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EU parliament to favour e-fuels, hydrogen: EPP lawmaker

  • Market: Biofuels, Hydrogen, Natural gas
  • 10/06/24

EU parliament to favour e-fuels, hydrogen: EPP lawmaker

The new EU parliament will be more pragmatic in 2024-2029, favour continuation of the internal combustion engine (ICE) beyond 2035 as well as more flexible rules for low-carbon hydrogen, e-fuels, biofuels, and other CO2-neutral fuels, outgoing member of the European Parliament Markus Pieper told Argus. The centre-right European People's Party (EPP) MEP was the key lawmaker behind the EU's revised renewable energy directive.

Will the next parliament favour renewable liquid fuels in spite of provisions for an ICE phase-out?

For me, the end of the internal combustion engine (ICE) has not been decided yet. The next European Parliament will likely have a majority supporting the continuation of ICE beyond 2035. This would provide planning security for investments in innovation and facilities for e-fuels, biofuels, and other CO2-neutral fuels, including power-to-x (P2X) fuels. Instead of an outright ban on combustion engines, there should be a phase-out of fossil fuels, enabling us to achieve climate targets more quickly and cost-effectively, without overloading power grids. We need to start working on a clear legal framework today. The blending of new fuels must be standardised and regulated.

Do you see the EU parliament favouring greater flexibility in the conditions for renewable hydrogen?

Yes, we have a review clause in the renewable energy directive, whereby the European Commission shall submit a report to council [of ministers] and parliament by 1 July 2028. If this assessment indicates that we cannot achieve targets for green hydrogen in industry due to a lack of supply, then we must adjust the definition of green hydrogen. If we do not adapt, the industry may relocate to regions with fewer environmental regulations. We need to be flexible in our legislation and ready to adjust rules due to worldwide competition.

How can a new EU parliament improve on existing legislation for 2030 climate and energy goals?

The magic word is technological openness. We need to get the best out of all energy resources. Additionally, we need to invest significantly more in the energy transition, especially in the expansion of cross-border green electricity projects. The new European Parliament will likely be more pragmatic and realistic in its energy goals.

Does the EU need to rethink the 2040 goals?

There's no need to rethink the 2040 CO2 reduction target of 90pc [compared with 1990 levels]. But we need to rethink how to achieve goals and keep a close eye on China and India. Europe must constantly redefine and adapt legislation as necessary. One crucial step is reaching new trade arrangements [to balance higher EU climate standards for domestic industry than global competitors]. We have to be more realistic.

Do you think EU 2030 targets for hydrogen are too ambitious?

Yes, the target for green hydrogen to represent 42pc of hydrogen used by industry in 2030 is too ambitious from today's point of view. And I currently don't see the capacity to produce enough hydrogen in Europe. As for imports, non-EU producers often do not meet the same standards for producing green hydrogen. This means we'll need to adapt our definition of green hydrogen and consider more low-carbon solutions. The Paris Climate Agreement remains our primary goal. If we can achieve these goals with low-carbon hydrogen, why not? Still, it remains possible to meet the 2030 green hydrogen targets if we adapt the definition.


