French union eyes strike over Exxon's petchem closure

: Crude oil, Oil products, Petrochemicals
24/04/12

ExxonMobil's plan to close its Gravenchon petrochemical plant in Normandy has raised the possibility of more strike action in France's downstream oil sector.

The CGT trade union has called on all ExxonMobil workers in France to down tools and for the "immediate shutdown of installations". The situation is fluid and it is not immediately clear whether workers will vote on strikes today or if ExxonMobil's operations in France will be stopped.

"We are preparing our plan of action. We will be announcing it very soon," a union official told Argus.

ExxonMobil said on 11 April that the Gravenchon plant has made more than €500mn ($540mn) in losses since 2018 and that it cannot afford to continue operating at such a loss. The firm expects the site to fully close, including the steam cracker and related derivatives units, at some point this year with the loss of 677 jobs.

"The configuration of the steam cracker, its small size compared to newer units, high operating costs in Europe and higher energy prices make it uncompetitive," it said.

The announcement coincided with news that a consortium comprising trading firm Trafigura and energy infrastructure company Entara is in talks to buy ExxonMobil's 133,000 b/d Fos refinery on the French Mediterranean coast.

As well as the direct job losses at Gravenchon, the CGT said there would be an additional loss of work for around 3,000 indirect positions and sub-contractors. The local prefecture of Seine Maritime said the decision will have a "very serious impact on employment and the local economy".

The CGT said upgrades costing around €200mn are needed at Gravenchon, which is "around 0.5pc" of ExxonMobil's total profit in 2023.

ExxonMobil said the decision to close the plant will not impact operations at its adjacent 236,000 b/d Port Jerome refinery. "In current market conditions, the refinery will continue to operate and supply France with fuels, lubricants, basestocks and asphalt," the firm said.

ExxonMobil has reduced its exposure to Europe's downstream sector in recent years, selling the 198,000 b/d refinery at Augusta in Italy to Algerian state-owned Sonatrach in 2018 and divesting its stake in the 126,500 b/d Trecate refinery in northern Italy to local refiner API last year.

By Adam Porter

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24/12/19

Viewpoint: Nigeria Dangote to affect WAF crude in 2025

London, 19 December (Argus) — The ramp up of operations at Nigeria's 650,000 b/d Dangote refinery, likely to occur next year, will affect west African crude trade flows. The refinery remains well below full capacity for now — with estimated deliveries averaging just under 260,000 b/d since March — but Nigerian operator Dangote Group is aiming for 350,000 b/d of throughput in a first phase of operations. When this takes place, and Dangote makes full use of its 385,000 b/d monthly allocation deal with state-owned NNPC, it will affect the amount of Nigerian crude left to be exported to the country's key outlet — the European market. Although NNPC only supplied around 202,000 b/d in December, the total volume under the deal is equivalent to around a quarter of Nigeria's crude and condensate exports monthly exports. The deal will eventually bring support to Nigerian crude differentials when European demand is stronger — or at least cushion the decline when demand is weaker. As Dangote ramps up operations, the refiner could widen its crude slate, which could also affect crude trade flows. The refinery will take receipt of a 2mn bl cargo of US light sweet WTI bought from Chevron via a tender that closed November, after a three-month hiatus related to credit issues. Dangote has so far run exclusively on Nigerian crude and WTI, but Nigerian banks eased restrictions on provision of trade finance to the refiner, which could open the door for possible purchases of non-Nigerian west African crude. Sources close to the refinery point to Angolan heavy and medium sweet grades as likely to become part of the refinery's basket intake. Market participants also pointed that the recent WTI tender might signal Dangote's attempt to increase run rates. Meanwhile, NNPC, in order to satisfy both Dangote and already existing commitments, will seek to increase its crude production, which has been severely constrained by theft and vandalism over the past few years. But recent efforts by the government appear to be paying off, with upstream regulator NUPRC reporting that volumes lost to theft and vandalism over the past year averaged 15,000 b/d, compared with over 100,000 b/d in 2021. West African output NNPC is targeting crude output of 2mn b/d by the end of 2024, while the country's president Bola Tinubu has set a crude production goal of 2.6mn b/d by 2027. The latest figures from NUPR have November crude production at 1.49mn b/d and the targets might prove too ambitious, even though output rose from 1.33mn b/d in December last year. Angola, the second largest crude producer in Africa behind Nigeria, has also endured years of output decline since a peak of nearly 2mn b/d in 2008. Argus estimated the country's crude output at 1.14mn b/d in October, broadly unchanged from September, but down from 1.20mn b/d in August. Angola has been trying in recent years to encourage investment in its upstream sector, and recently signed an initial agreement with Shell to explore six oil offshore blocks. The upstream regulator ANPG has a target of awarding 50 oil blocks by the end of 2025 and has said it is planning a licensing round for the first quarter of that year. By Elena Mataro Send comments and request more information at feedback@argusmedia.com Copyright © 2024. Argus Media group . All rights reserved.

