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US upstream oil companies downplay Biden risk

  • Spanish Market: Crude oil, Natural gas
  • 10/08/20

US oil and gas producers may have cheered the regulatory rollback of President Donald Trump's administration, but many are describing the prospect of a Democratic administration next year as a manageable risk.

A proposal by presumptive Democratic nominee, former vice-president Joe Biden, to ban new oil and gas permits on federal lands will have the biggest impact, with nearly 22pc of US oil output coming from federally owned land, much of it offshore the Gulf of Mexico. But recent interest in the offshore has been limited, and executives sound sanguine about US political prospects.

"Despite all the rhetoric we hear from the politicians, our view out there is it's pretty safe," leading upstream independent ConocoPhillips' chief executive, Ryan Lance, says. His firm is the largest oil producer in Alaska, with a significant position in the state's National Petroleum Reserve, where he says the most prospective acreage is already under lease. Even a ban on its federal land in New Mexico would be a minor concern. "If we were unable to drill on federal lands completely in New Mexico, we could just substitute that with non-federal lands for the next 10 years," chief operating officer Matthew Fox says.

Regardless, some firms are trying to secure as many federal permits as possible before November. Devon Energy, with about 20pc of its acreage on federal land, has been working quickly to get drilling permits approved. It is targeting over 550 new permits by this autumn, covering 75pc of its most prospective federal acreage.

Devon chief executive David Hager says that federal permits are eligible for two-year extensions — a routine process under any administration. "We've never been declined an extension," Hager says. "And, importantly, the environmental assessments that underlie those permits are good for a period of five years."

Concho Resources has enough permits on its federal land in New Mexico for another 1-2 years of drilling, but has developed scenarios in case it cannot drill there over the next five years. "We feel confident we can quickly shift our capital to other acreage in our portfolio without any significant impact to our capital efficiency over that period," chief operating officer Will Giraud says. About 20pc of Concho's acreage is on federal land.

A lighter shade of green

Biden's energy platform has taken some of the steam out of his most vociferous opponents by not endorsing the Green New Deal touted by many of the most progressive lawmakers in the Democratic party. He also says a hydraulic fracturing ban is not on the table, and focuses more on cutting power-sector CO2 emissions and restoring previously approved fuel-efficiency standards in cars. Biden can also remind the industry he was in the White House when the de facto 40-year ban on US crude exports was lifted, the path for LNG exports cleared and the first permit to drill in US Arctic Ocean waters granted.

Even Continental Resources chairman Harold Hamm, who has been a close advisor to Trump, concedes that Biden has backed off positions seen as most threatening to the industry. Hamm remains confident that Trump will be re-elected.

But other executives point to polls favouring his opponent. "It's obvious unless something happens we'll probably elect Biden," Pioneer Natural Resources chief executive Scott Sheffield says. "And there will be some significant changes."

Oil and gas companies do not appear to be taking their chances. They had pledged three-and-a-half times more cash to the Trump campaign than to Biden by 21 July, with $936,155 donated, according to data from non-profit research group the Center for Responsive Politics. For the 2016 election cycle, Trump raised just 20pc more than his Democratic opponent from oil and gas donors.

US upstream independents' results
2Q202Q19±% 1Q20
Profit $mn
Diamondback-2,393349na-272
ConocoPhillips-994486na-1,143
Marathon Oil-750161na-46
Pioneer-439-169na289
Concho-435-97na-9,277
Parsley-356116na-3,366
Continental-239237na-186
Production '000 boe/d
Diamondback2942805321
ConocoPhillips*9811,290-241,278
Marathon Oil390435-10422
Pioneer37533412375
Concho319329-3326
Parsley18314031197
Continental203331-39361
*excluding Libya

