Singapore's MPA, IEA unite on maritime decarbonisation

  • : Biofuels, Fertilizers, Oil products, Petrochemicals
  • 24/04/17

The Maritime and Port Authority of Singapore (MPA) and the IEA have signed an initial deal to push the transition to zero and near zero emission fuels, while working on technology as well as digitalisation to meet the maritime decarbonisation agenda.

The agreement, signed by MPA chief executive Teo Eng Dih and IEA executive director Faith Birol, was announced at the Singapore Maritime Week 2024 (SMW) this week.

"Greater international collaboration in maritime and energy industries is critical for international shipping to meet international decarbonisation goals," Teo said.

"Shipping is one of the hardest sectors to decarbonise and we need to spur development and deployment of new technologies to slow and then reverse the rise in its emissions," said IEA chief economist Tim Gould. "This will require strong collaboration at a national and international level."

Training programmes will be built to support the adoption of new fuels. There will also be partnerships made towards fuel-related projects and initiatives such as the International Maritime Organisation-Singapore NextGen project.

The IEA plans to open its first regional co-operation centre in Singapore, which will be its first regional office outside of its headquarters in Paris, France.


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24/05/24

Dangote refinery to export 10ppm diesel in June

Dangote refinery to export 10ppm diesel in June

London, 24 May (Argus) — Nigeria's 650,000 b/d Dangote refinery will start exporting diesel conforming to European specifications along with gasoline sales in June, its vice president for oil and gas Devakumar Edwin has said. "We expect before the end of next month we'll also have gasoline in the market, and we'll also have Euro V diesel for export, that is below 10ppm", Edwin said this week at a Society of Petroleum Engineers event in Lagos. Dangote chief executive Aliko Dangote reiterated the planned June start for gasoline on 17 May. Dangote started its crude distillation unit in January, and received approval to start up a mild hydrocracker with its desulphurisation units in March. A source at Nigeria's downstream regulator NMDPRA said the refinery has now received approval to start its residual fluid catalytic cracker. Dangote started naphtha exports in March, low-sulphur straight run fuel oil (LSSR) exports in May and began selling diesel and jet fuel domestically in April. It has a waiver from NMDPRA to sell diesel with sulphur levels above 600ppm into the local market. At full capacity Dangote will be able to more than meet Nigerian domestic gasoline demand. But a trader in the region said gasoline production is unlikely to start next month, citing the amount of cargoes to be delivered to the country. Exports of naphtha, a key blending component in finished-grade gasoline, are continuing from the refinery, with 80,000t due to load on 31 May according to Kpler. And Edwin hinted at a slowing of spot sales. "We had a meeting to see, probably, how we can slow down our sales because we've already made quite a few forward bookings," he said this week. "Export, for example, aviation/jet, the last vessel went to the Caribbean islands. The next vessel, we are booking for US market." Dangote recently added TotalEnergies as a buyer in a deal that could see the French company take refined products for its African network of 4,800 retail fuel stations, including more than 540 in Nigeria. The deal could also see the oil major supply crude to the refinery. A source told Argus there is a deal for TotalEnergies to supply two crude cargoes each month, or around 2mn bl. Indications based on the refinery's slate to date and TotalEnergies' Nigerian crude equity suggest one cargo of the very light Amenam blend one of Bonny Light. By Adebiyi Olusolape and George Maher-Bonnett Send comments and request more information at feedback@argusmedia.com Copyright © 2024. Argus Media group . All rights reserved.

