Sao Paulo state seeks biomethane boost

  • Spanish Market: Natural gas
  • 13/05/24

Brazil's Sao Paulo state is seeking to capitalize on growing demand for renewable energy, announcing a series of measures to increase biogas and biomethane production across various sectors, including sugarcane, waste management firms and waste agriculture.

As Brazil's largest sugar and ethanol producing state, Sao Paulo has substantial potential to leverage existing infrastructure and resources — especially vinasse, a byproduct of ethanol production — to increase biomethane output.

To boost output, the state government will streamline environmental licensing for new projects through new rules that should attract investment, according to the state's environment undersecretary for energy and mining, Marisa Barros.

The focus will initially be on the sugar and ethanol industry, which can produce 30mn m³/d of biogas. Biogas contains 50pc methane, which can be processed into biomethane, a drop-in substitute for natural gas.

The state is also seeking to attract investment in biogas production from animal waste, which can produce up to 5mn m³/d. The government estimates that roughly 190,000 farms in the state can install biodigestors to produce biogas, which would contribute to lower emissions in the state.

The state agriculture secretary also approved the use of the Sao Paulo agribusiness expansion fund (Feap) for investments in biodigestors as well as new solar power installations. And earlier this year state regulatory agency Arsesp stipulated a discount on distribution fees for biomethane sold on the wholesale market.

Brazil's energy research company EPE sees significant potential for the sugarcane industry to expand biomethane production, in part because it has the advantage of having many mills adjacent to existing gas distribution infrastructure.

In addition to selling the renewable gas on the wholesale market, many mills are using biomethane in their own operations and to substitute diesel in their trucks and machinery, contributing to lower fuel costs and emissions.


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31/05/24

Australia’s Queensland bans CCS in Great Artesian Basin

Australia’s Queensland bans CCS in Great Artesian Basin

Sydney, 31 May (Argus) — Australia's Queensland state government announced today it will ban carbon capture and storage (CCS) in its portion of the Great Artesian Basin. Greenhouse gas (GHG) storage activities, including CCS projects, will be permanently prohibited in the basin as the government looks to protect its water resources, Queensland premier Steven Miles said on 31 May. The ban, which will be legislated, also includes enhanced oil or petroleum recovery activities that use a greenhouse gas stream. Activities involving GHG storage or the injection of GHG streams into underground formations may be able to continue in other parts of the state, subject to existing assessment and approval processes. The government will appoint an expert panel to review projects outside the Great Artesian Basin, which will report back in 2025. The Great Artesian Basin is Australia's largest groundwater aquifer. It is made up of several sedimentary basins spanning over 1.7mn m² across Queensland, the Northern Territory, South Australia and New South Wales. Water extracted from the basin is used for agriculture, irrigation and stock watering, as well as for industry and household supply in over 80 Queensland towns, according to the government. Queensland's Department of Environment, Science and Innovation last week rejected the environmental impact statement for commodities producer and trading firm Glencore's CTSCo Surat Basin CCS project, which aimed to demonstrate carbon capture from a coal-fired power station and the permanent storage of CO2. The project was unsuitable to proceed because of the potential impact on groundwater resources in the Great Artesian Basin, the department said. The CCS ban follows the state's decision late last year to ban unconventional oil and gas extraction in its portion of the Lake Eyre basin to protect inland waterways, as well as conventional production alongside rivers and on floodplains. By Juan Weik Send comments and request more information at feedback@argusmedia.com Copyright © 2024. Argus Media group . All rights reserved.

