US seeks to speed permits by limiting reviews

  • Spanish Market: Coal, Crude oil, Emissions, Natural gas
  • 15/07/20

President Donald Trump's administration today finalized a rule that attempts to expedite approval of federal oil and gas leases, pipelines, highways and other infrastructure by curtailing environmental reviews.

The overhaul aims to simplify reviews under the National Environmental Policy Act (NEPA) so that federal permitting of pipelines and other projects could be done within two years. Critics say the administration is trying to gut a law meant to require regulators to take a "hard look" at how approving a project would affect communities and the environment.

NEPA has become a growing vulnerability for the oil sector. A judge last week ordered the 530,000 b/d Dakota Access crude pipeline to close due to flaws with its environmental review. The 830,000 b/d Keystone XL crude pipeline was unable to start construction in 2018 for similar reasons. A judge last year blocked hundreds of drilling leases in Wyoming for incomplete climate change studies.

Trump today said the "top-to-bottom overhaul" of environmental reviews would remove roadblocks to building infrastructure and provide billions of dollars in cost savings. Trump has regularly criticized environmental reviews as unnecessary and too costly, drawing on his previous career as a real estate developer where his projects were subject to complex permitting requirements.

"I have been wanting to do this since day one," Trump said.

The US enacted the statute in 1970 with a broad mandate for the government to study how its actions could affect the environment before making a decision. White House regulations and decades of court rulings have fleshed out what the law requires, resulting in reviews that can be hundreds of pages long and take years to complete.

The White House Council on Environmental Quality, in the changes today, is seeking to reset some of that process by issuing a rule curtailing what types of reviews are required. The changes would allow reviews to focus narrowly on near-term environmental effects, such as soil erosion from constructing a pipeline, while avoiding the study of long-term effects such as how burning fossil fuels transported by a pipeline could affect climate change.

Oil groups cheered the overhaul. The changes are "desperately needed," American Petroleum Institute president Mike Sommers said, and would "make sure that job-creating infrastructure projects get off the drawing board and into development." Independent Petroleum Association of American president Barry Russell said the revisions would provide "needed certainty" to businesses.

The NEPA changes are coming too late to have an effect on the Trump administration's approval of projects such as the Dakota Access pipeline or its decision to allow oil and gas development within the Arctic National Wildlife Refuge in Alaska. And the changes are likely to increase uncertainty in the near-term, as agencies figure out how to conduct reviews under the new rules. US courts might decide if the changes are lawful on a project-by-project basis.

Environmentalists are planning a major fight against the changes, which they say will be most harmful to low-income and minority communities that have used NEPA to oppose projects that would boost emissions near their neighborhoods. Critics say the government should undertake more robust reviews of whether projects would exacerbate climate change, rather than ignoring most of those effects.

"We will not allow this blatant polluter power-grab to stand," Earthjustice attorney Jan Hasselman said. "We will see them in court."

Presumed Democratic presidential nominee Joe Biden, if elected, would have a pathway to blocking the changes by undertaking a new review. If Democrats win control of the US Senate and retain control of the US House of Representatives, they could also vote to disapprove the change and quickly revert back to the earlier rules.


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29/04/24

Australia’s QPM hikes gas reserves estimate

Australia’s QPM hikes gas reserves estimate

Sydney, 29 April (Argus) — The energy arm of Australian battery metals firm Queensland Pacific Metals (QPM) has announced its certified reserves have increased more than a third on previous estimates at its Moranbah gas project (MGP) in Queensland state. QPM Energy (QPME) reported a 38pc increase in its total proven and probable (2P) gas reserves to 331PJ (8.8bn m³) on 29 April compared with a March 2022 estimate of 240PJ, as it pivots towards its energy business and pauses spending on its proposed Townsville Energy Chemicals Hub (TECH) project . QPME's waste coal mine gas reserves will be developed along with 300MW of new gas-fired power generation at the firm's Moranbah facilities located in the Bowen basin, a metallurgical and thermal coal producing region. The company is also planning to build compressed natural gas and micro-LNG facilities to distribute gas to northern Queensland customers. The company will seek to increase its output by 25pc to 35 TJ/d (935,000 m³/d) by late 2024, up from October-December 2023's average of 28 TJ/d by drilling a further seven wells by the year's end. A rig has arrived on site for drilling the first well of its Teviot Brook South Well programme, QPM said on 24 April. Australian independent Blue Energy, which is developing the Sapphire pilot project with 59PJ of 2P reserves near MGP, said QPM has confirmed it intends on taking gas Blue makes available to the MGP, in line with an existing non-binding agreement signed in June last year. Blue and QPME's parent company QPM also have a separate non-binding deal for supply of 7 PJ/yr of gas over 15 years to the TECH project. By Tom Major Send comments and request more information at feedback@argusmedia.com Copyright © 2024. Argus Media group . All rights reserved.

