the 79.8mn m³/d Nyhamna processing plant reduced flows to France to 108 GWh/d — from 491 GWh/d in May — on 13 June, forcing the country to turn to storage withdrawals to meet domestic consumption and demand from neighbouring markets. A prolonged heatwave also supported cooling demand, particularly in Mediterranean countries. In Madrid, maximum temperatures hovered at 6–7°C above seasonal norms on 18–23 June, peaking at 38°C, lifting demand for combined-cycle gas turbines. Milan saw temperatures of 2–5°C above seasonal norms during the period, further supporting gas use and tightening supply for injections. In France, heat had a limited impact on consumption, but low river flows and high Rhone temperatures could prompt nuclear cuts in the following days, potentially lifting gas-fired generation. Europe's supply in the past two weeks also has been affected by planned maintenance at France's 6mn t/yr Fos Cavaou and Belgium's 11.4mn t/yr Zeebrugge import terminals. LNG sendout from Fos Cavaou averaged 94 GWh/d on 11-24 June, compared with 309 GWh/d on 1-10 June, while Zeebrugge's sendout averaged 414 GWh/d, down from 609 GWh/d over the same period. Total sendout at European terminals averaged 4.2 TWh/d on 11–22 June, down from 4.4 TWh/d on 27 May-10 June and broadly in line with May levels when Montoir and Zeebrugge terminals were undergoing major maintenance. The EU continues to negotiate a final legal text to reduce the bloc's mandatory storage target to 83pc from 90pc. This could lower the effective EU-wide target to about 70.6pc, once national reductions are factored in. If the EU maintains the 90pc target, firms would need to inject 2.94 TWh/d until 1 November, still below the average of the past two weeks. Send comments and request more information at feedback@argusmedia.com Copyright © 2025. Argus Media group . All rights reserved.
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