Brazil launches new biomethane data tool

Spanish Market: Natural gas
09/03/22

Brazil hydrocarbons regulator ANP launched a new data visualization tool for the biomethane sector.

The new interactive data page shows information on four plants, located in Sao Paulo, Rio de Janeiro and Ceara states, so far. This is because the page only includes plants authorized to produce biomethane from solid waste, leaving out non-authorized production and biogas production from feedstock and biomass.

The tool shows 4mn m³ in biomethane production in January 2022, with sales distributed between Ceara, Rio Grande do Sul and Rio de Janeiro states.

Biogas producers association Abiogas and other market and government players also have their own tool, including data from 675 biogas plants, but its most recent data is from 2020.

By Rebecca Gompertz

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02/06/26

Over 300 vessels engaged with Strait Authority: Iran

Dubai, 2 June (Argus) — More than 300 non-Iranian vessels have contacted Iran's Persian Gulf Strait Authority (PGSA) since late April to obtain permits to cross the strait of Hormuz safely, the entity said yesterday. The PGSA was formed as part of Tehran's push to tighten control over shipping in and around the critical strait of Hormuz after the start of the US-Israeli war with Iran in late February. Numerous governments have pushed back strongly against Iran's claims on the waterway. "Since the start of operations early [in the Iranian month of Ordibehesht], more than 300 non-Iranian vessels have submitted information to the PGSA to obtain safe passage permits through the strait of Hormuz," the authority said yesterday. Ordibehesht corresponds to the period from 21 April to 21 May. A breakdown published by the PGSA showed 42pc of the vessels applying for a permit were "oil tankers". Another 27pc were bulk carriers, 11pc were container ships and 8pc LNG carriers. It said 77pc of the vessels submitting requests were looking to exit the Mideast Gulf through the strait, with the remaining 23pc looking to enter the Mideast Gulf. Of the vessels looking to exit the Mideast Gulf, the PGSA said more than one quarter, or 28pc, were destined for China, 19pc for India and another 23pc for elsewhere in Asia. Around 12pc of the vessels were heading for ports in Europe and 10pc for ports in Africa. And of the vessels travelling the opposite direction, more than one third, or 34pc, were destined for the UAE, 31pc for Qatar, 17pc for Iraq and 10pc for ports in Kuwait. The remaining 6pc was split equally between ports in Saudi Arabia and Oman. Staying power Tehran had been working on a mechanism to formalise its oversight and management of traffic through the strait of Hormuz since early in the conflict which was triggered by a surprise joint attack by US and Israel on Iran on 28 February. A bill dubbed the ‘law of strategic action for peace and development in the Persian Gulf' that was under discussion in Iran's parliament in March, now appears to have formed the basis for the creation of the PGSA. Iran formally announced the launch of the PGSA on 5 May, calling on all vessels intending to transit the strait to contact it by email to request a permit. The authority launched an account on social media platform X two weeks later on 18 May. But the US Treasury's Office of Foreign Assets Control (Ofac) last week issued fresh sanctions against it , despite ongoing talks between Washington and Tehran on a deal to end the war, and reopen the strait. Anyone co-operating with the PGSA "may be providing support to and receiving services from [Iran's Islamic Revolutionary Guard Corps] IRGC, which ultimately benefits from this attempted extortion, and may therefore be exposed to sanctions risk," Ofac said. The sanctions appear to have had an effect on traffic through the strait, with latest data from Kpler indicating that traffic has fallen to a little over three vessels per day since the sanctions were announced, down from almost seven daily in the week prior to the announcement. By Nader Itayim Send comments and request more information at feedback@argusmedia.com Copyright © 2026. Argus Media group . All rights reserved.