Richmond City Council proposes Chevron refinery tax


24/05/23
24/05/23

Richmond City Council proposes Chevron refinery tax

Houston, 23 May (Argus) — The Richmond City Council in California's Bay Area has paved the way for a tax on Chevron's 245,000 b/d refinery, voting unanimously at a 21 May meeting for the city's attorney to prepare a ballot initiative. The newly proposed excise tax would be based on the Richmond refinery's feedstock throughputs, according to a presentation given by Communities for a Better Environment (CBE) at the meeting. It is a "…legally defensible strategy to generate new revenue for the city," CBE attorney Kerry Guerin said. The city has previously looked to tax the refinery, with voters passing ‘Measure T' in 2008 before it was struck down in court in 2009. This led to a 15-year settlement agreement freezing any new taxes on Chevron's refinery, but the agreement expires on 30 June 2025. The city is projecting a $34mn budget shortfall for the 2024 to 2025 fiscal year and is seeking to shore up its finances with additional revenue. Ballot initiatives allow Californian citizens to bring laws to a vote without the support of the state's governor or legislature, and the tax proposal could go to voters as early as November this year, according to CBE's Guerin. "Richmond has been the refinery town for more than 100 years, but it won't be 100 years from now," Richmond Mayor Eduardo Martinez said during the meeting. Chevron reiterates risk to renewables A tax on the refinery is the "wrong approach to encourage investment in our facility and in the city that could lead to new energy solutions and reductions in emissions from the refinery," Chevron senior public affairs representative Brian Hubinger said during the meeting's public comments. Hubinger's comment echoes prior warnings from Chevron that a potential cap on California refining profit in the process of being implemented by the California Energy Commission (CEC) would make the company less willing to investment in renewable energy . "An additional punitive tax burden reduces our ability to make investments in our facility to provide the affordable, reliable and ever-cleaner energy our community depends on every day, along with the job opportunities and emission reductions that go with these investments," Chevron said in an emailed statement. The Richmond refinery tax is a "hasty proposal, brought forward by activist interests," the company said. The company last year finished converting a hydrotreating unit at its 269,000 b/d El Segundo, California, refinery to process both renewable and crude feedstocks. The facility was processing 2,000 b/d of bio feedstock to produce renewable diesel (RD) and sustainable aviation fuel (SAF) and said it expected to up production to 10,000 b/d last year. But Chevron has so far lagged its California refining peers in terms of RD volumes with Marathon's Martinez plant running at about 24,000 b/d in the first quarter — half of its nameplate capacity — and Phillips 66's Rodeo refinery producing 30,000 b/d with plans to up runs to over 50,000 b/d by the end of the second quarter . Chevron did not immediately respond to a request for current RD volumes at its California refineries. By Nathan Risser Send comments and request more information at feedback@argusmedia.com Copyright © 2024. Argus Media group . All rights reserved.

US ethane supply gains seen trailing demand growth


24/05/23
24/05/23

US ethane supply gains seen trailing demand growth

Houston, 23 May (Argus) — Export and domestic demand growth for US ethane is expected to outpace US supply growth by as much as 72,000 b/d by 2026, according to a recent forecast from consultancy East Daley Analytics. A surplus of US ethane production, bolstered by gains in natural gas drilling and production to meet growing demand for electricity generation and LNG exports, has led to increasing investments in additional ethane export terminal capacity to provide other outlets for the petrochemical feedstock. The US Energy Information Administration (EIA) showed US ethane production from natural gas processing rose to a record 2.78mn b/d in October of 2023 and fell to 2.69mn b/d in February, the latest data the agency has available. Those volumes don't take into account ethane that is rejected into the gas stream at processing plants during periods of restrained capacity or when natural gas prices spike on weather-related outages, incentivizing lower ethane recovery. Mont Belvieu, Texas, EPC ethane's premium relative to its natural gas fuel value at Waha reached a peak of 50.31¢/USG on 6 May, a 16-month high, and has averaged 26.08¢/USG in May so far, according to Argus data. As ethane margins versus natural gas rise, ethane extraction at natural gas processing plants becomes even more profitable, pushing ethane recovery rates higher. Yet East Daley's forecasts suggest projects to absorb this additional feedstock may quickly outpace production. The consultancy projects US ethane production will rise by 283,000 b/d by 2026, driven mostly by gains in natural gas production in the Permian and Marcellus basins. Increased gas takeaway capacity from the completion of maintenance on Kinder Morgan's Permian Highway pipeline (PHP), the Gulf Coast Express (GCX) pipeline, and the Transwestern pipeline at the end of this month, will allow for higher levels of ethane rejection, according to Rob Wilson, East Daley's vice president of analytics, limiting potential gains in ethane production from the additional gas. Further gas capacity restrictions in the Permian are expected to be mitigated when the 2.5 Bcf/d Matterhorn Express pipeline — which runs from the Waha, Texas, gas hub to Katy, Texas, on the Gulf coast — comes online in the third quarter of this year. Domestic demand for ethane is projected to rise by 129,000 b/d by 2026 with the addition of Chevron Phillips Chemical's joint venture with QatarEnergy to construct a 2mn t/yr ethane cracker on the Texas Gulf coast that is scheduled to come online in 2026. That joint venture will consume 118,000 b/d of ethane when at full capacity, but will operate at 50pc of capacity when first on line in 2026, according to East Daley. Increased US ethane cracking will come on top of a 231,000 b/d increase in ethane exports by 2026, driven by demand from Chinese crackers and burgeoning demand from Indian crackers, according to the consultancy. Ethane export expansions at Energy Transfer's Marcus Hook terminal in Pennsylvania and Enterprise Products Partners' new flexible LPG and ethane terminal at Beaumont, Texas, are expected to be complete by 2025 and 2026, respectively. Combined, these projects add another 360,000 b/d of ethane demand by 2026, outstripping expected supply growth by an estimated 72,000 b/d, according to East Daley's forecast. By Abby Downing-Beaver Send comments and request more information at feedback@argusmedia.com Copyright © 2024. Argus Media group . All rights reserved.

