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Energy spend set to surpass $3 trillion in 2024: IEA

  • : Coal, Crude oil, Electricity, Natural gas
  • 24/06/06

Global energy investment this year is on track to exceed $3 trillion, around $2 trillion of which will be "clean energy" financing, twice the amount being spent on fossil fuels, energy watchdog the IEA said today.

The IEA defines clean energy as renewables, electric vehicles, nuclear power, electricity grids, storage, heat pumps and "efficiency improvements". It also includes "low-emissions fuels", which it names as bioenergy, low-emissions hydrogen and carbon capture, use and storage (CCUS) associated with fossil fuels.

The remainder of energy investment, at just over $1 trillion, is set to go to coal, gas and oil, the IEA said. Investment in renewable power and grids overtook spending on fossil fuels in 2023, for the first time. The ratio of clean power to unabated fossil fuel power investments is set to reach 10:1 this year — in comparison to a ratio of 2:1 in 2015, the IEA said.

"Clean energy investment is setting new records even in challenging economic conditions, highlighting the momentum behind the new global energy economy," IEA executive director Fatih Birol said.

"The rise in clean energy spending is underpinned by strong economics, by continued cost reductions and by considerations of energy security. But there is a strong element of industrial policy, too, as major economies compete for advantage in new clean energy supply chains," he said.

Investment in solar photovoltaic (PV) power "now surpasses all other [electricity] generation technologies combined", the IEA found. It forecasts spending on solar PV will hit $500bn this year, "as falling module prices spur new investments".

Power sector investment rose by 15pc in the year to $1.3 trillion in 2023, but the IEA expects the growth rate to slow in 2024 owing to cost reductions for renewables. The watchdog noted that in 2023 "each dollar invested in wind and solar PV yielded 2.5 times more energy output than a dollar spent on the same technologies a decade prior".

Oil, gas investment matches demand

The IEA expects global upstream oil and gas investment to increase by 7pc to $570bn this year — following a similar year-on-year rise in 2023 of 9pc. The increase is driven mostly by Middle East and Asian national oil companies, it said.

Oil and gas investment this year "is broadly aligned with the demand levels implied in 2030 by today's policy settings, but far higher than projected in scenarios that hit national or global climate goals", the report found.

Reaching net zero emissions by 2050 would mean that annual investment in fossil fuels drops by more than half, from just over $1 trillion in 2024 to under $450bn in 2030, the IEA said. It would also mean spending on low-emissions fuels would increase tenfold, to around $200bn in 2030, it added.

"Clean energy investment" by oil and gas companies stood at $28bn in 2023, "less than 4pc of overall capital spending", the report noted.

More than 120 countries pledged at the UN Cop 28 climate summit to treble renewable energy capacity and double energy efficiency by 2030. In order to hit these goals, clean energy investment should double by 2030 globally — and quadruple in emerging and developing economies outside China over the same timescale, the IEA said.

It noted that China, the EU and the US account for nearly 60pc of current global spending on clean energy. Europe and the US will account for clean energy spending of $370bn and $315bn this year, respectively, while "clean energy powerhouse" China is projected to spend $675bn on clean energy in 2024, the IEA said. But of the more than 50GW of unabated coal-fired power generation approved last year, almost all was in China, reflecting the country's security priorities, especially in the face of underperforming hydropower capacity.


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24/10/17

Jury rules against P66 in trade secret case

Jury rules against P66 in trade secret case

Calgary, 17 October (Argus) — A California jury says US independent refiner Phillips 66 must pay $604.9mn in damages for allegedly stealing trade secrets related to the state's biofuels market. The jury issued its verdict on 16 October, siding with west coast fuel retailer Propel Fuels more than two years after it filed suit in the Superior Court of California. Propel sought $1bn in damages , alleging that Phillips 66's renewables business in California was developed from trade secrets the refiner gained while conducting due diligence on for a possible acquisition of the fuel retailer in 2017 and 2018. Propel said it was "... actively building a new integrated renewable fuels business for Phillips 66 when Phillips 66 abruptly and without explanation terminated the deal on August 24, 2018." Shortly after terminating the deal, the refiner told California regulators it would begin selling E85 fuel in the state and launched retail sales of renewable diesel (RD) weeks later, Propel says. "Phillips 66 rapidly expanded its California renewables business using Propel's data and market insights," according to Propel. Phillips 66 denied any wrongdoing and said it is evaluating its legal options following the verdict. A final judgment in the case has not been entered and post-trial motions are pending before the court, Phillips 66 said. By Brett Holmes Send comments and request more information at feedback@argusmedia.com Copyright © 2024. Argus Media group . All rights reserved.