BP to sell 5pc stake in Australia’s Browse LNG project

02/06/26

BP to sell 5pc stake in Australia’s Browse LNG project

Sydney, 2 June (Argus) — BP will sell a 5pc stake in the $35bn Browse gas fields offshore Western Australia (WA), with South Korean private-sector firm GS Energy joining the project to help backfill the 14.3mn t/yr North West Shelf LNG terminal. BP will retain a 39.33pc working interest in Browse joint venture (JV) post-transaction, a BP spokesperson said on 2 June, describing GS as a "committed partner" that complements the substantial work already completed to advance the project as it progresses towards the front-end engineering and design (FEED) stage. The deal is conditional upon regulatory and JV approvals. Australian independent Woodside Energy is the operator and holds a 30.6pc stake in Browse alongside BP, Japan's Mimi — a joint venture between Mitsui and Mitsubishi — which owns 14.4pc, while state-owned PetroChina controls 10.67pc. PetroChina is planning to sell its share to Japanese firm Inpex, it said last month . Inpex already operates the 9.3mn t/yr Ichthys JV and holds a 17.5pc stake in the Shell-operated 3.6mn t/yr Prelude floating LNG facility, both of which are located in the Browse basin. South Korea is considered a critical energy partner for Australia. Australia was the top LNG exporter to South Korea in both 2024 and 2025, shipping 14.68mn t in 2025 , up by 29pc from 11.4mn t in 2024. South Korea was Australia's largest gasoil supplier in 2025, data from Australian Petroleum Statistics show, shipping about 150,000 b/d , mainly to the east coast. Australia also shipped about 10pc, or 20.5mn t , of its thermal coal exports to South Korea last year. At the same time, it imports around 30pc of its gasoil cargoes from South Korean refiners — a supply that is critical to keeping its mining and agriculture sectors operational, as it lacks domestic refining capacity to meet demand. The addition of Japanese and South Korean partners to the Browse JV may help spur progress on the controversial project, as north Asian importers seek to secure non-Middle East supplies in the wake of the US-Iran war, while Canberra similarly moves to lock-in oil product imports. Browse ‘critical': WA With a forecast production capacity of 11.4mn t/yr across LNG, LPG and domestic gas and a peak condensate production rate of 50,000 b/d, Browse is considered Australia's single largest untapped oil and gas project. But the JV's plans for the field are already facing headwinds from a national environmental campaign alleging potential damage from the project's emissions and to the nearby Scott Reef, a remote shoal system . Proponents include WA premier Roger Cook, who has warned that Browse is critical to the state's domestic gas supply, as the NWS project includes the 630 TJ/d capacity Karratha Gas Plant (KGP). Production at KGP has dipped since mid-2020 due to natural field depletion. Woodside's share of NWS' LNG production has also fallen to 2.94mn t in 2025, down from 3.64mn t a year earlier, after it retired a 2.5mn t/yr train at the terminal in late 2024. By Tom Major Send comments and request more information at feedback@argusmedia.com Copyright © 2026. Argus Media group . All rights reserved.

Union begins strikes at Australia's Ichthys LNG: Update

02/06/26

Union begins strikes at Australia's Ichthys LNG: Update

Adds statement from Inpex in paragaph 5 Sydney, 2 June (Argus) — The union representing oil and gas workers at the 9.3mn t/yr Ichthys LNG project near Australia's northern city of Darwin began strikes from 6am Australian Western Standard Time today (10pm GMT 1 June), according to the Offshore Alliance (OA) union. Protected industrial action authorised by members in April has started despite significant progress in talks between the union and project operator Japan's Inpex that led to delays to planned work stoppages last week, the OA said. The strike action includes union members downing tools between 6am and 8am and 6pm and 8pm, and bans on overcycle, working past 6am on demobilisation day, and swapping between day shift and night shift without at least four weeks' notice from management. All three Inpex facilities will be disrupted by stoppages of work and work bans, including the onshore processing facilities and LNG terminal at Darwin harbour, the floating production, storage and offloading (FPSO) and central processing facility (CPF) units. Management remains committed to engaging in good faith to reach a fair and equitable agreement, maintaining safe operations and ensuring reliable energy supply, Inpex's senior vice-president Bill Townsend said. The OA has served a further notice to Inpex setting out more strikes to occur from 11-23 June but the union remains committed to negotiating and pausing industrial action should Inpex return to genuine bargaining, it said. Ichthys can also produce about 100,000 b/d of condensate and 1.65mn t/yr of LPG, shipping about 1.36mn t of LPG in 2025. By Tom Major Send comments and request more information at feedback@argusmedia.com Copyright © 2026. Argus Media group . All rights reserved.

