US poised to back New Jersey offshore wind farms

: Electricity, Emissions
24/05/23

US regulators could soon approve two offshore wind projects near New Jersey, but with stipulations that would slightly reduce the number of turbines installed in the Atlantic Ocean.

The US Bureau of Ocean Energy Management (BOEM) favors a design for the Atlantic Shores South system that would result in up to 195 turbines, as many as 10 offshore substations and eight transmission cables to ferry electricity ashore to New Jersey, the agency said today in its final environmental impact statement for the project.

Atlantic Shores South comprises two separate projects, Atlantic Shores 1 and Atlantic Shores 2, which are 50:50 partnerships between Shell and EDF Renewables. The pair's overall capacity is tentatively set at 2,837MW, with the first phase targeting 1,510MW and a size for the second to be determined.

Atlantic Shores 1 has a contract to deliver up to 6.18mn offshore renewable energy certificates each year to New Jersey, with first power expected in 2027. The state selected the project through its second offshore wind solicitation, with the 20-year contract scheduled to begin in 2028.

The developers had proposed installing up to 200 turbines, but BOEM decided to favor a modified plan, adopting alternatives put forward by the companies in the name of mitigating impacts on local habitats while limiting turbine height and their proximity to the shore to reduce the project's "visual impacts," a point of contention among New Jersey residents who fear damage to tourism in oceanside communities.

The BOEM-endorsed design would have mostly "minor" to "moderate" effects on the surrounding environment, with exceptions including consequences for North Atlantic right whales, commercial and for-hire fisheries and local scenery, which could be "major." The areas potentially hit hardest by the projects would be open to "major" consequences regardless of the project design, according to BOEM's analysis.

The preference is not BOEM's final ruling, but it does herald the path the agency is likely to take. Regulators will publish the review in a "coming" edition of the Federal Register, starting a mandatory 30-day waiting period before BOEM can publish its final decision on the project.