Few 2024-25 LNG cargoes scheduled at Alexandroupolis


24/10/17
24/10/17

Few 2024-25 LNG cargoes scheduled at Alexandroupolis

London, 17 October (Argus) — Users of Greece's new Alexandroupolis LNG terminal have so far only scheduled seven LNG deliveries for the 2024-25 gas year, according to a schedule sent to Argus by terminal operator Gastrade. TotalEnergies delivered the year's first 1TWh cargo to Bulgargaz on 3 October and the French company is scheduled to bring further 1TWh shipments to Bulgargaz on 25 November and 27 December. And next year, only one cargo is scheduled to arrive each month in January-March — the March shipment being only 509GWh — before a four-month gap until a final scheduled delivery of 509GWh on 27 July ( see data and download ). Although still subject to change if spot slots are purchased or swapped in the future, those 6TWh of scheduled deliveries would utilise only a fraction of the terminal's full 66.3 TWh/yr capacity. Such low utilisation is despite the fact that 69pc of the terminal's capacity is booked for the current gas year, according to the operator. With prices on Bulgaria's Balkan Gas Hub frequently at least €5/MWh ($5.4/MWh) below the TTF, firms have little incentive to bring LNG to Greece. Imports to Greece's Revithoussa terminal have more than halved so far this year, despite much higher Greek consumption . And the full 90pc of Alexandroupolis' capacity is booked for the 2025-26 and 2026-27 gas years, with just the EU-mandated 10pc held back for offer as prompt products. Bookings drop slightly in the following three years before falling more significantly from 2030 onwards ( see bookings table ). The Alexandroupolis terminal is currently undergoing scheduled maintenance on the 15-18 October gas days, halting sendout. Works are also scheduled to freeze sendout on 7-14 June 2025. There are currently 14 registered users at Alexandroupolis. As well as some of the main regional players such as Bulgargaz, OMV Petrom, Edison, and Depa, there are also some smaller companies such as Attiki Gas Supply, Tibiel EOOD, and Sustainable Energy Supply ( see supplier table ). By Brendan A'Hearn Alexandroupolis registered users ATTIKI GAS SUPPLY COMPANY S.A. BULGARGAZ EAD DEPA COMMERCIAL S.A. EDISON SpA HERON ENERGY S.A. OMV PETROM S.A. PUBLIC POWER CORPORATION OF GREECE S.A. PREMIER ENERGY SRL SK GAS MED PUBLIC COMPANY SRBIJAGAS NOVI SAD JSC Power Plants of North Macedonia - AD Elektrani na Severna Makedonija (AD ESM - Skopje) TIBIEL EOOD SUSTAINABLE ENERGY SUPPLY LTD VENTURE GLOBAL LNG ― Gastrade Alexandroupolis capacity bookings GWh/d Gas year Technical cap Reserved cap Available cap Available short-term cap 2025-2026 181.6 163.4 0.0 18.2 2026-2027 181.6 163.4 0.0 18.2 2027-2028 181.6 158.4 5.0 18.2 2028-2029 181.6 158.4 5.0 18.2 2029-2030 181.6 138.6 24.8 18.2 2030-2031 181.6 99.3 64.2 18.2 2031-2032 181.6 94.3 69.2 18.2 2032-2033 181.6 94.3 69.2 18.2 2033-2034 181.6 94.3 69.2 18.2 2034-2035 181.6 31.4 132.1 18.2 2035-2036 181.6 31.4 132.1 18.2 2036-2037 181.6 31.4 132.1 18.2 2037-2038 181.6 31.4 132.1 18.2 2038-2039 181.6 31.4 132.1 18.2 ― Gastrade Send comments and request more information at feedback@argusmedia.com Copyright © 2024. Argus Media group . All rights reserved.

Pemex to cut 20pc of upstream budget in 4Q


24/10/17
24/10/17

Pemex to cut 20pc of upstream budget in 4Q

Mexico City, 17 October (Argus) — Mexico's state-owned Pemex plans to reduce its upstream budget by 20pc in the fourth quarter, impacting short-term crude production, according to industry sources and internal documents. Pemex's new upstream head, Nestor Martinez, has instructed the company's units to implement budget cuts in activities such as major well repairs and seismic data contracts, according to documents seen by Argus . The company aims to save Ps26.78bn ($1.38bn) in 2024, according to an internal presentation of Pemex's upstream arm (PEP) dated 9 October. Pemex typically spends around Ps130bn quarterly, so the cut represents about 20pc of that, said an industry source. Pemex did not respond a request for comment. The reduction could lower Pemex's crude production by 5,804 b/d, according to the document. But the actual impact may be greater if wells go without essential repairs and stop production, sources added. Pemex produced 1.73mn b/d of crude and condensates in August, according to hydrocarbon regulator CNH data. This budget cut signals ongoing issues with delayed payments to Pemex vendors, which has worsened over the past six years, according to market sources. The cuts also suggest that President Claudia Sheinbaum's target of maintaining oil output below 1.8mn b/d could lead to further reductions in exploration and production spending. As of 2 October, PEP owed around Ps99bn to suppliers, with Ps81bn for 2024 work, Ps10.5bn from 2023, and Ps1.9bn from 2022, according to an internal document sent by PEP to its units on 11 October. In July, Pemex reported Ps126.4bn in overdue payments across all units. Oil services companies GMS Bronco, Typhoon Offshore, Cotemar, Perforadora Integral de Orienta and Baker Hughes had the five highest outstanding balances as of 2 October, according to the internal document. Dowell Schlumberger and Halliburton de Mexico, subsidiaries of SLB and Halliburton, were among the10 companies owed the most by Pemex. By Édgar Sígler Send comments and request more information at feedback@argusmedia.com Copyright © 2024. Argus Media group . All rights reserved.