Lyondell Houston refinery to run at 95pc in 2Q


26/04/24
26/04/24

Lyondell Houston refinery to run at 95pc in 2Q

Houston, 26 April (Argus) — LyondellBasell plans to run its 264,000 b/d Houston, Texas, refinery at average utilization rates of 95pc in the second quarter and may convert its hydrotreaters to petrochemical production when the plant shuts down in early 2025. The company's sole crude refinery ran at an average 79pc utilization rate in the first quarter due to planned maintenance on a coking unit , the company said in earnings released today . "We are evaluating options for the potential reuse of the hydrotreaters at our Houston refinery to purify recycled and renewable cracker feedstocks," chief executive Peter Vanacker said on a conference call today discussing earnings. Lyondell said last year a conversion would feed the company's two 930,000 metric tonnes (t)/yr steam crackers at its Channelview petrochemicals complex. The company today said it plans to make a final investment decision on the conversion in 2025. Hydrotreater conversions — such as one Chevron completed last year at its 269,000 b/d El Segundo, California, refinery — allow the unit to produce renewable diesel, which creates renewable naphtha as a byproduct. Renewable naphtha can be used as a gasoline blending component, steam cracker feed or feed for hydrogen producing units, according to engineering firm Topsoe. Lyondell last year said the Houston refinery will continue to run until early 2025, delaying a previously announced plan to stop crude processing by the end of 2023. By Nathan Risser Send comments and request more information at feedback@argusmedia.com Copyright © 2024. Argus Media group . All rights reserved.

Azerbaijan wants certainty from EU on gas needs


26/04/24
26/04/24

Azerbaijan wants certainty from EU on gas needs

London, 26 April (Argus) — Azerbaijan needs long-term guarantees and available financial instruments to invest in gas production growth, its president Ilham Aliyev said earlier this week. Azerbaijan and the EU signed a strategic partnership agreement in 2022, in which Azerbaijan committed to increasing its supply to the EU to 20bn m³/yr by 2027 from 8bn m³ in 2021. This is a "target that we are moving towards" and exports to Europe will be around 12bn m³ this year, Aliyev said on 23 April at the Cop 29 and Green Vision for Azerbaijan forum ( see Azeri gas production graph ). But Azerbaijan needs investments to reach this export target, and restrictions from financing institutions on fossil fuel projects make them harder to realise, Alyiev said. The European Investment Bank has removed fossil fuel projects from its portfolio and the European Bank for Reconstruction and Development has only a small share of such projects, Aliyev said. Corporations tend to finance 30pc of gas production or infrastructure projects on their own and the remainder through loans, he said. The other issue is a need to receive long-term guarantees for Azeri gas supply, as "Azerbaijan cannot invest billions only for 5-10 years and not be able to recover the costs", Aliyev said. Azerbaijan is still paying back loans for the Southern Gas Corridor and Shah Deniz Stage 2 projects, he said. A long-proposed Ionian-Adriatic pipeline that could provide the Balkan region with Azeri gas is yet to materialise because it lacks EU funding support and gas consumption in the countries involved is low, particularly considering the challenges involved with building a pipeline in a mountainous region, Aliyev said. But Azeri gas can already reach Croatia, Bosnia Herzegovina and Montenegro through Hungary, while it can flow to Serbia through Bulgaria, he said. Aliyev said he believes that the Croatian and Azeri governments are already in consultation about this. Referring to a long-mooted project to build a pipeline across the Caspian Sea to deliver Turkmen gas to Europe, Aliyev said that Azerbaijan has "received no messages from Turkmenistan". Azerbaijan as a transit country cannot become the initiator or co-ordinator of a trans-Caspian pipeline project, Aliyev said. The Southern Gas Corridor is fully booked, meaning that infrastructure developments are needed to transport more gas to Europe, which is "under discussion", Aliyev said. Azerbaijan plans renewables build-out Azerbaijan is targeting 5GW of additional renewable generation capacity, which it aims to substitute for gas, releasing this supply for export to Europe, Aliyev said. Azerbaijan's first 240MW solar plant was inaugurated in 2023. It plans to add four new 1.3GW solar and wind projects this year and is considering some offshore and onshore wind projects as well as solar and hydropower plants. Azeri gas consumption for power generation and heating needs increased to 6.6bn m³ in 2022 from 6.1bn m³ in 2020, and made up almost half of domestic consumption in 2022 ( see data and download ). Azerbaijan is in the last phase of a feasibility study for a green energy cable from the Caspian Sea to the Black Sea and then further down to Europe. The project aims to initially connect the Georgian Black Sea to the Romanian coast, and plans to expand it further down to the eastern Caspian and Kazakhstan, according to Aliyev. The state plans to keep investing to strengthen the energy grid to allow it to cope with the renewables build-out. Foreign investors are mainly involved with renewables projects. Oil and gas makes up less than half of Azerbaijan's GDP today, but 95pc of its exports, Aliyev said. By Victoria Dovgal Azeri gas production bn m³ Send comments and request more information at feedback@argusmedia.com Copyright © 2024. Argus Media group . All rights reserved.