Reliability drives New Zealand power mix: Minister

24/12/19

Reliability drives New Zealand power mix: Minister

Sydney, 19 December (Argus) — New Zealand's conservative coalition government wants to ensure reliable generation, whether that is from coal, oil, gas, or geothermal resources, the country's resources minister Shane Jones told Argus this week. Jones was also clear about the need to draw a distinction between "the expectations on [a] small, open trading nation like [New Zealand] not to use coal and the major hope[s] and needs of the average New Zealander for affordable power, reliable power." "If [reliable power] comes from coal, that's the mix and the menu for the future," he added. Jones argued that existing renewable power sources cannot exclusively provide for New Zealand's energy needs. He instead suggested that his government is interested in promoting alternative power sources such as oil, gas and geothermal, through investments and policy changes. New Zealand's coal-fired power generation surged between July-September, according to the New Zealand's Ministry of Business Innovation and Employment (MBIE). Coal rose to 8pc of total generation from 3pc a year earlier, following a drop in hydroelectric power production. The country burned 363,513t of coal over those months, more than tripling its use for power generation purposes compared to the same period last year. Oil, gas Jones has taken steps to boost the country's oil sector since taking office in late 2023, following the coalition's victory over the centre-left Labour party. The minister introduced the Crown Minerals Amendment Bill in June, a piece of legislation that he described as being "aimed at increasing investor confidence in petroleum exploration and development." Jones told Argus that under the previous government, "people who may have been willing to [make] investment[s] and bring patient capital concluded that New Zealand was no longer available as a destination for oil and gas and this has resulted in a diminution in [oil] investment." The Crown Minerals Amendment Bill will overturn a 2018 ban on offshore oil exploration, which was introduced while Jones was serving in the previous Labour-led coalition government. New Zealand's oil sector increased its annual well spending from NZ$110mn ($63.2mn) in 2018 to NZ$403mn, in the years following the ban in 2018. The total number of active oil permits in the country has plunged from 56 to 37 over the same period, MBIE data show. New Zealand likely houses at least 223.5bn m³ of undiscovered, offshore gas reserves; 249mn bl of undiscovered, offshore oil reserves; and 177mn bl of undiscovered, offshore NGL reserves, mostly scattered around the North Island, according to US Geological Survey (USGS) estimates in 2022. The country's discovered, recoverable reserves are at between 38.3mn-52.7mn bl of oil; 29.4bn-39.8bn m³ of gas; and between 1.2mn–1.4mn t of LPG as of 1 January 2024, according to the MBIE. Besides restarting oil exploration, the Crown Minerals Amendment Bill also seeks to change permitting processes to drive capital into the sector. Permits are currently allocated through a competitive tender process, Jones told Argus this week. The government wants "the flexibility to use alternative processes to match investor interest in the most efficient and effective way by allowing the option of using non-tender methods." MBIE has indicated that the government may start using ‘priority in time' tenders, which allocates permits to the first eligible projects that apply for them, once the bill passes. But the Crown Minerals Amendment Bill does not specify how the government will manage non-competitive tenders. The government is also not using the Crown Minerals Amendment Bill to "specifically intervene in coal mining operations" in New Zealand, Jones said. But coal demand will fall "in the event that [the government is] able to expand the supply of indigenous gas," he noted. Geothermal The government's energy strategy also appears to involve doubling down on domestic geothermal generation, which is New Zealand's second most common source of power. Geothermal generators produced 2,363GWh of power between July-September, accounting for 20.5pc of total generation, in line with historical averages, according to MBIE data. New Zealand's government seems to be trying to push that share up. The government in early December decided to allocate up to NZ$60mn of public infrastructure funding to research for deep, geothermal energy production. The work will focus on drilling geothermal wells up to 6km deep, nearly twice the depth of standard wells. Jones told Argus that New Zealand officials are currently in Japan, discussing supercritical geothermal generation opportunities with engineers and scientists. By Avinash Govind Send comments and request more information at feedback@argusmedia.com Copyright © 2024. Argus Media group . All rights reserved.

US Army Corps proposes new Illinois River lock

24/12/18

US Army Corps proposes new Illinois River lock

Houston, 18 December (Argus) — The US Army Corps of Engineers (Corps) has proposed a new lock to replace the LaGrange Lock and Dam (L&D) near Beardstown, Illinois, as part of the Navigation and Ecosystem Sustainability Program (NESP). The project would be the first new lock for NESP, a program that invests in infrastructure along the Mississippi and Illinois rivers. The new 1,200ft proposed LaGrange Lock would allow for passage of more barges in a single lockage, instead of having to split the tow in two with the current 600ft LaGrange Lock. At the moment, most tows trying to pass through the LaGrange lock experience multiple hour delays. The new LaGrange lock would have an estimated cost of $20mn, with a construction timeline of five years. The project area would be located on the west bank of the Illinois River near the 85-year old LaGrange L&D, encompassing 425 acres. Real estate acquisition, design plans and contractors are already in place, said the Corps. The current LaGrange lock would remain in operation and become an auxiliary chamber. The Corps opened the upcoming project to public comments on 11 December and will close on 3 January. NESP has four other projects along the Mississippi River. Another full lock construction project is anticipated for Lock and Dam 25. By Meghan Yoyotte Send comments and request more information at feedback@argusmedia.com Copyright © 2024. Argus Media group . All rights reserved.