By Patrick Zemanek

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25/06/19

BMWE legt RED III Entwurf vor

Hamburg, 19 June (Argus) — Das BMWE hat Verbänden am 19. Juni einen ersten Referentenentwurf zur Umsetzung der RED III vorgelegt. Diese sieht grundlegende Veränderungen zur Erfüllung der THG-Quote vor. Erste Preisindikationen steigen schlagartig. Um die auf EU-Ebene gültige dritte Fassung der Erneuerbare-Energien-Direktive (RED III) in deutsches Recht umzusetzen, hat das Bundesministerium für Wirtschaft und Energie (BMWE) einen Entwurf zur Anpassung des Bundes-Immissionsschutzgesetzes (BImSchG) vorgelegt. Unter anderem sieht der Entwurf vor, die Treibhausgasminderungsquote (THG-Quote) bis 2040 schrittweise auf 53 % zu erhöhen (siehe Grafik). Das bisherige Ziel war eine Quotenhöhe von 25,1 % im Jahr 2030. Auch der Pfad bis 2030 wurde leicht angepasst. Damit käme das Gesetz, wenn es in dieser Form umgesetzt wird, einer vielgeäußerten Forderung der Biokraftstoffindustrie nach, die sich für eine stärkere Quotenerhöhung eingesetzt hat. Infolgedessen melden erste Marktteilnehmer Angebote für Andere Zertifikate für das Verpflichtungsjahr 2026 in Höhe von 175 €/tCO2e. Für dieselben Zertifikate für 2025 werden 125 €/tCO2e geboten. Zusätzlich enthält der Entwurf einen Mechanismus, der im Falle einer Übererfüllung die Höhe der Quote im übernächsten Jahr erhöht. Ausschlaggebend ist dafür, ob die gesamte Quotenerfüllung in einem Jahr bereits ausreichen würde, um die Quotenhöhe des Übernächsten Jahres zu erfüllen. Darüber hinaus sieht der Entwurf vor, die Option zur zweifachen Anrechnung von als fortschrittlich geltenden Biokraftstoffen abzuschaffen und die Mindestquote zu erhöhen. Diese steigt dann bis 2030 auf 3 %. Zuvor lag das Ziel bei 2,6 %. Viele Marktteilnehmer haben gemutmaßt, dass die Doppelanrechnungsoption entfallen würde, um die benötigte Menge an Erfüllungsoptionen zu erhöhen. Auch welche Kraftstoffe zur Erfüllung der Quote genutzt werden können wird angepasst: So können keine Kraftstoffe auf Soja- oder Palmölbasis zur Erfüllung genutzt werden. Letzteres schließt auch Kraftstoffe aus Nebenprodukten der Palmölproduktion, allen voran Palmölmühlenabwasser (POME) ein. Dieses wurde in der Vergangenheit insbesondere genutzt, um die fortschrittliche Unterquote zu erfüllen, da es dank einer Sonderklausel trotz seiner Einstufung als fortschrittlich nur einfach zur Erfüllung der THG-Quote angerechnet werden konnte. Diese Regelung würde direkt ab Inkrafttreten der Gesetzesänderung wirksam werden. Die Anrechnungsgrenzen für futtermittel- und abfallbasierte Kraftstoffe werden ebenfalls angepasst: Während das Limit für futtermittelbasierte Produkte bis 2030 von 4,4 % der in Verkehr gebrachten Energiemenge auf 3 % reduziert wird, steigt das Limit für abfallbasierte Produkte wie Altspeiseöl (UCO) bis 2039 von 1,9 % auf 2,8 %. Zusätzlich wird eine Mindestquote für erneuerbare Kraftstoffe nicht-biogenen Urpsrungs (RFNBO) eingeführt. 2026 beträgt der energetische Mindestanteil 0,1 % und soll bis 2040 auf 12 % steigen. Zu den RFNBOs gehören unter anderem synthetische Kraftstoffe wie eFuels (PtL, Power-to-Liquid) und Grüner Wasserstoff. Der Entwurf erweitert den Geltungsbereich der THG-Quote außerdem auf den Luftverkehr. Bisher galt hier eine gesonderte Quote für erneuerbare Kraftstoffe. Darüber hinaus unterliegt nun auch der Seeverkehr der THG-Quote. In der Seefahrt genutzte Kraftstoffe, die im Straßenverkehr anrechenbar wären, können hierbei jedoch nicht für die Erfüllung genutzt werden. Damit soll vermieden werden, dass Unternehmen die Erfüllung ihrer Verpflichtung komplett vom Straßenverkehr auf die Seefahrt umwälzen. Der Entwurf sieht außerdem vor, dass erneuerbare Kraftstoffe nur noch angerechnet werden können, wenn Vor-Ort-Kontrollen der Produktionsstätten durch staatliche Kontrolleure ermöglicht werden. Dies soll das Betrugspotenzial bei der Anrechnung von Biokraftstoffen mindern. Der Entwurf liegt nun den Branchenverbänden vor. Ein Mitglied des Umweltausschusses erklärte am 4. Juni im Rahmen einer Podiumsdiskussion, dass der Entwurf nach Anpassung an eventuelle Verbandsvorschläge im Oktober dem Parlament zur Debatte vorgelegt werden soll und idealerweise zum 1. Januar 2026 in Kraft treten soll. Der Referentenentwurf sieht vor, dass die Änderungen an der THG-Quote mit Beginn des neuen Verpflichtungsjahres in Kraft treten. Dies soll Marktverwerfungen verhindern, für den Fall, dass die Gesetzesänderung innerhalb eines Verpflichtungsjahres in Kraft treten sollte. Von Svea Winter & Max Steinhau Entwicklung der THG-Quote bis 2040 Senden Sie Kommentare und fordern Sie weitere Informationen an feedback@argusmedia.com Copyright © 2025. Argus Media group . Alle Rechte vorbehalten.

