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Canada’s Liberals ahead on election homestretch

  • Market: Crude oil, LPG, Natural gas
  • 25/04/25

Both parties push the need for new investment to tap non-US energy markets, but project permitting policy is a key differentiator, writes Brett Holmes

Canada's Liberal party is positioning itself to receive a fourth straight mandate on 28 April, but it must first fend off a late push by the Conservatives in an election campaign that has been closely watched by the energy sector.

The Liberals have benefited from the selection of a new leader in Mark Carney last month, combined with a considerable foe to rally against — US president Donald Trump and his verbal and economic attacks on Canada. While campaigning, Carney has tried to keep the focus on Trump's annexation and economic threats, but momentum has seemingly stalled. The Liberals led the Conservatives by a 42:38 margin on 24 April, but this is three points less than 10 days earlier, according to poll aggregator 338Canada.

The tight race has already motivated a record 7.3mn electors to cast their vote at advance polls, and the energy industry has kept a close eye on promises made by both Carney and his challenger, Conservative leader Pierre Poilievre. Both agree that pivoting away from a hostile US is critical, and that new trade corridors to Canada's coasts are key to reaching more reliable partners. But executives from major Canadian energy companies point out that there is likely to be lower-hanging fruit that can attract investment in a country where productivity has been lagging its peers. Industry leaders have pleaded for government to "reset its policies", which Carney seems less inclined to do than Poilievre.

Carney sees a future where foreign countries will demand less carbon-intensive oil and gas, meaning a proposed cap on the industry's emissions would be implemented as planned, and support for carbon capture projects would continue under a Liberal government. An overhaul of Canada's Impact Assessment Act is unnecessary, Carney says, suggesting the legislation sets major project proponents up for success because its rigour helps to avoid court battles.

But the Canadian Association of Petroleum Producers (Capp) points to that legislation as the top reason why C$280bn ($200bn) of oil and gas projects were cancelled over the past decade. Repealing the law was among the "demands" Alberta premier Danielle Smith made to Carney in March, but the latter seems content to hang on to many of former prime minister Justin Trudeau's energy policies. Carney was born in Alberta, but familiarity has yet to translate into co-operative relations between federal and provincial government. Yet his desire to build new conventional energy projects marks a key departure from Trudeau.

Build, baby build

"I'm interested in getting energy infrastructure built," Carney said during the 18 April leaders' debate. "That means pipelines, that means carbon capture and storage, that means electricity grids." And the Liberals are prepared to use federal emergency powers, but consent from provinces would still be required.

The Conservatives pitch an accelerated six-month regulatory review period to "unleash" Canada's energy so as to stand up to the likes of Trump from a position of strength. The Conservatives tout shovel-ready projects that would kick-start construction as soon as they are approved by a new government. Capp estimates that Canada has C$50bn of energy investment waiting approval.

"For three Liberal terms, Canada has had the worst GDP per capita in the G7," Poilievre says. The National Bank of Canada says this primarily reflects Canada's lacklustre investment and productivity over the past decade. Canadian think-tank CD Howe Institute says this cycle can be corrected by a full overhaul of government policy, including the acceleration of permitting for major private-sector projects. Eliminating current and proposed Liberal policy would be among Poilievre's first moves to resurrect investment.


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Naphtha no longer competitive feedstock: Braskem


12/05/25
News
12/05/25

Naphtha no longer competitive feedstock: Braskem

Sao Paulo, 12 May (Argus) — Brazil-based petrochemical producer Braskem is pursuing a strategic shift in polymers production by favoring natural gas liquid (NGL) feedstocks and moving away from naphtha. Naphtha is no longer a competitive feedstock in the petrochemical sector, driving the need for greater flexibility in raw material sourcing, chief executive Roberto Ramos said Monday on the company's first-quarter earnings call. The transition to lighter feedstocks is part of a broader initiative to enhance efficiency, reduce costs, and improve competitiveness amid evolving global petrochemical dynamics, Ramos said. The company's plan focuses on increasing the use of ethane and propane as primary feedstocks in Mexico and Brazil. In Mexico, Braskem has inaugurated an ethane import terminal, which will provide a stable supply to its operations. The facility has the capacity to store 80,000 b/d of ethane, while the polyethylene (PE) plant processes 66,000 b/d. This surplus storage has prompted considerations for a new PE unit in Mexico to maximize the available feedstock. In Brazil, Braskem aims to reduce reliance on naphtha-based PE production by integrating more natural gas-derived inputs. The company is evaluating projects to utilize feedstocks sourced from shale gas extracted in Argentina's Vaca Muerta formation. The petrochemical complex in Rio Grande do Sul, which operates with a mixture of naphtha and natural gas, is among the facilities targeted for increased gas utilization. Braskem's Rio de Janeiro facility is also undergoing expansion of its gas-based assets, adding two new furnaces that crack ethane and propane to increase capacity to 700,000 t/yr. This increased production is anticipated to lower unit production costs and improve profitability. The move to gas-based production is expected to optimize operations and align Braskem's facilities with cost-effective supply chains, Ramos said. The shift comes as global trade dynamics continue to influence raw material availability. While US-China trade agreements have temporarily eased tariff pressures, Braskem is trying to position itself to navigate long-term supply chain uncertainties by diversifying its production inputs. Ramos has also indicated potential investments in ethanol dehydration technology, which would allow select facilities to convert ethanol into ethylene, further supporting PE production with an alternative renewable feedstock. Production and sales Braskem said its first-quarter domestic resin sales fell by 4pc from the same period in 2024, but sales were little changed from the prior quarter. Domestic resin sales totalled 807,000 metric tonnes (t) in the first quarter, down from 839,000t a year earlier. Resin sales volumes remained in line with the fourth quarter last year, but the company highlighted a quarter-on-quarter increase in PE and polypropylene (PP) sales volumes of 2pc and 3pc, respectively, offset by a 16pc reduction in PVC sales. In Mexico, Braskem Idesa's PE sales fell by 11pc from the same period in 2024 and by 5pc quarter-on-quarter, as the company is looking to manage inventory ahead of a planned maintenance shutdown in the second quarter. The plant utilization rate reached 79pc, rising from the fourth quarter on higher ethane availability through the Fast Track solution. But utilization fell by four percentage points year-on-year, mainly due to reduced supply of ethane from Mexico's Pemex. Braskem posted a first-quarter profit of $114mn, rebounding from a loss of $273mn a year earlier and a loss of $967mn in the fourth quarter last year. By Fred Fernandes Send comments and request more information at feedback@argusmedia.com Copyright © 2025. Argus Media group . All rights reserved.