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03/07/24

India’s Gail seeks swap for August-loading LNG

India’s Gail seeks swap for August-loading LNG

Singapore, 3 July (Argus) — Indian state-controlled gas distributor Gail is offering a LNG cargo loading in the US in August, in exchange for a cargo for delivery to India in the same month. Gail is offering a cargo loading on 9 August from the US' 33mn t/yr Sabine Pass terminal in exchange for a 15-18 August delivery to the 5mn t/yr Dhamra terminal, through a tender that will close on 4 July. The firm was last in the market to seek a swap just last month, for the exact same delivery windows. Gail already issued this tender twice in June, but may have been unsuccessful in awarding the tender both times. Gail remains focused on issuing destination swap tenders to optimise its contracted US volumes. But falling spot prices may compel the firm to emerge for outright spot purchases in time to come. Indian state-controlled firm Gujarat State Petroleum (GSPC) likely purchased a 20-31 August delivery to the 5mn t/yr Mundra terminal at around $11.60-11.70/mn Btu, through a tender that closed on 2 July, traders said. The requirement was likely to fulfil captive demand from its subsidiary city gas supplier Gujarat Gas, they added. This transaction level is markedly lower than the previous spot transaction to India just last week. Indian state-controlled refiner BPCL purchased a delivery either on 30 July or 7, 8, 9, 11 August at around low-$12s/mn Btu, through a tender that closed on 26 June. Spot demand from India will likely fall in the weeks and months to come as the monsoon season has began in the country. More rains will increase hydropower generation, weigh on the need for additional gas-fired power generation as well as lower temperatures and reduce cooling demand, traders said. The Argus -assessed price for deliveries to India and the Middle East was last at $11.89/mn Btu for the second half of August on 2 July, about 3¢/mn Btu higher than a week earlier, but 20¢/mn Btu lower than a recent peak on 27 June. By Rou Urn Lee Send comments and request more information at feedback@argusmedia.com Copyright © 2024. Argus Media group . All rights reserved.

Venezuela's Maduro open to talks with the US


02/07/24
02/07/24

Venezuela's Maduro open to talks with the US

Caracas, 2 July (Argus) — Venezuelan leader Nicolas Maduro plans to talk with US envoys on Wednesday to discuss allowing the South American country to increase oil exports in exchange for free and fair elections, he said late on Monday. But Maduro's call for dialogue comes less than a month before the 28 July election in which polls show him up to 40 percentage points behind his main challenger. It is also after the US rescinded a six-month reprieve on sanctions in April, accusing Venezuela of violating a commitment to hold a fair vote. Maduro said that the US had sought dialogue with him "for two months in a row", and, "after thinking about it, I have accepted". The head of the pro-Maduro assembly elected in 2020, Jorge Rodriguez, will represent him in the talks, Maduro said. The US State Department declined to directly confirm Maduro's statement but said that the US welcomed "dialogue in good faith, and we support the Venezuelan people's desire for competitive and inclusive elections on July 28." The US ties sanctions relief to Maduro's observing the 2023 Barbados agreement with the Venezuelan opposition, which promised to hold a competitive presidential election. The US in April reimposed sanctions against Venezuela because the Maduro government did not allow the main opposition contender, Maria Corina Machado, to run for president. Former Venezuelan diplomat Edmundo Gonzalez is the sole presidential candidate representing the opposition Unitary Platform. "We are clear-eyed that democratic change will not be easy, and certainly requires a serious commitment," the US State Department said. "This is something that we will continue to focus on when we will engage in dialogue with with a broad range of Venezuelan actors." Venezuela in recent weeks has barred an additional 10 city mayors from running for office for 15 years after they expressed support for Gonzalez, according to the CNE electoral authority and the comptroller general's office. During the first six months of 2024 Maduro has arrested 39 people connected to Gonzalez's campaign, the last one as recently as 30 June, a campaign source told Argus, using figures from Venezuelan non-governmental organizations. Police over the weekend also detained Machado for several hours while leaving a rally for Gonzalez. Venezuela's oil output increased by around 4pc in May to 911,700 b/d from 878,000 b/d in April as drilling campaigns showed results after three months of flat production, according to the oil ministry. But US sanctions are expected to keep a cap on much additional growth. By Carlos Camacho Send comments and request more information at feedback@argusmedia.com Copyright © 2024. Argus Media group . All rights reserved.