French Bugey nuclear cuts likely from 25 June: EdF

25/06/19

French Bugey nuclear cuts likely from 25 June: EdF

London, 19 June (Argus) — High temperatures on the River Rhone are "likely" to drive production cuts from nuclear plants along the river, especially Bugey, according to French utility EdF. The potential cuts will be reviewed on 24 June, and a specific publication will detail the cuts if they are confirmed, EdF said. France is about to see a combination of a heatwave and dry spell, with daily highs in Grenoble forecast to remain mostly above 30°C until the beginning of July. The combination of heat and a lack of rain in the Alps has increased the chance of hotter water and lower flows on the Rhone, which could have a knock-on effect on France's nuclear fleet. Eight of the country's 57 reactors discharge their cooling water directly into the river, and environmental regulations limit the temperature at which they can do this, meaning if the river's flow is low and temperatures high, the units can be forced to reduce output. Flows out of Lake Geneva — where the Rhone leaves Switzerland and enters France — have remained at 239-328 m³/s since 2 June. Earlier in the month this was within the 25th to 50th percentile of historical values, but is now slightly below the 25th percentile, as flows typically increase in June to peak at the end of the month and into July. The low outflows are reflective of low inflows, as the lake's level is regulated by the Seujet dam at the lake's exit to the Rhone, which keeps its level about 1m all year. The lake's level typically falls in the first quarter and rises in the second to a peak in June and July, and the level has been creeping up over June in line with the historical trend. The outflow's average temperature of 20.9°C on Wednesday was between the 75th and 95th percentile for the date. A convention between France and Switzerland guarantees that the flow of the Rhone upstream of Bugey, the first nuclear plant on the river, is to remain above 150 m³/s, with the potential for release of water from the Emosson reservoir in Switzerland to the Arve River to achieve this. In recent days, flows at Bugey — combining outflows from Lake Geneva and tributaries of the Rhone, which have brought more than 100 m³/s — have been well above this minimum. And thermal limits for Bugey are set at a maximum temperature downstream of the plant of 26°C and a maximum temperature difference between upstream and downstream of 5°C. If grid operator RTE determines that the plant is necessary to maintain supply, this maximum limit can increase to 27°C, but with only a 1°C temperature difference allowed. Only two of Bugey's four units discharge their cooling water directly into the Rhone, with the other two using cooling towers, which sharply reduce their thermal impact on the river, and so the extent to which the regulations affect them. If water flows were at their minimum of 150 m³/s, and at a temperature of 21°C upstream of the plant, this stream would have the capacity to carry 3.14GW of waste heat away from the plant before hitting the regulatory limit of 5°C of temperature difference and 26°C maximum temperature downstream. This is less than the roughly 3.8GW of waste heat generated by Bugey 2 and 3 operating at full power, including their thermal power of 5.6GW less their electrical power of 1.8GW. Bugey 4 and 5 contribute a small amount of extra waste heat downstream, as their cooling towers do not completely eliminate waste heat. Both units have had to stop at moments in the past two years because of heat-related constraints. In the last period when Bugey was constrained, in mid-August, flows leaving Lake Geneva were significantly hotter than now, roughly 24-26°C. At that point, output from Bugey 2 was reduced to zero, before a sharp fall in water temperature to roughly 20°C by 18 August allowed constraints to be lifted. But air temperatures in the region are forecast to remain elevated for the next two weeks, which will boost water temperatures over time. Daily highs in Sion, Switzerland, are seen at 3-4°C above the norm through to the beginning of July. Temperatures and flows at reactors further downstream which do not possess cooling towers — 2.6GW Saint Alban and 3.6GW Tricastin — are affected by other flows on tributaries to the Rhone, which cool the river down and increase its volume after passing Bugey. By Rhys Talbot Send comments and request more information at feedback@argusmedia.com Copyright © 2025. Argus Media group . All rights reserved.

Australia’s carbon credit supply remains strong in May

25/06/19

Australia’s carbon credit supply remains strong in May

Sydney, 19 June (Argus) — Australian Carbon Credit Unit (ACCU) supply remained strong in May, bringing total issuances over January-May 2025 closer to the combined volume in the first half of 2024, according to data published on 19 June. A total of 2.11mn ACCUs were issued in May, up from 1.99mn in April , register data released by the Clean Energy Regulator (CER) show. This takes total supply over January-May 2025 to 7.15mn, close to the 7.66mn issued in the first six months of 2024. The regulator did not publish monthly data before 2025. Vegetation methods, mainly from human-induced regeneration (HIR) and avoided deforestation (AD) projects, accounted for 1.32mn ACCUs in May, or nearly 63pc of the total. This was up from just 29pc in April, but below shares of around 82-90pc in February and March. Waste methods, mostly from landfill gas projects, made up 670,596 units, or approximately 32pc of the total. Savana burning, agriculture and energy efficiency methods accounted for the remaining issuances in May ( see chart ). The high number of issuances in April was because of a "backlog of crediting applications for waste methods" , which was expected to clear in the second quarter, the CER said last week. A total of 3.04mn ACCUs were issued in the first quarter, and 5mn applications were "on hand" as of 31 March 2025, the regulator said. The CER maintained its supply forecast of 19mn-24mn for 2025. Bioenergy company LMS Energy remained the largest recipient of new ACCUs in May at 329,879 units, followed by environmental market investor GreenCollar's subsidiary Terra Carbon at 315,420 units and waste management firm Veolia at 154,015 units. ACCU spot prices have been stable in June but continued to rise slowly on the month. The Argus ACCU generic no avoided deforestation (No AD) spot price assessments averaged A$35.65/t CO2 equivalent ($23.20/t CO2e) so far in June, up from A$35.35/t CO2e in May and the highest so far in 2025. By Juan Weik ACCU issuance by method type (mn) Send comments and request more information at feedback@argusmedia.com Copyright © 2025. Argus Media group . All rights reserved.