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25/04/25

Canada H2 sees opening as political chaos engulfs US

Canada H2 sees opening as political chaos engulfs US

Houston, 25 April (Argus) — Canada's hydrogen sector sees an opportunity to attract global customers as the US' bellicose stance toward its northern neighbor unites Canadians behind strengthening its energy capacity and as US political turmoil sends countries looking for other trading partners. "The mayhem south of the border has created a real national interest in exports," Trigon Pacific Terminals chief executive Robert Booker said this week at the Canadian Hydrogen Convention in Edmonton, Alberta. Trigon is building a berth at the port in Prince Rupert, British Columbia, to handle low-carbon hydrogen converted to ammonia. "The choice, quite frankly, is become the 51st state or export," Booker said. "We should export, and there's broad understanding that that's good for Canada." Canadian energy exports from Alberta have largely gone south to the US. Ambitions to tap global markets have been stymied in years past by community and federal opposition to building rail and pipeline infrastructure that would connect the landlocked province to the Pacific coast. Multiple large-scale hydrogen proposals in western Canada were quietly shelved in the past year because of a lack of infrastructure, among other challenges, and Canadian companies were shut out of recent Asian auctions to buy hydrogen because of similar restraints. But Trump's return to the White House has changed Canadians' views on export infrastructure. Both candidates in the upcoming 28 April general election, including Liberal Prime Minister Mark Carney who served as UN Special Envoy for Climate Action, have vowed to build out pipelines , rail corridors and other infrastructure — including electricity grids — to diversify energy exports away from the US. "We've never been this united in the country," said Julie Lemieux, chief executive officer of Triple Point Resources, which is developing a salt dome in Newfoundland for hydrogen storage. "That's the positive of the chaos. We've been notoriously slow to approve these projects and invest in infrastructure. Whoever wins next week, they've all committed to investing in infrastructure." Panelists speaking in Edmonton expressed relief that Canada didn't follow the US example of putting tariffs on China, whose technology and components will be instrumental to containing costs while building Canadian infrastructure. "For better or worse, whatever your opinion, the build out of new infrastructure today is really dependent on China, especially when it comes to green infrastructure, where there's already an embedded green premium," said Matthew Borys, vice president of corporate development at EverWind Fuels. "Keeping the cost down is super important to getting these things built out." The Trump administration's preference for fossil fuel extraction over clean energy and its expansionist designs on the Panama Canal are also seen as opportunities for Canadian developers to attract Asian customers who could avoid the canal by exporting from British Columbia terminals, said James Vultaggio, vice president of Atco EnPower. "The administration to the south is focused more on fossil fuel production and reducing environmental regulations," Vultaggio said. "If they want to cede their seat as a clean energy leader, then Canada has an opportunity to fill that seat, and we should take it." Trump has been outspoken in his preference for fossil fuel extraction and has paused all federal clean energy disbursements related to the Inflation Reduction Act, which has raised doubts about whether US hydrogen hubs can survive as they were initially conceived during the administration of former president Joe Biden. Clean energy incentives such as the 45V hydrogen production tax credit have also come under scrutiny as the Trump administration seeks to shrink government spending. The uncertainty around clean energy incentives in the US may well send American investment north, said Denis Caron, chief executive of the Belledune Port Authority in eastern Canada's New Brunswick province, which is positioning itself as a green energy hub targeting European markets. Caron said an American company working with the port of Belledune remains bullish on its prospects there and could serve as a model to attract even more American investment if the US continues to claw back support for clean energy. "We see an opportunity to attract American investment to Canada and make those types of investments," Caron said. "Canada has a golden opportunity to fulfill the requirement of supplying clean and green energy products globally." By Jasmina Kelemen Send comments and request more information at feedback@argusmedia.com Copyright © 2025. Argus Media group . All rights reserved.

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SLB taking steps to offset tariffs: Update


25/04/25
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25/04/25

SLB taking steps to offset tariffs: Update

Adds details from call. New York, 25 April (Argus) — Oilfield services contractor SLB said it is taking proactive steps to offset the impact of US tariffs by reviewing its supply chain and manufacturing network, pursuing exemptions and talking to customers to recover related cost increases. "We have made progress on all these fronts in the last two weeks, and we are stepping up those actions across the organization as we speak," chief financial officer Stephane Biguet told analysts after the company reported first quarter results today. SLB is partly protected from the overall tariff fallout given 80pc of total revenue comes from international markets, as well as its in-country manufacturing and local sourcing efforts. But other areas are exposed to increasing tariffs, such as imports of raw materials into the US, as well as exports from the US subject to retaliatory action. Under the current tariff framework, most of the likely effects come from trade activity between the US and China. "As the second quarter progresses and ongoing trade negotiations continue, we will hopefully gain better visibility of where tariffs may settle and the extent to which we will be able to mitigate their effects on our business," Biguet said. In the current climate, SLB says customers are likely to take a more cautious approach to near-term activity. Given industry headwinds from volatile oil prices and demand risks, SLB expects global upstream investment to decline this year from 2024, with customer spending in the Middle East and Asia holding up better than elsewhere. SLB reported a "subdued" start to the year as revenue fell 3pc in the first quarter from the same three months of 2024. The company noted higher activity in parts of the Middle East, North Africa, Argentina and offshore US, along with strong growth in its data center and digital businesses in North America. However, those gains were more than offset by a larger-than-expected slowdown in Mexico, a slow start in Saudi Arabia and offshore Africa, and a steep decline in Russia. Even so, SLB remains committed to returning a minimum of $4bn to shareholders through dividends and share buybacks this year. "The industry may experience a potential shift of priorities driven by changes in the global economy, fluctuating commodity prices and evolving tariffs — all of which could impact upstream oil and gas investment and, in turn, affect demand for our products and services, said chief executive officer Olivier Le Peuch. "In this uncertain environment, we remain committed to protecting our margins, generating strong cash flow and delivering consistent value." First quarter profit of $797mn was down from $1.07bn in the same three months of 2024. Revenue of $8.5bn compared with $8.7bn last year. SLB is the last of the top oilfield services firms to post first-quarter results. Halliburton and Baker Hughes reported earlier this week. By Stephen Cunningham Send comments and request more information at feedback@argusmedia.com Copyright © 2025. Argus Media group . All rights reserved.