News

Ukrainian gas imports double in May


12/05/25
News
12/05/25

Ukrainian gas imports double in May

London, 12 May (Argus) — Ukraine's gas imports have nearly doubled in the first 10 days of May from April, although still only the Polish and Hungarian routes are being used. Ukraine's net imports — after netting off inflows and outflows to and from Moldova — averaged 140 GWh/d on 1-10 May, nearly double the 73 GWh/d average in April, the latest available data from transmission system operators show. The increase has been driven by flows from Hungary at VIP Bereg rising to near full capacity of 103 GWh/d from 60 GWh/d, and a smaller 12 GWh/d increase from Poland ( see flows graph ). Net flows to Moldova also fell to 13 GWh/d from 23 GWh/d, leaving more gas in Ukraine. But imports would need to ramp up significantly to match the 4.6bn m³ that state-owned incumbent Naftogaz estimated would be needed over the entire summer. If Ukrainian net imports remain at 140 GWh/d until 15 October, around the typical start of the heating season, then cumulative net imports would reach around 22TWh, or around 2.1bn m³ using Ukraine's standard 10.5 kWh/m³ conversion rate. VIP Bereg is already flowing at near maximum capacity, as is the interconnection point with Poland, meaning that any additional flows will need to arrive from Slovakia at Budince or from Romania at Isaccea, both particularly expensive transit routes. Demand for third-quarter capacity along the Bereg route continues to outstrip available capacity, with the auction now in its sixth day and still not concluded. So far, Naftogaz has announced few public supply deals, although it has contracted 300mn m³ of LNG from Poland's Orlen , with some market participants saying Orlen would supply as much as 1bn m³. The firm has €410mn in funds from the European Bank for Reconstruction and Development , which it hopes will finance the purchase of around 1bn m³. But it is unclear where funding for additional purchases will come from, and the government does not intend to increase household or business tariffs to cover Naftogaz's higher costs. Even if Ukraine imports as much as Naftogaz said it will need, the country could still face shortages in the winter . Ukraine started the injection season in mid-April at the lowest stock level in at least a decade , and while Naftogaz managed to restore more than half of the output it lost in February following attacks on its production infrastructure, Ukrainian production still remains well below pre-2022 levels. Hungary maintains pivotal hub role Hungary has become an increasingly important transit hub over the past year, and Ukraine's import needs have increased its prominence further. With VIP Bereg at a 99pc utilisation rate this month and continued exports northward to Slovakia, Hungary has been pulling in more gas from other sources to maintain these flows. Inflows from Serbia at Horgos, where Russian gas arrives into Hungary through Turkish Stream, rose to 244 GWh/d on 1-10 May from 223 GWh/d in April, just below the point's technical capacity of 246 GWh/d. And inflows from Austria have also increased considerably, rising to 139 GWh/d from 92 GWh/d, while receipts from Romania more than doubled to 40 GWh/d from 19 GWh/d ( see Hungarian flows graph ). Hungarian prompt prices have risen to a premium over Austria and Romania in order to attract more gas ( see prices graph ). Slovakia remains at a premium to Hungary, though, driven by the need to incentivise flows from Hungary now that Russian transit through Ukraine has ceased. Hungarian transmission tariffs remain significantly cheaper than in Slovakia or Romania, so demand for Hungarian capacity at quarterly auctions last week held strong . The bookings suggest that the recent flow configuration is set to continue in the second half of summer, with all import capacity from Serbia booked and most available capacity from Austria. The export route from Romania to Ukraine remains unpopular, not just because of the high transmission tariffs paid in Romania and Moldova, but also because of the conditional nature of the flows. An equal amount of gas must be brought into Romania at Negru Voda 1 as is exported at Isaccea 1, as they are part of the same Trans-Balkan Pipeline string. Additionally, anyone hoping to bring gas from Greece or Bulgaria up to Ukraine must secure capacity in as many as 10 or more auctions, which take place simultaneously given that the transit route crosses in and out of Moldova several times. Even one failed auction could make exports along this route impossible. By Brendan A'Hearn Hungarian DA vs nearby markets €/MWh Ukrainian net flows by point GWh Hungarian net flows by point GWh Send comments and request more information at feedback@argusmedia.com Copyright © 2025. Argus Media group . All rights reserved.