Trump found guilty in criminal 'hush money' case


30/05/24
30/05/24

Trump found guilty in criminal 'hush money' case

Washington, 30 May (Argus) — Former president Donald Trump was found guilty today on 34 felony counts of falsifying business records in relation to the reimbursement of a $130,000 payment to an adult film star ahead of the 2016 presidential election. The unanimous guilty verdict, from a 12-member jury in New York, will inject further uncertainty into the presidential election on 5 November, where Trump is the presumed Republican nominee and is leading in many polls against President Joe Biden. Trump is the first former US president to face a criminal trial, and his conviction means he will run for office — on a campaign focused in part on rolling back energy sector regulations and expanding drilling — as a convicted felon. Sentencing is scheduled for 11 July. Trump has argued the criminal charges, filed by New York state prosecutors, were "ridiculous" and were a politically motivated attempt to interfere with his campaign. At trial, Trump's attorneys argued against the credibility of a key witness, Trump's former attorney Michael Cohen, who testified that Trump directed the falsification of the business records to conceal a "hush money" payment to the adult film star following an alleged affair. "This was a rigged, disgraceful trial," Trump said following the verdict, "but the real verdict is going to be November 5 by the people, and they know what happened here." Despite the conviction, Trump, if elected, could still serve as president. Trump could face up to four years in prison, and sentencing will be decided by the judge overseeing the case. Trump is separately facing dozens of other felony charges in federal and Georgia state court, but those cases have faced delays and may not go to trial before the election. President Joe Biden's campaign said Trump has "always mistakenly believed" he would not face consequences. Biden's campaign said that despite the verdict, it would be up to voters to decide whether Trump is re-elected. "Convicted felon or not, Trump will be the Republican nominee for president," Biden's campaign said. By Chris Knight Send comments and request more information at feedback@argusmedia.com Copyright © 2024. Argus Media group . All rights reserved.

Enagas LNG bunkering sales at record high in 2023


30/05/24
30/05/24

Enagas LNG bunkering sales at record high in 2023

London, 30 May (Argus) — Spanish system operator Enagas' supplies of LNG as a marine bunkering fuel from its terminals in Spain and LNG bunkering vessels (LNGBVs) rose to a record high last year, as more capacity and stronger demand boosted throughput. Enagas supplied about 1.4TWh of LNG as a bunkering fuel in 2023, much more than the 400GWh supplied in 2022 and 300GWh in 2021, according to the firm. Enagas has expanded its LNG bunkering capacity in recent years, while the cost of LNG as a marine fuel has held much lower than competing alternatives such as marine gas oil (MGO) over the past year, supporting demand for LNG bunkering operations. The firm fully owns three LNG import terminals in Spain that offer LNG bunkering services — the Barcelona, Huelva and the Cartagena facilities. Barcelona offers pipe-to-ship (PTS) and ship-to-ship (STS) services, Huelva offers STS services and will soon offer PTS services, while Cartagena offers PTS operations, while Enagas plans to add STS services at the port too, the firm said. Enagas subsidiary Scale Gas co-owns two LNGBVs — the 5,000m³ Haugesund Knutsen in Barcelona with Norwegian firm Knutsen, and the 12,000m³ Levante LNG in Huelva, alongside UK supplier Peninsula. Most of the LNG bunkering operations in Spain are carried out in Barcelona, where bunkering volumes similarly rose to an all-time high last year, according to the port authority. The increase to 143,000 m³ of LNG as a bunker fuel across 199 deliveries last year, more than double the previous record posted in 2021 of 65,051m³, was linked largely to the commissioning of the Haugesund Knutsen in 2023. Enagas partially owns other assets that can offer truck-to-ship operations at the El Musel import terminal and the Sagunto and Bilbao LNG terminals. Bilbao can also provide PTS operations. Spain eyes growth Spain aims to build on its presence in the LNG bunkering market, with several planned LNG bunkering projects adding to its already-large LNG import and storage capacity. Utility Endesa recently advanced plans that were initially announced in 2021 to build a small LNG terminal with 5,000m³ of LNG storage capacity in the Spanish exclave of Melilla in north Africa. Endesa earlier this month requested permits for the project from the local government. Endesa also has plans for an LNG bunkering project in the port of Algeciras, with an LNG plant comprising four tanks with a combined capacity of 4,000m³. The firm had intended to start offering services earlier this year, but this appears to have been delayed. Scale Gas also aims to launch an LNGBV in the Canary Islands that it is building at present and aims to start operating in 2026. This LNGBV will also offer bio-LNG bunkering operations. By Ellie Holbrook Send comments and request more information at feedback@argusmedia.com Copyright © 2024. Argus Media group . All rights reserved.