Alabama lock expected to reopen late April

24/12/18

Alabama lock expected to reopen late April

Houston, 18 December (Argus) — The main chamber of the Wilson Lock in Alabama along the Tennessee River is tentatively scheduled to reopen in four months, according to the US Army Corps of Engineers (Corps). The Corps expects to finish phase two of dewatering repairs on the lock on 20 April, after which navigation can resume through the main chamber of the lock. The timeline for reopening may shift depending on final assessments, the Corps said. Delays at the lock average around 12 days through the auxiliary chamber, according to the Lock Status Report by the Corps. Delays at the lock should wane during year-end holidays but pick up as spring approaches, barge carriers said. The main chamber of the Wilson Lock will have been closed for nearly seven months by the April reopening after closing on 25 September . By Meghan Yoyotte Send comments and request more information at feedback@argusmedia.com Copyright © 2024. Argus Media group . All rights reserved.

Viewpoint: rHDPE packaging grade demand solid into 2025

24/12/18

Viewpoint: rHDPE packaging grade demand solid into 2025

London, 18 December (Argus) — A number of European recyclers report stronger demand for premium rHDPE BM grades heading into 2025, but prices and margins are likely to remain under pressure. European recyclers have endured well-publicised struggles in the past two years, but demand for rHDPE BM natural and, particularly, white grades has been the brightest spot for those operating in the polyolefin market in 2024. Prices have risen by 7-8pc over the year and — while some recyclers are keen to emphasise that contracting out their 2025 volumes has not been without its difficulties — many report that they have more orders for the coming year than they are able to supply. The closure of UK-based recycler Viridor's Avonmouth recycling plant , an rHDPE natural supplier, pushed some orders to other suppliers at the end of the year. But underlying demand also appears to be rising, and large packaging companies told Argus that they expect — based on forecasts from their customers, and with the caveat that these do not always translate into physical volumes — to be using more rHDPE in 2025 than in 2024. This shows brands are keen to further increase the recycled content of their packaging, and that many see rHDPE as a good category to focus on. But challenges remain, even for recyclers that are seeing a stronger demand outlook. Packaging manufacturers and brand owners have no legal obligation to use rHDPE in 2025, and there will be a limit to what they will pay for sustainable packaging materials. Fast-moving consumer goods (FMCG) brands' sales were hit by inflation in 2022 and 2023, and they remain cognisant of the need to find the right price point with their customers as volumes recover. As a result, decreases in the virgin HDPE market and the consequent widening of the rHDPE BM-virgin HDPE BM premium to its highest since August 2023 may become an obstacle to demand. Barring a sharp rise in crude and naphtha costs that underpin the European petrochemicals chain, Argus does not expects any major increases in HDPE prices in 2025. The potential for virgin prices to cap recyclate prices will remain for the foreseeable future. Some European recyclers are also concerned about import pressure, which is resurfacing after a lull linked to two periods of unusually-higher Asia-Europe freight rates in 2024. Asian rHDPE natural pellets have been offered up to €400-500/t ($419-$524/t) cheaper than the highest-priced European supply in recent weeks. And, although some buyers prefer the optics of supporting their regional recycling industry, or the opportunity to resolve quality issues more easily and avoid traceability concerns by working with local suppliers, this price advantage may encourage more to find import sources they are comfortable with. Recyclers also still need to find an outlet for their lower-value grades, from darker/coloured packaging grades down to grades that mainly sell into "cost-saving" markets such as pipe. A typical colour-sorting recycling process produces a range of grades, reflecting the combined natural, white and mixed-colour composition of standard HDPE packaging bales in northwest Europe. But finding a home for darker pellets can be difficult in the packaging industry, where buyers like to process white or natural grades with masterbatch colourants — concentrated pigments — to preserve the appearance of their products. And construction and industrial markets are depressed by the current economic environment and unlikely to buy large volumes unless recyclers can offer a discount to virgin material. Recyclers making premium HDPE grades may therefore feel more confident than those in other polyolefin markets heading into 2025. But until buyers are more accepting of a wide range of grades, or recently-confirmed legislation mandating the use of recyclates in polyolefin packaging kicks in, they will be under no illusion that the past few years' challenges can be consigned to the rear view mirror just yet. By Will Collins Send comments and request more information at feedback@argusmedia.com Copyright © 2024. Argus Media group . All rights reserved.

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