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Canada’s Liberals ahead on election homestretch

  • : 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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25/05/13

Mexico industrial production contracts in March

Mexico industrial production contracts in March

Mexico City, 13 May (Argus) — Mexico's industrial production contracted by 0.9pc in March from the previous month, as declines in mining and manufacturing were only partly offset by continued growth in construction. The drop was not enough to undo the 2.2pc increase in February — the sharpest monthly expansion in four years — as manufacturers ramped up output ahead of incoming US tariffs. The March industrial production index (IMAI), published by statistics agency Inegi, was higher than Mexican bank Banorte's forecast of a 1.4pc decline. Banorte noted signs of volatility affecting manufacturing and other sectors because of a complex trade outlook. Manufacturing contracted 1.1pc in March after expanding 2.9pc in February. The impact varied across subsectors, with metal goods down 5.5pc and transportation, including auto production, down 1.1pc. Volatility may ease in the coming months as US tariff policies become clearer and Mexican officials push to preserve the country's trade edge under US-Mexico-Canada (USMCA) free trade agreement rules, Banorte said. Construction expanded 0.8pc in March, following increases of 3.4pc in February and 0.5pc in January, driven by higher public investment tied to President Claudia Sheinbaum's economic plan, "Plan Mexico." Analysts see the plan as a catalyst for continued growth in construction this year, with measures including greater domestic content in public purchases, public-private participation in infrastructure projects and a target of $100bn in private infrastructure investment for 2025. These effects could be amplified by aggressive interest rate cuts from the central bank. Mining contracted by 2.7pc in March, returning to negative territory after a slight 0.1pc uptick in February. Oil and gas output also contracted 2.7pc after rising 1.0pc the month before, while non-oil mining contracted 4.3pc in March after a 0.6pc increase in February. By James Young Send comments and request more information at feedback@argusmedia.com Copyright © 2025. Argus Media group . All rights reserved.

Namibia expects first oil in 2029-30: Official


25/05/13
25/05/13

Namibia expects first oil in 2029-30: Official

Paris, 13 May (Argus) — Namibia expects first oil and gas from its offshore oil blocks as early as 2029, according to the country's petroleum commissioner Maggy Shino. Oil and gas production is on track to begin by that time, Shino said, with a first field development plan set to be received from TotalEnergies by July. The French major is a stakeholder in the Venus block, which it estimates to contain 750mn bl. The timeline announcement comes as Namibia seeks to accelerate the path to first oil, Shino said. Windhoek is streamlining licensing processes and is encouraging industry to contribute to upstream policymaking, she told the Invest in African Energies forum today. TotalEnergies, which discovered Venus in February 2022, plans to make a decision on whether to begin the development of the field next year. Its chief executive Patrick Pouyanne said he was negotiating with the Namibian government about the development but that discussions were still at an early stage. "It's a project which faces, fundamentally, some challenges, but it's feasible," Pouyanne told analysts on the company's first-quarter earnings call in April . Speaking at the conference, TotalEnergies' senior vice president for Africa, Mike Sangster, said the three wells the company has tested at Venus have demonstrated the need for a lot of gas reinjection, and he said it will be difficult to keep the cost of development down to Pouyanne's publicly-stated $20/bl. Besides upstream investment, Namibia is encouraging investors to consider port and pipeline infrastructure with a particular emphasis on the coastal town of Lüderitz in the southwest. Namibia's new president, Netumbo Nandi-Ndaitwah, placed the country's oil and gas industries under direct presidential control the day after her inauguration in March. Although details of the restructuring have yet to emerge, some stakeholders hope the move will speed up decision making. By George Maher-Bonnett Send comments and request more information at feedback@argusmedia.com Copyright © 2025. Argus Media group . All rights reserved.

US tariff rate drops to 13.1pc after trade truce: Fitch


25/05/12
25/05/12

US tariff rate drops to 13.1pc after trade truce: Fitch

New York, 12 May (Argus) — The US tariff rate on all imports fell to 13.1pc from 22.8pc after China and the US agreed to a significant de-escalation in their trade dispute over the weekend, according to rating agency Fitch. Even so, a rate of around 13pc was last seen in 1941 and remains much higher than the 2.3pc at the end of 2024, Fitch said. The rate represents total duties as a percentage of total imports and changes, with shifts in import share by country of origin and product mix. The US effective tariff rate for China remains the highest at 31.8pc, reflecting duties imposed on China before 2 April, as well as a 10pc baseline tariff imposed on most countries. That was down from 103.6pc. Japan, Mexico, Canada and Germany, which have the next highest exports to the US, have effective tariff rates in excess of 10.5pc. As a result of the breakthrough over the weekend, the US will reduce punitive tariffs on imports from China to 30pc , with Beijing keeping in place retaliatory tariffs of 10-15pc on most US energy and agricultural commodities. By Stephen Cunningham Send comments and request more information at feedback@argusmedia.com Copyright © 2025. Argus Media group . All rights reserved.

Naphtha no longer competitive feedstock: Braskem


25/05/12
25/05/12

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.

Ukrainian gas imports double in May


25/05/12
25/05/12

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.

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