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Latest natural gas news
Browse the latest market moving news on the global natural gas industry.
Australia court dismisses action against Beetaloo gas
Australia court dismisses action against Beetaloo gas
Sydney, 26 June (Argus) — Drilling for appraisal shale gas in the Beetaloo sub-basin in Australia's Northern Territory (NT) can continue after Australia's Federal Court rejected an attempt by environmental campaigners to pause development. The court on 26 June dismissed a case brought by Lock the Gate Alliance, a coalition of anti-fossil fuel activists. Lawyers for the applicant had argued federal government approval was needed for US-listed shale gas developer Tamboran Resources to use hydraulic fracturing or 'fracking', to drill its 40 TJ/d Shenandoah South pilot project in the region. But the applicant failed to establish that Canberra should review the project under the Environment Protection and Biodiversity Conservation Act, Justice Nicholas Owens found. The court was not satisfied the development would have a significant impact on a water resource, the hurdle required for it to be federally-assessed. The project has been approved by the NT government which is also effectively underwriting its development with a take-or-pay gas sales agreement inked in 2024 . First gas is planned for July-September . The Beetaloo sub-basin is a remote shale gas region about 500km south-east of NT capital Darwin — home to the 9.3mn t/yr Ichthys and 3.7mn t/yr Darwin LNG (DLNG) terminals. DLNG holds permits for up to 10mn t/yr of exports, with operator domestic independent Santos eyeing Beetaloo flows for a potential expansion of the facility. Santos will drill three Beetaloo appraisal wells from July, which it said would be tested for 9-12 months to determine further development actions . By Tom Major Send comments and request more information at feedback@argusmedia.com Copyright © 2026. Argus Media group . All rights reserved.
Australia reservation scheme to shape new gas: Woodside
Australia reservation scheme to shape new gas: Woodside
Sydney, 25 June (Argus) — The design of the federal government's new gas reservation scheme, currently open for public comment, will dictate Australian independent Woodside Energy's decision to drill new domestic wells in the Gippsland basin. Woodside last year identified four development targets that it said could deliver up to 200PJ (5.34bn m³) of sales gas to the market via its Bass strait assets, including the Gippsland basin joint venture (GBJV), for which it will assume operatorship from ExxonMobil this year. But this plan hinges on both technical maturity and Canberra's new gas reservation scheme, chief executive Liz Westcott said on 25 June, warning that the right policy settings and collaboration between industry, government and community was needed to progress new projects. The 50:50 GBJV assets include the 700 TJ/d Longford gas plants, the Long Island Point gas liquids terminal and pipelines linking offshore operations with Victoria state. Woodside will also take over operatorship at the Kipper unit joint venture, which is 32.5pc owned by ExxonMobil, 32.5pc by Woodside, and 35pc by Japan's Mitsui. Scheme start looms The gas reservation programme, slated to begin on 1 July next year, will require LNG exporters to reserve 20pc of shipped volumes for the domestic market only, the government has said. Australia has, however, pledged to respect term supply contracts entered into before this year as part of the national scheme. It remains unclear how this will operate practically, but it is designed to avoid a possible shortfall later this decade due to poor gas planning by state and federal governments. Woodside does not exports gas from its eastern states assets but supplies LNG from its 14.3mn t/yr North West Shelf and 4.9mn t/yr Pluto terminals on the west coast. Western Australia's state government has said it has been assured its 15pc reservation scheme will meet Canberra's stated goals . Consultation on the reservation scheme will close on 30 June , with further development of the programme to take place in July-December. The reservation is causing uncertainty among foreign investors in the nation's LNG sector , while domestic producers are flagging future supply impacts if investment is curtailed . By Tom Major Send comments and request more information at feedback@argusmedia.com Copyright © 2026. Argus Media group . All rights reserved.