Fire at Germany's Bayernoil refinery


24/10/17
24/10/17

Fire at Germany's Bayernoil refinery

Hamburg, 17 October (Argus) — A fire broke out in a crude distillation unit at Germany's 215,000 b/d Vohburg-Neustadt refinery complex on 16 October, operator Bayernoil said. The fire occurred in the sole CDU in the Neustadt section, the smaller of the two sites, and was put out within a few minutes, Bayernoil said. The cause and the extent of the damage are not yet known. Traders in the region have not reported any impact on supply so far. Bayernoil is a joint venture comprising Varo Energy, Italy's Eni and Rosneft Deutschland. Rosneft Deutschland is one of Russian state-controlled Rosneft's two German subsidiaries, both of which have been under the trusteeship of Germany's Federal Network Agency since 2022. Rosneft has said it intends to sell its German assets. The company is actively pursuing the sale by the end of this year, according to the German government. By Natalie Müller Send comments and request more information at feedback@argusmedia.com Copyright © 2024. Argus Media group . All rights reserved.

Australia’s Santos commissions Moomba CCS facility


24/10/17
24/10/17

Australia’s Santos commissions Moomba CCS facility

Adelaide, 17 October (Argus) — Australian independent Santos has commissioned its 1.7mn t/yr Moomba carbon capture and storage (CCS) project in the onshore Cooper basin of South Australia state, the firm said in its July-September results. The Australian carbon credit unit (ACCU)-generating project is running at full injection rates of up to 84mn ft³/d (2.38mn m³/d) of CO2 with all five wells on line, Santos said, adding that the full 1.7mn t/yr capacity would depend on Cooper basin gas production. The CCS will be Australia's second largest by nameplate capacity after Chevron's controversial 4mn t/yr Gorgon CCS on Barrow Island, which has been criticised for failing to reach its sequestration goals because of issues with the pressure management system. Santos reported July-September output 3pc down from 22.2mn bl of oil equivalent (boe) in the previous quarter to 21.6mn boe. This was primarily because of planned maintenance at amine trains at its Varanus Island plant and natural field decline in Western Australia state. Condensate production fell by 97pc from 329,100 bl to 9,000 bl for the quarter because of field decline and shutdown at the Ningaloo Vision floating production, storage and offloading vessel (FPSO) because of a subsea communications fault, expected to return to service in early to mid October-December quarter. Santos completed decommissioning of 13 wells within the Harriet joint venture and three of 11 wells in the Mutineer, Exeter, Fletcher and Finucane fields. The 7.8mn t/yr Gladstone LNG shipped 21 cargoes for the quarter, one less than a year and quarter earlier. LNG production was similar to the previous quarter because of seasonal shaping to meet domestic winter gas requirements. Growth is expected in October-December owing to new wells from Arcadia and Roma fields. Angore field in Papua New Guinea is being commissioned and will start production of about 350mn ft³/d in October-December, Santos said, in line with previous guidance. The Barossa backfill project offshore northern Australia is 82pc complete with FPSO integration continuing in Singapore and three of six wells completed. Santos' Pikka phase one project is 67pc complete, with Alaskan authorities approving a 25pc increase in the acreage in September. But the project's costs would increase by about 20pc, or around $520mn from the original $2.6bn estimate, because of inflation and accelerated pipelay activity costs, Santos said. This would take the cost of Pikka, which was sanctioned in mid-2022 to $3.12bn. Santos controls 51pc and Spanish energy firm Repsol owns 49pc of the asset. Santos expects its 2024 production to be at the upper end of its guidance of 84mn-90mn boe. By Tom Major Santos results Jul-Sep '24 Apr-Jun '24 Jul-Sep '23 y-o-y % ± q-o-q % ± Volumes ('000 t) GLNG (100pc) 1,300 1,338 1,370 -5 -3 Darwin LNG (100pc) 0 0 42 -100 -100 PNG LNG (100pc) 1,938 2,001 2,111 -8 -3 Santos' equity share of LNG sales 1,148 1,264 1,300 -12 -9 Financial LNG sales revenue ($mn) 766 762 821 -7 1 Total sales revenue ($mn) 1,269 1,313 1,436 -12 -3 LNG average realised price ($/mn Btu) 12.69 11.47 12.02 6 11 Oil price ($/bl) 83.24 89.48 89.97 -7 -7 Source: Santos Send comments and request more information at feedback@argusmedia.com Copyright © 2024. Argus Media group . All rights reserved.

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