US judge halts 'pause' on LNG export licenses


01/07/24
01/07/24

US judge halts 'pause' on LNG export licenses

Washington, 1 July (Argus) — A federal judge in Louisiana has ordered President Joe Biden's administration to end its five-month-old "pause" on the approval process for new LNG export licenses until the resolution of a lawsuit by states that said the policy is unlawful. The US Department of Energy (DOE) and other administration officials are immediately "enjoined and restrained" from "halting and/or pausing the approval process" for LNG export applications requesting licenses to export to countries without a free trade agreement with the US, federal district court judge James Cain wrote today. DOE did not immediately respond to a request for comment. The court's ruling is a potential blow for the Biden administration, which had said it would need until the first quarter of 2025 — after the November elections — to finish a more thorough review of the economic and climate-related effects of fully licensing LNG terminals, beyond the 48 Bcf/d of US liquefaction capacity that is fully permitted today. DOE officials have cited concerns that licensing more LNG projects could end up increasing natural gas prices for consumers. "So much has changed, including the volumes of what we're exporting," US deputy energy secretary David Turk said last week at a congressional hearing. "So we said, 'Let's take a step back, let's update our economic analysis." Biden announced the LNG licensing pause in January, delighting climate groups that have argued that approving additional projects would amount to a "climate bomb." But the pause enraged gas industry officials that worried the pause could threaten investments in a set of projects that were nearing a final investment decision. The pause raised uncertainty on the status of LNG export projects that have yet to obtain licenses, including Venture Global's proposed 28mn t/yr CP2 project in Louisiana that last week cleared a key part of the federal permitting process. The court's ruling does not explicitly require DOE to issue new LNG export licenses, or set an explicit deadline for the agency to take final action on pending applications. But the judge said that under the Natural Gas Act, DOE is required to act "expeditiously" once it receives an export application. Before Biden formally announced the pause, some LNG export applications were already subject to reviews that industry officials said amounted to a de facto freeze. In the ruling, Cain said that Louisiana and other states that challenged the LNG licensing pause were likely to succeed on the merits in showing Biden's policy was arbitrary and capricious, in part because DOE failed to provide a "detailed explanation" for its halt of the approval process. Cain said that DOE had made a "complete reversal" from its position in July 2023, when it defended its licensing process in its rejection of a complaint from environmentalists. By Chris Knight Send comments and request more information at feedback@argusmedia.com Copyright © 2024. Argus Media group . All rights reserved.

Petroecuador expects more crude with fewer wells


01/07/24
01/07/24

Petroecuador expects more crude with fewer wells

Quito, 1 July (Argus) — State-owned oil company Petroecuador will drill fewer wells this year than first planned but still expects to produce 5,000 b/d more crude than initially forecast for 2024, according to the work plan of interim chief executive Diego Guerrero. Petroecuador plans to drill 90 wells this year, including 27 drilled through May and 63 planned for the rest of the year — well below the 156 wells initially forecast under former chief executive Marcela Reinoso , who resigned in May. But the company expects crude output to average 390,000 b/d by December, according to Guerrero's plans, higher than the 370,000 b/d estimate made before he took office, and up from 369,000 b/d reported for June. Ecuador is expected to lose about 50,000 b/d come 1 September when it shuts down the Ishpingo, Tambococha and Tiputini (ITT) fields in block 43 after Ecuadorians voted to end oil activities in the environmentally sensitive region. Guerrero's plan did not break out how much output it expects from ITT this year. Petroecuador did not respond to a request for comment. Reinoso told the national assembly in February that without ITT, Petroecuador's production would fall to 358,500 b/d in September before rising again to 373,300 b/d in December, leading to a 2024 average of about 385,000 b/d. But petroleum engineers' association vice-president Fernando Reyes said that both the new and old goals for December production are too optimistic without ITT. After a 50,000 b/d drop with the end of ITT production, Reyes believes under a best-case scenario new drilling could add 20,000–30,000 b/d of production, bringing December output to 360,000-370,000 b/d. But Guerrero's higher projections are feasible if Petroecuador keeps pumping crude from ITT, Reyes said. Ecuadorian president Daniel Noboa in January proposed a one-year delay on plans to end drilling in the ITT, but the plan has not advanced. Guerrero's work plan also includes new projects to recover associated gas from the Sacha Norte 2, Sacha Central, Drago and Shushufindi fields, and also workovers in four wells in the offshore Amistad natural gas field. Petroecuador produced 81pc of Ecuador's crude output of 484,499 b/d in May. By Alberto Araujo Send comments and request more information at feedback@argusmedia.com Copyright © 2024. Argus Media group . All rights reserved.

