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Investor group urges BP to allow new climate vote

  • : Crude oil, Natural gas, Oil products
  • 25/02/19

A group of 46 BP institutional investors has voiced concerns that the company may ditch a target to reduce its oil and gas production to 2mn b/d of oil equivalent (boe/d) by the end of the decade, urging in a letter to BP chairman Helge Lund that a new shareholder vote be allowed on its net-zero strategy.

The letter's signatories include several UK and European pension fund managers and other investors, including Aegon, Investec and Robeco. It comes ahead of BP's capital markets day on 26 February, when the company has said it will "fundamentally reset" its strategy.

The group calls on BP to give another opportunity to vote on its net-zero plans at its 2025 annual general meeting, pointing out that shareholders in 2022 endorsed a BP plan to cut hydrocarbon production by 40pc, to 1.5mn boe/d, by 2030. That achieved 88.5pc support from shareholders, but the group of investors behind the letter note that nine months later BP revised upwards its target for 2030 to 2mn boe/d.

BP's output averaged 2.36mn boe/d in 2024.

The investors are now concerned that increased spending by BP on oil and gas output, due to subsequent strategy tweaks, will raise "potential exposure to stranded assets as the energy transition progresses."

The letter notes there is opportunity for BP to explain how emissions budgets in Paris Agreement-aligned scenarios are considered in the sanctioning of new projects.

"Showing where projects will sit on the global merit curve of producing assets would also allow investors to assess the relative competitiveness and resilience of BP's portfolio and capital expenditure," it states.

In a statement to Argus a signatory to the letter, Royal London Asset Management, said it recognised BP's past efforts toward the energy transition but it is "concerned about the company's continued investment in fossil fuel expansion.

"If BP has decided to scrap its production target, we seek clarity on how capital allocation will shift to ensure resilience through the energy transition," it said. "Will BP scale up investments in renewable energy, carbon capture, and emerging technologies to future-proof the business against regulatory, market, and climate risks?"

Royal London urged BP "to strengthen governance and transparency around transition planning, ensuring that future capex decisions align with a net-zero pathway rather than locking in further emissions growth."

It added: "Robust oversight and clear long-term strategies are essential to delivering value while managing the risks of an accelerating energy transition."

A BP spokesman said the company had received the letter and "will respond in due course."

Environmental pressure group Greenpeace said BP can expect this kind of pushback and challenge from its shareholders "at every turn if it doubles down on fossil fuels".

"Government policies will also need to prioritise renewable power, and as extreme weather puts pressure on insurance models policymakers will be looking to fossil fuel profits as a way to fund extreme weather recovery," Greenpeace said. "BP might want to seriously put the brakes on this U-turn."

Earlier this month BP's shares jumped on media reports that activist hedge fund Elliott Investment Management was building a stake in the UK major. Investment bank analysts that follow BP expect Elliott to attempt to bring about a boardroom shake-up as it has at other resources companies, including at Canadian oil sands business Suncor Energy in 2022.


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25/05/12

Ukrainian gas imports double in May

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.

Aramco sees 'steady' oil demand growth in 2025


25/05/12
25/05/12

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.

EU, UK diesel imports from Mideast, India fall in April


25/05/12
25/05/12

EU, UK diesel imports from Mideast, India fall in April

London, 12 May (Argus) — Arrivals of diesel and other gasoil in the EU and UK edged lower in April, with high imports from Saudi Arabia's port of Yanbu not fully making up for lower supply from the Mideast Gulf and India. Data from Vortexa show total arrivals at 4.3mn t, lower by 3pc from March on a daily average basis and by 7pc on the year. The Mideast Gulf is the region that has supplied the most to the EU and UK so far this year, stepping up to fill a gap created by weak US arrivals. But market participants said the arbitrage from the Mideast Gulf was shut for most of April. Arrivals from the Mideast Gulf were around 1mn t, dropping by 24pc on a daily average basis from March but only marginally falling from April 2024. Exports from the region probably fell because of maintenance at the 400,000 b/d Rabigh refinery. Geopolitical tensions may have harmed transit through the Bab el-Mandeb strait. The EU and UK imported the largest amount from Saudi Arabia, at 1.3mn t or around 29pc of total arrivals. Around 68pc of Saudi Arabian arrivals, or about 780,000t, came from the Red Sea port of Yanbu, the largest amount from there since December 2020. Yanbu is just south of the Suez Canal, and market participants often treat it similarly to a Mediterranean port when calculating arbitrage economics. Arrivals from India dropped sharply in April, again probably driven by poor arbitrage economics. Arrivals fell by 45pc on the month on a daily average basis and by 33pc on the year, to 455,000t. Only five tankers arrived in the EU and UK from India, compared with 13 in April 2024. Reliance's 1.36mn b/d Jamnagar refinery conducted maintenance on a crude unit in April, and domestic demand reached an all-time high. Imports from the US, the EU's and UK's largest supplier in 2024, remained muted. Arrivals rose by 17pc on the month on a daily average basis to 562,000t, but were still only half the amount of April last year. Spain was the largest EU/UK importer, with 745,000t, the highest since May 2024. Imports may have risen because of maintenance at Repsol's 135,000 b/d Puertollano and 180,000 b/d Tarragona refineries . German arrivals were 493,000t, the highest since January 2023, up by 13pc on the year and more than double levels of March. Shell began to close its 147,000 b/d Wesseling refinery in March, and a turnaround took place at the Bayernoil consortium's 215,000 b/d Vohburg-Neustadt refinery. Demand stepped up, with households taking advantage of lower prices to stockpile product. By Josh Michalowski Send comments and request more information at feedback@argusmedia.com Copyright © 2025. Argus Media group . All rights reserved.

US shale M&A faces headwinds on oil price rout


25/05/12
25/05/12

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.

Saudi Aramco cuts dividend after fall in 1Q profit


25/05/12
25/05/12

Saudi Aramco cuts dividend after fall in 1Q profit

Dubai, 12 May (Argus) — State-controlled Saudi Aramco has announced a sharp cut to its quarterly dividend after reporting a 5pc year-on-year decline in profit for the first three months of 2025. The company's profit fell to $26.01bn in January-March from $27.3bn in the same period last year after lower oil prices squeezed revenues. Aramco said its bottom line was also hit by higher operating costs. The company said it sold its crude for an average $76.30/bl in January-March, down from $83/bl the first quarter of 2024. "Global trade dynamics affected energy markets in the first quarter of 2025, with economic uncertainty impacting oil prices," Aramco's chief executive Amin Nasser said. The company said its overall dividend for the quarter will be $20.61bn, down from $31bn in the corresponding period in 2024. The steep drop is due to the performance-linked element of the dividend being slashed to just $219mn for the quarter, from $10.7bn a year earlier. Aramco already announced in March that it expected its dividends for the full year to fall to $85.4bn from $124.3bn in 2024. Despite the current economic uncertainty, Aramco's capital expenditure (capex) rose to $12.5bn for January-March from $10.83bn in the same period last year, although this puts investment broadly in line with the lower end of the full-year 2025 capex guidance of $52bn-58bn that the company announced in March. The aggressive capex programme will help drive growth plans for the downstream and new energies sides of Aramco's business, as well as fund the firm's strategy to maintain its maximum sustainable crude capacity at 12mn b/d and expand its gas output by 60pc by 2030 compared with 2021 levels. By Nader Itayim Send comments and request more information at feedback@argusmedia.com Copyright © 2025. Argus Media group . All rights reserved.

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