USDA to invest $83mn in fertilizer projects


24/05/23
24/05/23

USDA to invest $83mn in fertilizer projects

Houston, 23 May (Argus) — The US Department of Agriculture (USDA) plans to invest $83mn to build out fertilizer production plants, modernize equipment and adopt new technologies in 12 states. The grants are part of the USDA's Fertilizer Production Expansion Program (FPEP) aimed at boosting domestic fertilizer production, increasing competition and lowering costs for farmers. Around $25mn will be granted to a food waste upcycling facility in Jurupa Valley, California, to produce organic fertilizer. Nearly 90 market participants in the area will be supplied by the 11,400 tons of fertilizer produced annually at this facility. Cog Marketers, in partnership with AgroLiquid, is expected to produce 2mn USG of fertilizer a year at its Lake City facility in Florida with a $4mn grant from the USDA. Around 200 fertilizer retailers in the Mid-South region would receive product from this facility. Return will receive $4mn to expand production at its Northwood facility in Iowa. Other grants were awarded to projects in California, Florida, Hawaii, Iowa, Illinois, Kansas, Kentucky, Minnesota, North Carolina, North Dakota, Oregon and Washington. So far, FPEP has supplied 29 states with $251mn for increased domestic fertilizer production, with the last round of awards announced in March and January . About $649mn are left from the $900mn the administration of President Joe Biden committed to domestic fertilizer funding through FPEP in 2022. The FPEF was started in response to rising fertilizer prices caused by a variety of factors including the war in Ukraine. By Meghan Yoyotte Send comments and request more information at feedback@argusmedia.com Copyright © 2024. Argus Media group . All rights reserved.

Günstiger Frei-Haus Diesel wirft Fragen auf


24/05/23
24/05/23

Günstiger Frei-Haus Diesel wirft Fragen auf

Hamburg, 23 May (Argus) — Im Osten und Süden Deutschlands bieten mehrere Unternehmen mindestens seit Ende 2023 Diesel zur Lieferung frei Haus teils mehrere Euro pro 100l unter den Preisen ab Lager oder Raffinerie an. Händler berichten von Umsatzeinbußen. Marktteilnehmer in den entsprechenden Regionen im Osten und Nordbayern suchen nach einer Erklärung für diese großen Preisdifferenzen. Sie berichten von Diesellieferungen frei Haus, deren Preis 4,00 €/100l bis 6,00 €/100l unter den Inlandspreisnotierungen und damit weit unter ihren Einkaufspreisen liegt. Entsprechend könnten sie preislich nicht mithalten. Händler und Großhändler haben deswegen Kunden in geschäftsrelevanten Größenordnungen verloren. Inverkehrbringer von Diesel schätzen, dass täglich etwa zwischen 600 und 1000 m³ von den Niedrigpreisanbietern umgesetzt werden. Weiter geben Marktteilnehmer an, es seien diverse Zollämter auf diese Preisdiskrepanz aufmerksam gemacht und um Überprüfung gebeten worden, ein Ergebnis stehe jedoch noch aus. Die Generalzolldirektion teilte auf Anfrage von Argus mit, zu etwaigen laufenden Ermittlungen keine Auskunft geben zu können. Die Firmen, die Diesel so günstig anbieten, sind erst seit kurzer Zeit aktiv beziehungsweise waren zuvor nicht im Mineralölmarkt tätig. Gegenüber Argus haben zwei der besagten Anbieter bestätigt, dass sie Diesel unter Inlandspreisniveau verkaufen, gaben jedoch keine Auskunft darüber, wer exakt die Ware nach Deutschland importiert und diese in Verkehr bringt, also für das Aufkommen von Energiesteuer, EBV-Beitrag, CO2-Abgabe und THG-Kosten verantwortlich ist. Es handele sich um ganz normale Trading-Geschäfte. Eines der anbietenden Unternehmen teilte mit, dass Diesel mit einem Abschlag von 4,00 bis 5,00 €/100l auf Inlandspreisbasis verkauft würde. Hierbei handele es sich jedoch um große Mengen von mindestens zehn kompletten Tankzügen in der Woche. Bei kleineren Mengen wäre der Abschlag geringer. Die Ware würde im großen Umfang von mehreren Unternehmen in Rostock oder im Raum Amsterdam-Rotterdam-Antwerpen zusammen zugekauft und dann an mehrere Lagerhäuser verteilt. Dabei hat die Firma auf Nachfrage nicht angegeben, ob es sich bei den Lagerhäusern um Tanklager handele. Lagerraum würde individuell verwendet werden. Die Auslieferung an den Kunden erfolge per eigenem Spediteur. Ein anderer Anbieter ist nach eigener Aussage nur als Zwischenhändler tätig, und das seit etwa einem Jahr. Sein Vorlieferant kaufe Handelskontingente in Polen, Tschechien und auch Deutschland zu, um diese dann in Deutschland günstig auf den Markt bringen. Die Ware würde allen deutschen Vorgaben entsprechen. Von Gabriele Zindel Senden Sie Kommentare und fordern Sie weitere Informationen an feedback@argusmedia.com Copyright © 2024. Argus Media group . Alle Rechte vorbehalten.

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