Dutch Nam launches second Grijpskerk open season
Dutch Nam launches second Grijpskerk open season
London, 8 June (Argus) — Dutch gas producer and storage operator Nam is reoffering storage capacity at the Grijpskerk gas site for the current storage year, it said on Friday. Nam is holding a new open season for the 24TWh site, with the successful bidder to hold the entire capacity from 1 July 2026 to 31 March 2027. Only one party can buy the full capacity because of technical constraints at the site, and the capacity will be allocated on a first-come, first-served basis, Nam said. This is the second open season for Grijpskerk, after the first in March failed to attract a successful bid. The site's restrictions and scheduled unavailability remain unchanged from the previous offering. The annual bundle fee for booking the site was reduced to €54.89mn ($63.32mn) because of the shorter timeframe. There is little scope for Nam to allocate the capacity, as the site is not set up for multiple users and a single party is unlikely to take on such a large risk given supply uncertainty after the closure of the strait of Hormuz, market participants said. There is also little economic incentive for firms to book the site, as the TTF July-winter 2026-27 spread remains inverted and has been since the start of the US-Iran war. Argus assessed the TTF July-winter 2026-27 seasonal spread at +€1.99/MWh on Friday. The reoffering shows that Nam did not reach an agreement with EBN for EBN to take over filling operations at the site, as it did for Norg , even though the Dutch climate and green growth ministry had previously said EBN could step in if storage capacity at Grijpskerk remained uncontracted to ensure security of supply. By Alejandro Moreano Send comments and request more information at feedback@argusmedia.com Copyright © 2026. Argus Media group . All rights reserved.
Turkish Stream maintenance slows storage refilling
Turkish Stream maintenance slows storage refilling
London, 5 June (Argus) — Maintenance work on the Turkish Stream pipeline has curtailed gas deliveries to central and southeast Europe so far this month, reducing the pace of storage injections and supporting regional gas prices. Limited arbitrage opportunities have prevented firms from making up for slower inflows on that route through stronger imports from elsewhere, leaving storage as the most economical source of market balancing. Annual Turkish Stream maintenance is taking place on 2–7 June, with the daily transit nomination at the Strandzha 2 entry point to Bulgaria falling to zero on 2–6 June, the most recent data show. Daily transit deliveries at the Strandzha 2 entry point to Bulgaria were at around 480 GWh/d on 1 June, below around 490 GWh/d in May ( see Turkish Stream flows graph ). Gas shipped through Turkish Stream supplies Hungary, Slovakia, Serbia and other central eastern Europe markets. Assuming Turkish Stream remains fully off line until 7 June, countries in central and southeast Europe are set to lose a combined 2.94TWh of supply over the period. But flows on the Turkish Stream resumed one day ahead of schedule last year, at roughly half the rate seen prior to maintenance works. The loss of flows was largely offset by a slowdown in storage injection rates across the region. Combined injections in Hungary, Romania and Slovakia declined to 64 GWh/d on 2–4 June from around 132 GWh/d in May, while Bulgaria stopped injections on 2 June after building 14.3 GWh/d a week earlier. Regional prompt prices have risen during Turkish Stream maintenance, increasing their values relative to markets in western Europe. The Hungarian prompt day-ahead price held an average premium of €1.98/MWh to the TTF on 1-4 June, widening from €0.745/MWh in May. The Slovakian day-ahead price has held €2.41/MWh above the TTF so far this month, widening from €2.08/MWh in May. Bulgarian day-ahead prices switched to a premium of €3.19/MWh from a discount of €0.35/MWh in May ( see price graph ). The limited price uplift did not attract additional west-to-east imports, as arbitrage opportunities were insufficient to cover transportation costs. Flows at Baumgarten, Lanzhot and Mosonmagyarovar increased by 19 GWh/d on 2-4 June from 45 GWh/d in May, but this did not compensate for the loss of deliveries on the Turkish Stream. LNG sendout from Greek, Croatian and Polish terminals did not increase. The combined sendout from these terminals so far in June was 292 GWh/d, lower than the 377GWh recorded in May. Alternative supply in the region may come from Azerbaijan through the 11.16bn m³/yr Trans Adriatic Pipeline and imports from Turkey. But deliveries of Azeri gas have been stable at the Kipoi interconnection point on the Turkish-Greek border and have averaged 346 GWh/d so far this month, down slightly from 347 GWh/d in May. Flows at Strandzha 1 have averaged 18.2 GWh/d so far this month, up from 8.3 GWh/d in May, but this increase is also still not sufficient to compensate for the loss of Gazprom's deliveries to the region. By Victoria Dovgal Turkish stream flows May-June GWh/d Send comments and request more information at feedback@argusmedia.com Copyright © 2026. Argus Media group . All rights reserved.
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