TC Energy targets brownfield expansion growth

25/06/18

TC Energy targets brownfield expansion growth

Washington, 18 June (Argus) — Canada-based TC Energy intends to focus on expansions of its existing natural gas pipeline network in North America to serve growing demand for natural gas service until the mid-2030s, chief executive Francois Poirier said today. TC Energy has a $32bn backlog in capital projects and is looking at an additional $30bn of projects that may not all come to fruition, Poirier said. The company's focus is on increasing capacity through existing pipelines and pipeline corridors, he said, rather than pursuing greenfield projects that require entirely new routes. "Our view is that we're going to be able to prosecute all of that with brownfield expansions," Poirier said in an interview on the sidelines of the Atlantic Council's Global Energy Forum. "The industry has been quite innovative in finding the nooks and crannies to move gas around. So I don't see a need for a big greenfield pipeline until the mid-2030s." Pipeline developers since 2020 have prioritized brownfield projects, after permitting delays and lawsuits delayed or halted proposed pipelines across the eastern US, such as the now-canceled $8bn Atlantic Coast Pipeline. President Donald Trump has pushed to restart new pipeline development, and last month US midstream operator Williams said it was restarting work on the 124-mile (200km) Constitution pipeline and the Northeast Supply Enhancement project. Last month, TC Energy announced a $900mn expansion of its ANR pipeline system in the US Midwest, known as the Northwoods project. TC Energy will focus on those types of brownfield projects until at least the mid-2030s, Poirier said, when the company forecasts gas production in the Hayettesville and Permian basins will reach maturity. At that point, he expects there will more need to transport Appalachian gas to the US Gulf coast, where demand from LNG export terminals is set to increase. "Then the question is going to be, is it economical?" Poirier said. "It's going to depend on the price for Henry Hub [gas]. Right now, the Henry Hub price doesn't support a new greenfield pipeline." Data centers are among the largest drivers of demand growth, Poirier said. In the last three months, TC Energy has seen "quite an acceleration" in demand for gas transportation service from utilities serving that demand, he said. Gas-fired plants are still the fastest way to reliably serve those data centers even though such plants take 3-5 years to build, he said, because renewable power is intermittent and nuclear plants take at least a decade to build. "If you look at the 660 or so data centers under development and construction in the US, about two-thirds are within 50 miles of our pipelines," Poirier said. By Chris Knight Send comments and request more information at feedback@argusmedia.com Copyright © 2025. Argus Media group . All rights reserved.

Poland wraps up CBAM changes with European Parliament

25/06/18

Poland wraps up CBAM changes with European Parliament

Brussels, 18 June (Argus) — Poland has concluded negotiations on behalf of EU member states with the European Parliament for a revised carbon border adjustment mechanism (CBAM), ahead of handing over the bloc's six-month rotating presidency to Denmark at the end of June. But Warsaw will not lead discussions on the EU's emissions cut target for 2040 and the bloc's updated nationally determined contribution (NDC) to the Paris climate agreement. Leading negotiations for EU states with parliament, Poland's deputy climate minister Krzysztof Bolesta said the revised CBAM would exempt 90pc of originally covered EU companies from reporting obligations, while 99pc of emissions embedded in imported products would remain covered. The agreement on CBAM now has to be formally approved by parliament and EU ministers. Once published in the bloc's official journal, the revised CBAM text will exempt importers that do not exceed a new single mass-based threshold of 50 t/yr of imported goods. Bolesta admitted that progress has been held up on concluding the EU's NDC during Warsaw's presidency of EU ministerial meetings. CBAM was also listed by Bolesta as one of the points for flexibility in discussions on the 2040 climate target, alongside carbon credits under Article 6 of the Paris agreement, additional funding and flexibility between climate sub-targets. At a meeting of environment ministers yesterday, Bolesta indicated that most states still favour the European Commission linking its submission of an EU NDC to the UN — which includes a 2035 emissions cut target — with the bloc's planned 2 July proposal for a 2040 EU climate target. The CBAM yesterday contributed to delays in technical negotiations held in Bonn, Germany, for the UN Cop 30 climate conference in Brazil. The Like-Minded Group of Developing Countries, including countries such as Bolivia, China, Saudi Arabia, Cuba and Vietnam, had urged the need to address concerns "with climate change-related trade-restrictive unilateral measures". Despite "very, very divergent views", EU member states agree that it "is absolutely urgent to come up with an NDC before the end of September", Bolesta said. The Polish presidency of the EU, chairing climate ministers' meetings, has advanced NDC work as much as possible in the absence of the commission's proposal to revise the bloc's climate law. "We really have only a couple of months to come up with something. What lacks in the NDC draft is now the headline target," Bolesta said. Countries have not yet discussed the quality of Article 6 offsets, Bolesta added. "Everyone in the room realises that we need to be very stringent on what kind of offset will be let into the system," he said. EU climate commissioner Wopke Hoekstra is "cautiously optimistic" that a landing ground can be found on the 2040 climate target. He called for more assertive climate diplomacy, as a large part of the problem lies outside Europe. For China, Hoekstra noted unfair trade practices and "serious" concerns about plans to build additional coal-fired plants. "It's a mixed bag. And we invite them to step up their ambition," he said. By Dafydd ab Iago Send comments and request more information at feedback@argusmedia.com Copyright © 2025. Argus Media group . All rights reserved.

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