Germany to stop gas storage levy on transit from 2025


30/05/24
30/05/24

Germany to stop gas storage levy on transit from 2025

London, 30 May (Argus) — The German government has agreed to stop charging its gas storage levy on natural gas exiting the German grid at border interconnection points from 2025, permanent secretary in the German economy and climate ministry Sven Giegold said this morning. The government intends to submit a law to parliament to change its gas storage levy so that it is no longer charged on gas transiting the country, in order to support stronger integration between European energy markets, Giegold said ahead of an energy council meeting in Brussels this morning. It had "never been Germany's intention to inhibit the integration between markets with this levy" or to disturb countries' efforts to gain independence from Russia, he said. Germany continued to support European gas supply diversification, for example through expanding its LNG import infrastructure, also in the interest of its neighbours, Giegold said. The German government had introduced the levy to recoup the cost of purchasing 50TWh of gas on the spot market without hedging it forward in summer 2022 to fill storage sites ahead of the winter. But falling prices meant that market area manager THE could only recover about a third of the amount spent through gas sales , leaving a loss of about €6.3bn ($6.8bn) to be levied on all gas exiting the German grid. The gas storage neutrality charge will continue to exist for domestic consumers as the "public good will continue to require financing", but Giegold said he did not want to pre-empt the legislative process with any details of future levy-setting methodologies. The recently-announced hike of the levy to €2.50/MWh for the second half of this year remains a legal requirement under the law currently in force. A change from the start of 2025 is an exceptionally quick turnaround in democratic legislation, Giegold said. Germany's central and eastern European neighbours — especially Austria, the Czech Republic, Hungary and Slovakia — had previously pointed out large negative impacts of the levy for their diversification efforts away from Russian gas, and had asked the commission to act against the levy . Energy commissioner Kadri Simson, who had previously criticised the levy for "putting energy solidarity at risk", said this morning that she had sent several letters to German economy and climate minister Robert Habeck on the matter and expected Germany to abolish the levy on transit flows. By Till Stehr Send comments and request more information at feedback@argusmedia.com Copyright © 2024. Argus Media group . All rights reserved.

Jera sells partial stake in Freeport LNG to Japex


30/05/24
30/05/24

Jera sells partial stake in Freeport LNG to Japex

Osaka, 30 May (Argus) — Japan's largest LNG importer Jera has decided to sell part of its stake in the operator of the 15mn t/yr Freeport LNG export project in the US' Texas to Japanese upstream developer Japex. Jera has agreed with Japex to sell 15pc of its 100pc owned subsidiary Gulf Coast LNG, which holds a 25.7pc stake in Freeport LNG Development, for around $380mn. The deal will reduce Jera's ownership of the Freeport operator to 21.9pc. The transaction is scheduled to be completed on 10 June. Jera will continue maintaining a liquefaction agreement in the Freeport LNG project. The company separately has a 25pc stake in Freeport's first liquefaction train and receives around 2.32mn t/yr of LNG under a 20-year contract. The sale is aimed at optimising Jera's asset portfolio, although it is unclear how the profits will be used. The company is planning to spend ¥5 trillion ($32bn) to drive decarbonisation of its business over the April 2024-March 2036 fiscal years, focusing on LNG, renewables and hydrogen and ammonia. Jera plans to maintain its LNG handling volumes at no less than 35mn t/yr until 2035-36, as it sees LNG will play a key role to adjust for imbalances in electricity supplies in Japan and help reduce dependence on coal- and oil-fired power producers in Asian countries. It has also secured funding for the Scarborough gas project offshore northwest Western Australia, a joint venture project by Jera and Australian independent Woodside Energy. State-owned Japan Bank for International Co-operation (JBIC) has agreed with Woodside Finance, a subsidiary of Woodside Energy, to finance up to $1bn for the Scarborough development, according to JBIC on 30 May. The lending will be co-financed by private financial institutions, taking the total funding to $1.45bn. Scarborough aims to produce 8mn t/yr of LNG from 2026 at Woodside's 4.9mn t/yr Pluto LNG, where it is building a second 5mn t/yr production train. Jera with its 15.1pc stake in Scarborough is planning to offtake as much as 1.2mn t/yr of LNG. JBIC separately agreed with Jera in March to finance up to $831mn for buying the Scarborough stake. By Motoko Hasegawa, Yusuke Maekawa Send comments and request more information at feedback@argusmedia.com Copyright © 2024. Argus Media group . All rights reserved.

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