US M&A deals dip after record 1Q: Enverus


26/04/24
26/04/24

US M&A deals dip after record 1Q: Enverus

New York, 26 April (Argus) — US oil and gas sector mergers and acquisitions (M&A) are likely to slow for the rest of the year following a record $51bn in deals in the first quarter, consultancy Enverus says. Following an unprecedented $192bn of upstream deals last year, the Permian shale basin continued to dominate first-quarter M&A as firms competed for the remaining high-quality inventory on offer. Acquisitions were led by Diamondback Energy's $26bn takeover of Endeavor Energy Resources. Other private operators, such as Mewbourne Oil and Fasken Oil & Ranch, would be highly sought after if they decided to put themselves up for sale, Enverus says. Send comments and request more information at feedback@argusmedia.com Copyright © 2024. Argus Media group . All rights reserved.

Start-ups to help Total keep output stable in 2Q


26/04/24
26/04/24

Start-ups to help Total keep output stable in 2Q

London, 26 April (Argus) — TotalEnergies said it expects its oil and gas production to hold broadly steady in the second quarter as planned maintenance is partially offset by rising output from new projects in Brazil and Denmark. The company expects to average 2.4mn-2.45mn b/d of oil equivalent (boe/d) in April-June, compared with 2.46mn boe/d in the previous three months and 2.47mn boe/d in the second quarter of 2023. Production is being supported by the restart of gas output from the redeveloped Tyra hub in Denmark late last month and the start of the 180,000 b/d second development phase of the Mero oil field on the Libra block in Brazil's Santos Basin at the beginning of the year. TotalEnergies first-quarter output was flat compared with the previous three months but 2pc lower than a year earlier as a result of Canadian oil sands divestments. The company reported a robust set of first-quarter results today, broadly in line with analysts' expectations. Profit for the first three months of 2024 was $5.7bn, compared to $5.6bn in the same period last year. Adjusted profit — which takes into account inventory valuation effects and special items — came in at $5.1bn, down by 22pc on the year but slightly ahead of the consensus of analysts' estimates of $5bn. Adjusted operating profit from the firm's Exploration & Production business was down by 4pc year-on-year at $2.55bn, driven in part by lower natural gas prices. The Canadian oil sands asset sales weighed on the segment's production but this was partly compensated by start-ups. As well as Mero 2, the Akpo West oil project in Nigeria started production during the first quarter. TotalEnergies' Integrated LNG segment saw a 41pc year-on-year decline in its adjusted operating profit to $1.22bn in January-March. The company said this reflects lower LNG prices and sales. But while its LNG sales for the quarter fell by 3pc in year-on-year terms, its LNG production was greater by 6pc. TotalEnergies achieved an average $78.9/bl for its liquids sales in the first quarter, an improvement on $73.4/bl a year earlier. But the average price achieved for its gas sales was 43pc lower on the year at $5.11/mn Btu. In the downstream, the company's Refining & Chemicals segment's first-quarter adjusted operating profit was $962mn in January-March, down by 41pc on the year but 52pc higher than the preceding quarter. TotalEnergies attributes the quarter-on-quarter rise to higher refining margins and a rise in refinery throughput . For the second quarter, it expects refinery utilisation rates to be above 85pc, compared with 79pc in the first quarter, boosted by the restart of 219,000 b/d Donges refinery in France. Total's Integrated Power segment continued to improve, registering a quarter-on-quarter and year-on-year increased of 16pc and 65pc respectively in its adjusted operating profit to €611mn. Net power production increased 14pc year-on-year to 9.6 TWh, while the company's portfolio of installed power generation capacity grew 54pc to 19.5GW. Total's cash flow from operations, excluding working capital, was down by 15pc on a year earlier at $8.2bn in the first quarter. The company has decided to raise its dividend for 2024 by 7pc to €0.79/share and plans a $2bn programme of share buybacks for the second quarter. By Jon Mainwaring Send comments and request more information at feedback@argusmedia.com Copyright © 2024. Argus Media group . All rights reserved.

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