State lawmakers may hold fate of Alaska LNG

01/06/26

State lawmakers may hold fate of Alaska LNG

Houston, 1 June (Argus) — Alaska's state lawmakers are convening in a special legislative session to consider tax relief for the 20mn t/yr Alaska LNG export project, a potentially make-or-break decision that developer Glenfarne says is required to secure financing. Alaska governor Mike Dunleavy (R) ordered the state legislature to convene for a special session in late May with only one priority: pass a bill that would reduce upfront costs for Alaska LNG. Dunleavy first unveiled a proposal on 20 March pushing for a carve-out that would exempt Alaska LNG from the state's existing property tax law and replace it with a volume-based tax on its pipeline flows. But the legislature failed to pass a bill by the end of the legislative session on 20 May, citing a need for more information from Glenfarne. Lawmakers began the 30-day special session on 21 May. "I'll remain optimistic that the legislature just needs a little bit more time in this special session that they didn't have because of all the other bills they had to deal with in the regular session," Dunleavy told Argus . For Glenfarne, which took over the project in early 2025 after other developers abandoned it in 2016 citing cost concerns, tax reform is necessary to move forward with the project. The legislative effort is "one component of the requirements needed for Alaska LNG to proceed", a Glenfarne spokesman told Argus , calling Alaska's property taxes "a hurdle for the development of a North Slope natural gas project for more than a decade". Glenfarne plans to split Alaska LNG into two phases. The first encompasses construction of a 739-mile, 3.5bn ft³/d pipeline from Alaska's gas-rich North Slope to the state's south-central coast ( see map ). The line would also supply the domestic market, which faces a looming gas supply shortage amid declining domestic production in the Cook Inlet. The second phase of adding the liquefaction terminal would come later with a separate financial decision. Glenfarne hopes to begin construction on the pipeline in the first half of 2027, with first flows moving in late 2029. Under the state's existing law, Alaska LNG would be exempt from property taxes during construction. Once the project is in service, Dunleavy's proposal would replace the property tax with a volumetric tax of 6¢/1,000 ft³ of throughput on the pipeline. The volumetric tax would apply only after throughputs reach a 30-day average of 1bn ft³/d or 10 years after the first flows, granting Glenfarne a ramp-up period and reducing its upfront tax burden. The former is unlikely to occur without the liquefaction phase. The domestic gas market along the proposed pipeline consumes less than 300mn ft³/d, according to consultancy firm Rapidian Energy. The volume-based treatment equals about a 90pc reduction in property taxes that the state and local municipalities would collect under the existing law for oil and gas projects, according to the Alaska Department of Revenue. Legislators have proposed higher volumetric rates, up to as much as 55¢/1,000 ft³, to ensure more revenue. A concealed cost Though lawmakers broadly support Alaska LNG, they have questioned Glenfarne's ability to deliver the project as well as its true cost. The $44bn estimate for both phases comes from a study published in 2016. Rapidian Energy estimated last year that the project's total price tag will command between $53bn-63bn, with upside risk for labor and steel costs due to the project's remote location. "Glenfarne was unknown 18 months ago. They have no completed N. America projects. But they want a 92pc reduction in our local property taxes," senator Cathy Giessel (R), chair of the Senate Resources Committee, wrote in a newsletter to constituents in March. "They are holding all financial information about the project confidential. This is not a good business position for our state to be in." Dunleavy hopes the special session will provide enough time for lawmakers to receive the information they need. If not, Dunleavy told Argus he would consider calling another special session unless lawmakers outright oppose the project. By Tray Swanson Alaskan LNG projects Send comments and request more information at feedback@argusmedia.com Copyright © 2026. Argus Media group . All rights reserved.