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Danish H2 sector criticises country's mandate draft


25/04/25
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25/04/25

Danish H2 sector criticises country's mandate draft

London, 25 April (Argus) — Industry group Hydrogen Denmark and some of its member companies have criticised the country's draft to transpose EU hydrogen transport targets into Danish law, and have urged Copenhagen to adjust the rules before they are finalised in May. Companies with hydrogen projects, including Everfuel, Copenhagen Infrastructure Partners and European Energy, signed an open letter calling for changes, as did fuel producer Crossbridge Energy, which runs the 67,000 b/d Fredericia oil refinery and has an offtake deal for hydrogen from Everfuel. The group said Denmark's targets are unambitious and too low to spur significant demand and help the country realise its goal to export 'green' energy. The draft rules would effectively mean Danish fuel companies supply 1pc renewable hydrogen and derivatives to the transport sector by 2030, which was the minimum goal set by Brussels. The group urged Denmark to aim above the EU target, following member states like Finland that has set a 4pc target . The group also wants Denmark to phase in the quota with incremental increases each year until 2030 starting as early as 2026, to aid first-mover projects and generate experience that ensures Denmark can successfully meet the binding EU target that starts in 2030. The group also warned Denmark must not exclude use of subsidised hydrogen from counting towards transport targets. This would ruin the business case for many hydrogen production projects and could steer Danish producers towards exports and mean Denmark effectively subsidises neighbours like Germany to meet its own mandates, it said. The group's concerns stem from language around 'supported' projects in the draft text, which it understands to refer to state aid. If left unchanged, the rule would affect projects that Denmark has subsidised through its power-to-X tender and Danish projects that may hope to benefit from EU-level funds like the European Hydrogen Bank or the Innovation Fund. The industry group praised Copenhagen's plan to allow renewable hydrogen switching in refineries to count towards the targets. This mechanism, known as the refinery route in some European countries, has been called "elegant" by market participants because it should raise demand for hydrogen in the near term and is a logistically simpler way to cut CO2 than converting refuelling stations and vehicle fleets to use hydrogen. Denmark appears to have allowed the rule without limiting the value of credits, unlike the Netherlands where a 'multiplier' rankled industry participants . Allowing the refinery route will probably please Everfuel and Crossbridge Energy, as the latter had complained Denmark was not supporting its refinery 20MW fuel switching project unlike EU peers. Copenhagen had planned to set the draft mandates into law by 21 May — the deadline set under the EU's revised renewable energy directive (REDIII) — but it remains to be seen if it will press ahead with this timeline given industry has demanded changes. By Aidan Lea Send comments and request more information at feedback@argusmedia.com Copyright © 2025. Argus Media group . All rights reserved.

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Kurdish gas plans may boost Iraqi oil exports


25/04/25
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25/04/25

Kurdish gas plans may boost Iraqi oil exports

Dubai, 25 April (Argus) — Plans for a significant increase in natural gas production in Iraq's semi-autonomous Kurdistan region over the next 18 months could not only help address the country's chronic power shortages but also enable Baghdad to boost its oil exports. The Pearl Petroleum consortium — which comprises Abu Dhabi-listed Dana Gas, Sharjah-based Crescent Petroleum, Austria's OMV, Hungary's Mol, and Germany's RWE — aims to increase gas production capacity in Kurdistan to 825mn ft³/d by the end of next year, representing a more than 50pc increase from current output. The plan involves expanding the capacity of the region's sole gas-producing field, Khor Mor, to 750mn ft³/d by the first quarter of 2026, and adding up to 75mn ft³/d from the Chemchemal field by the end of 2026. According to a source at Pearl, the development of Chemchemal is a key priority for the companies, as it is believed to have reservoirs comparable to those of Khor Mor. Under a 2019 agreement, the additional gas from the expansion project will be sold to the Kurdistan Regional Government (KRG) for a 20-year term, which should help eliminate the region's frequent power outages, particularly during peak summer months when demand for air conditioning is high. The Kurdistan region will also be well-positioned to supply any excess gas to the rest of Iraq. The federal government in Baghdad had previously approved a plan to import approximately 100mn ft³/d of gas from Khor Mor to power a 620MW plant in Kirkuk province, but no formal agreement has been signed to date. "The federal ministry of electricity and Crescent Petroleum have already met to finalise the agreement, which is ready for signature and awaiting implementation," the Pearl source said. "The infrastructure needed to support the sale of this quantity of gas is also in place." The plan has faced delays partly because of Iran's long-standing influence over Iraq and the potential impact such an agreement with the Kurdistan region could have on Baghdad's reliance on Iranian gas and power. However, the revival of US president Donald Trump's ‘maximum pressure' campaign against Tehran is forcing Baghdad to get serious about seeking alternative energy sources, with the Kurdistan region emerging as a viable option. Crude Export Boost Formalising the deal to import Kurdish gas would allow Baghdad to allocate more oil for export, as it would reduce the need to burn crude for power generation. Argus estimates that Iraq typically burns between 50,000 b/d and 100,000 b/d of crude in its power stations, depending on the season, and has recently increased imports of gasoil for power generation. By the time Iraqi Kurdistan has fully ramped up its additional gas capacity, Iraq's Opec+ crude output target will be 200,000 b/d higher than it is today, based on the group's latest production plans. By Bachar Halabi and Nader Itayim Send comments and request more information at feedback@argusmedia.com Copyright © 2025. Argus Media group . All rights reserved.