News

Aramco sees 'steady' oil demand growth in 2025


12/05/25
News
12/05/25

Aramco sees 'steady' oil demand growth in 2025

London, 12 May (Argus) — Global oil demand is on course for "steady growth" this year despite uncertainties over trade, according to state-controlled Saudi Aramco's chief executive Amin Nasser. "For the second quarter we are seeing resilient growth despite the impact of tariffs and the uncertainty that we are seeing in the market," Nasser said on Aramco's first-quarter earnings call today. "The fundamentals are very strong." The outlook for the global economy has deteriorated since US president Donald Trump announced a wide array of import levies in April. But the US and China today announced a deal to reduce some bilateral tariffs . And talks with other countries continue. Oil demand could increase more than currently anticipated depending on the result of trade talks, Nasser said, adding that Aramco estimates oil demand grew by 1.7mn b/d in the first quarter compared with the same period last year. Asia is responsible for most of the demand growth, but there is also an uptick in the US, particularly in demand for transport fuels, Nasser said. By Aydin Calik and Nader Itayim Send comments and request more information at feedback@argusmedia.com Copyright © 2025. Argus Media group . All rights reserved.

News

US shale M&A faces headwinds on oil price rout


12/05/25
News
12/05/25

US shale M&A faces headwinds on oil price rout

New York, 12 May (Argus) — Dealmaking in the US shale patch, which had been on a roller-coaster ride in the past few years, is at risk of grinding to a halt as a result of an oil price slump. Just as a growing number of producers are unveiling plans to cut spending and slow activity as crude prices teeter around levels needed to profitably drill wells, prospects for mergers and acquisitions (M&A) in the shale patch are also souring. That marks a departure from the start of 2025 , when dealmakers were expecting a bumper year with recent acquirers looking to offload non-core assets and private equity gearing up to make a return after raising new funds. April brought five deals with a combined value of $2.3bn, bringing the year-to-date total for M&A activity in the US upstream space to $19.2bn, consultancy Enverus says. That was down by 60pc from a year earlier, when the latest round of consolidation was in full sway. "We're just hearing over and over again, across the board, that companies are overwhelmingly sitting on their hands," law firm Sidley partner Stephen Boone says. Recent deals include natural gas giant EQT buying the upstream and midstream assets of privately held Olympus Energy for $1.8bn . Gas is increasingly likely to dominate dealmaking going forward, as not only has the commodity fared better than oil on a relative basis, but investors are likely to be drawn by the US LNG boom and rapid growth of gas-fired power generation demand to meet the energy needs of data centres required for artificial intelligence . "The trouble is, there aren't enough potential gas deals to make up for a drop in oil asset activity, which we do anticipate is going to fall off a cliff," Enverus principal analyst Andrew Dittmar says. Aside from the trade tariff-induced market volatility that has sent crude prices tumbling to four-year lows, a lack of high-quality targets on the oil side also suggests deals will be few and far between this year. Most publicly-held operators will be focused on protecting their bottom line as they remain focused on shareholder returns rather than growth, and might well be reluctant to take on debt to fund deals. And private equity may prefer to bide its time. "That group is likely looking for some sign of a bottom on crude before jumping in, rather than trying to catch a falling knife of asset values," Dittmar says. That is not to say that deals have completely dried up, with Permian Resources agreeing this week to snap up assets in the New Mexico part of the top US shale play from APA for $608mn. But Diamondback Energy, a top Permian producer which has played an active role in the most recent round of M&A, might sum up the view of many with its plan to remain on the sidelines for the time being. Too much noise "We're in the period right now where there's so much noise and volatility that not a lot gets done," Diamondback's president, Kaes Van't Hof, says. "Anything that we would look at would have to be extremely cheap, and I just don't think we're there yet today." Even if some relief comes on the tariff front and the economy avoids a recession, it will take time for deals to pick up again, and that could push a resurgence in dealmaking well into 2026. The fact that public operators have spent the years since the pandemic on repairing balance sheets and focusing on investor payouts might also count against any uptick in transactions anytime soon. "That's actually going to keep M&A down, because now that we see the downturn, we have significantly less distressed companies out there that will be forced to sell, and we have more and more companies that think they are better situated to just ride it out," Sidley's Boone says. 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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