Shale to emerge leaner from M&A boom


01/07/24
01/07/24

Shale to emerge leaner from M&A boom

New York, 1 July (Argus) — The recent flurry of deals in the US shale patch is poised to deliver significant productivity gains, potentially offsetting a drilling slowdown and suggesting that it might well be a mistake to bet against the sector any time soon. Ownership of top shale basins, such as the Permian in west Texas and New Mexico, is increasingly falling into the hands of fewer but larger operators, with the necessary resources to chase technology breakthroughs and drive economies of scale that could support further output growth. The flood of deal-making comes as shale growth is likely to slow after defying all expectations last year. Even as acquirers look to fine-tune their combined portfolios and slow activity in favour of shareholder returns, they will still be targeting ever longer lateral wells that reduce the need for more rigs and hydraulic fracturing (fracking) crews. Fracking multiple wells at the same time and shifting to electric fleets will also help them become more efficient. All in all, shale could continue to be a thorn in Opec's side for years to come. Underestimate US shale at your peril was the title of a recent report from analysts at bank HSBC. "We expect the mergers and acquisitions to result in substantial capital efficiencies," they wrote. Concentrated operations have reduced inefficiencies in the supply chain, and the elimination of downtime has also helped producers become leaner, according to consultancy Wood Mackenzie. But costs remain 15-30pc higher than 2020-21 levels, suggesting scope for further improvements. And while efficiency gains will inevitably become exhausted at some point, opportunities to tackle unproductive processes might still crop up. "The will and the technology are there for some operators, who should be able to keep cutting capex while modestly growing and maintaining shareholder distributions for a while to come," Wood Mackenzie research director for the Lower 48 Maria Peacock says. ExxonMobil flagged $2bn in annual savings from its $64.5bn takeover of shale giant Pioneer, with two-thirds to come from improved resource recovery and the rest from efficiencies. Leading US independent ConocoPhillips says improved technology will help it extend its inventory of top-quality drilling locations in both the Eagle Ford and Bakken basins after its $22.5bn tie-up with Marathon Oil. Return to spender Productivity gains are hardly the preserve of firms that have been active participants in the $200bn of shale deals seen over the past year. For example, US independent EOG, which has sat out the mergers and acquisitions (M&A) boom so far, plans to deliver the same level of growth for this year as seen in 2023 with four fewer rigs and two fewer fracking fleets. "Technology has evolved so much that you can go and drill horizontal wells in these and exploit that technology and you can get just absolutely outstanding returns," chief operating officer Jeff Leitzell says. Still, almost half of oil and gas executives recently polled by the Dallas Federal Reserve think that US oil output will be "slightly lower" if consolidation continues over the next five years. But the answer differed by company size. All executives from E&P firms that produce 100,000 b/d or more envisaged "no impact". Service company executives are more concerned: "Consolidation by E&P firms has curtailed investment in exploration," one said. "Our hope is that it's a temporary situation that will work itself out as the integration is completed." And even though the prolific Permian basin is due to peak before the end of the decade, analysts forecast robust growth in the intervening years. Relatively high oil prices that remain above breakeven costs and efficiency gains — which will shift the mix of wells to newer and more productive ones — will be the main drivers, according to bank Goldman Sachs. By Stephen Cunningham US tight oil production Send comments and request more information at feedback@argusmedia.com Copyright © 2024. Argus Media group . All rights reserved.

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