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Investment funds slash net long position on Ice TTF


24/04/25
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24/04/25

Investment funds slash net long position on Ice TTF

London, 24 April (Argus) — Investment funds have slashed their TTF net long positions on the Intercontinental Exchange (Ice) nearly in half so far in April, with commercial undertakings' net long position conversely rising. Investment funds' net long position on Ice dropped to 86TWh in the week ending 17 April, well below the 146TWh at the end of March, and was as low as 73TWh on 11 April ( see net positions graph ). The near-halving of their net position was driven entirely by the closing of longs, which dropped to 308TWh by 17 April from 383TWh on 28 March. In contrast, shorts dropped by only 16TWh in the same period, the exchange's most recent Commitments of Traders report shows. This left investment funds' total amount of open positions at 529TWh by 17 April, well down from 620TWh on 28 March. Global commodity market turmoil in recent weeks following the US' ‘liberation day' on which president Donald Trump announced tariffs on nearly every country may have prompted funds to reduce their exposure to gas market. The resulting fallout in global commodity, stock, bond and currency markets would have hit multi-strategy hedge funds in particular, which had exposure to many different assets, some of which are thought to be among the largest players in the overall investment fund category of participant. Wider macroeconomic factors rather than market fundamentals have driven the TTF this month, according to many traders, with daily TTF movements frequently having tracked wider moves across global macroeconomic indicators such as the S&P 500 index. In contrast with investment funds' sharply reduced net long position, commercial undertakings — the other largest category of market participant, mostly comprising firms with retail portfolios — more than doubled their net long position to 85TWh on 17 April from 33TWh on 28 March. This means commercial undertakings' and investment funds' net positions now have nearly exactly converged, with the difference between them having been as wide as nearly 350TWh as recently as early February. Commercial undertakings first flipped to a net long position in the week ending 28 February, and the net long has steadily increased every week since then. While investment funds significantly reduced their overall exposure to the TTF, commercial undertakings increased both their long and short positions in April. Total shorts rose by about 34TWh between 28 March and 17 April to 1.055PWh, while longs soared by 86TWh to 1.140PWh. This leaves their total open positions at about 2.195PWh, more than quadruple investment funds' 529TWh. The data could suggest that commercial undertakings took advantage of hedge funds unwinding their long positions, leading to a reallocation of about 90TWh of liquidity from speculative positions to risk reduction contracts. The large majority of commercial undertakings' overall open positions are risk reduction contracts, which total 1.457PWh out of aggregate open positions of 2.195PWh, or 66pc. In contrast, investment funds hold zero risk reduction contracts, making it likely that all of their interest is speculative. Commercial undertakings' risk reduction shorts increased only by about 7TWh between 28 March and 17 April to 747TWh, but longs soared by 92TWh over the same period to an all-time high of 710TWh. As recently as 28 February, risk reduction longs were as low as 550TWh, meaning an overall increase of nearly 200TWh in less than two months. The only other time in recent history when risk reduction longs increased at such a rapid pace was in 2018, when they jumped from 445TWh on 30 July to a peak of 644TWh on 15 October ( see risk reduction graph ). One explanation for such a distinct increase in risk reduction longs while shorts remained roughly even could simply be that utilities have purchased winter contracts instead of the more usual practice of hedging physical gas bought for summer injection by selling winter contracts. Typically, summer prices are below winter thanks to lower seasonal consumption, so a utility would buy the summer to inject the gas and sell the winter for when it will be withdrawn, locking in a profit margin. But because summer prices this year remained above winter, there was no commercial incentive to lock in a negative spread, meaning utilities may simply have opted to buy winter contracts to cover their expected demand. But since the turn of April, TTF summer-month prices have increased their discount to the front-winter, providing more of an incentive to inject gas. By Brendan A'Hearn Net positions on ICE TTF TWh Commercial undertakings' risk reduction positions TWh Send comments and request more information at feedback@argusmedia.com Copyright © 2025. Argus Media group . All rights reserved.

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