Foreign buyers lured back to Canada’s upstream

01/06/26

Foreign buyers lured back to Canada’s upstream

New York, 1 June (Argus) — After rushing to the exits just a few years ago, international buyers are returning to Canada's oil and gas patch, drawn by a deep pool of untapped reserves on offer as growth slows elsewhere. A pivot back to oil and gas under Canadian prime minister Mark Carney, driven in part by a desire to diversify exports given trade tensions with the US, has seen moves to fast-track pipeline projects and ease some environmental regulations. Overseas investors are also increasingly turning to Canada as a relatively safe haven at a time of geopolitical uncertainty, in a marked shift after some of the largest majors scaled back exposure to the oil sands following investor pressure. Mergers and acquisitions (M&A) have largely centred upon the Montney shale basin in British Columbia and Alberta, as well as the Duvernay in west-central Alberta. A slowing US shale sector that has seen the best remaining acreage already exchange hands is also spurring greater interest in Canadian inventory that offers a cheaper cost of entry. "These Canadian plays — the Montney and Duvernay — offer a good blend of high-quality resource and duration, and that's something that some US operators lack today," says energy consultancy Enverus' senior analyst Michael Berger. "There is an incentive to look north of the border." While Alberta's oil sector has been boosted by this year's rally in crude prices, there has also been a growing recognition of its outsized role against a backdrop of elevated trade tensions with the US. To that end, Carney has backed plans to increase LNG and oil exports from British Columbia to deepen trade ties with Asia and Europe, and pledged faster approvals to ease bottlenecks. In announcing its initial foray into Canada last week, US independent Northern Oil and Gas (NOG) cited the Duvernay's "high-quality, low-cost, long-life inventory with meaningful upside that remains largely untapped". NOG, which bought a 25pc stake in assets from Parallax Energy for $259mn, is following other US firms. Ovintiv doubled down on the Montney last year, acquiring NuVista Energy for $2.7bn, to gain control of 140,000 net acres and 100,000 b/d of oil equivalent. US private equity has also been keen, with Carlyle Group and NGP Energy Capital Management funding privately held Cygnet Energy's takeover of Kiwetinohk Energy in October. Parallax is backed by Carnelian Energy Capital. Vote of confidence In April Shell acquired ARC Resources in a $13.6bn deal that establishes Canada as a "heartland" for the major, chief executive Wael Sawan said. The purchase will also support Shell's growing LNG footprint in Canada. Calgary-based Whitecap Resources says the transaction has put a spotlight on the Canadian energy sector and "people are hyper-focused" on the Montney and Duvernay. The size and quality of inventory in Canada's hottest plays will continue to drive deals, but bigger acquisitions may be limited. "There are fewer and fewer candidates out there for large-scale M&A activity," Whitecap chief executive Grant Fagerheim says. A referendum scheduled for October over whether Alberta should remain part of Canada could cast a shadow over the investment outlook, but analysts said it was too early to say whether it could slow deal-making. The total value of Canadian upstream deals is running at $17bn so far this year, Enverus says, compared with $19.5bn in 2025 and $12.9bn the year before. For now, analysts see further foreign interest in Canada's upstream, encouraged by a more supportive federal government and new pipeline projects that are easing concerns about getting supplies to market. "All of these factors combined with inventory pressures elsewhere have seen capital re-emerge and new buyers come back to Canada," TD Securities senior research analyst Aaron Bilkoski says. By Brett Holmes and Stephen Cunningham Send comments and request more information at feedback@argusmedia.com Copyright © 2026. Argus Media group . All rights reserved.

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