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Nigerian road project push could see switch to concrete

  • Spanish Market: Oil products
  • 21/08/24

The Nigerian government is involving some key concrete producers in a raft of new federal road projects across the country, signalling greater intent to switch away from asphalt.

Works minister David Umahi said last month that 20 new road projects are to be funded through the federal government's Road Infrastructure Development and Refurbishment Investment Tax Credit Scheme and are to be supported by private-sector firms including Dangote Group, BUA Group, Mainstream Energy Solutions and MTN.

Suppliers of bitumen — which is used to make asphalt, the predominant material for road paving — say the involvement of Dangote and BUA, both important Nigerian cement producers, is likely to signal a greater intent by the government to push for a switch away from asphalt, which could significantly dent Nigerian bitumen demand growth prospects.

One market participant said most new federal road projects, including those under the tax credit scheme, are being designed on the basis of cement construction.

Umahi began pushing for a switch to concrete last summer after he took up his ministerial role. But some industry and political opposition to the move, as well as the high costs involved in concrete road construction, created uncertainty over the policy's progress. Meanwhile, Nigerian market participants have pointed out that large volumes of bitumen will still be needed for repair and maintenance of the existing road network.

Spanner in the works

Nigeria, which produces little to no bitumen itself, imported 280,000-290,000t last year, slightly higher than in 2022. Prior to the change in government last year, some bitumen suppliers had expected Nigerian consumption to reach as high 400,000-450,000 t/yr in the coming years. But the new government's concrete roads push has put a major dent in those expectations.

There was the usual seasonal surge in bitumen imports in the first half of this year during the peak dry season for road construction activity, but a decision by President Bola Tinubu's administration to sharply devalue the naira against the US dollar in late January drove up domestic bitumen truck prices, discouraging some buying.

A lagged reaction to the naira devaluation pushed domestic truck prices to N1.35mn/t ex-works by mid-February from N1.15mn/t at the start of the month, before rising further to reach a peak of N1.55-1.6mn/t in early March. A subsequent recovery in the value of the naira helped push prices back down to N1.2-1.3mn/t ex-works by early July. A renewed slide in the Naira followed, but was not accompanied by a rise in bitumen truck prices until mid-August.

One market participant said prices had been "shockingly stable" as suppliers tried to encourage buying during the low demand rainy season that usually runs from late June until October. Prices were raised to N1.32-1.35mn/t ex-works last week in a belated bid by suppliers to recover some margin.

Even when the Nigerian road construction season resumes later this year, the renewed push to encourage concrete road construction is likely to keep demand for bitumen and mixed asphalt in check, although the continued need at federal and state level for repair, maintenance and upgrade projects on existing asphalted roads should support consumption and imports.


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05/05/25

California refinery closures panic politicians

California refinery closures panic politicians

Houston, 5 May (Argus) — California could lose up to 17pc of its refining capacity within a year, triggering major concerns about its tightly supplied and frequently volatile products market. US independent Valero announced on 16 April that it will shut or repurpose its 145,000 b/d Benicia refinery near San Francisco by April 2026. The firm is also evaluating strategic alternatives for its 85,000 b/d Wilmington refinery in Los Angeles. And independent Phillips 66 said in October that it would shut its 139,000 b/d Los Angeles refinery in the fourth quarter of this year. Valero's Benicia announcement brought a quick reaction from state officials. Governor Gavin Newsom on 21 April urged regulators at the California Energy Commission (CEC) to work closely with refiners through "high-level, immediate engagement" to make sure Californians have access to transport fuels. He has ordered them to recommend by 1 July any changes to California's approach that are needed to ensure adequate fuel supply during its energy transition. The message appears to have hit home. The CEC delayed a vote on new refinery resupply rules to provide time for additional feedback and consultation with stakeholders after the Valero announcement. The CEC also plans to introduce a rule this year for minimum inventory requirements at refineries in the state as well as possible rules on setting a refiner margin cap. The new rules are part of an effort by Newsom to mitigate fuel price volatility in California, including the signing of two pieces of legislation known as AB X2-1 and SB X1-2. Refiners have been unhappy with the state's regulatory and enforcement environment for some time. It is "the most stringent and difficult" in North America owing to 20 years of policies pursuing a move away from fossil fuels, Valero chief executive Lane Riggs says. The long and short of it Refinery closures are fuelling long and short-term supply concerns in California. The most immediate is an anticipated supply crunch at the end of this summer. Phillips 66's plan to shut the Los Angeles refinery by October will deal a significant blow to the state's refining capacity and is likely to occur at a time when Californian gasoline prices are most prone to volatility. The US west coast is an isolated market, many weeks sailing time from alternative supply sources in east Asia or the US Gulf coast. California's strict product specifications further limit who can step in when refinery output falls. The state sometimes sees price spikes in late summer and early autumn because the switch from summer gasoline blends leaves local inventories low while in-state refineries adjust to producing winter grades. California gasoline prices spiked in September 2022 when stocks fell to a nine-year low on the west coast. Spot deliveries hit a record $2.45/USG premium to Nymex Rbob futures in the Los Angeles market at the time (see graph). Production problems at several refineries in southern California led to another spot price surge in September 2023. The California Air Resources Board (Carb) permitted an earlier switch to cheaper winter gasoline production in response to both events. Refinery closures will force California to rely on imports in the longer term, leaving the state exposed to stretched supply lines. State regulators' proposed solutions have raised eyebrows. The CEC's Transportation Fuels Assessment report in August last year included a policy option in which California would buy and own refineries, which the state is not pursuing. Another option involves state-owned products reserves to allow rapid deployment of fuel when needed. The CEC and Carb regulators will also release a draft transportation fuels transition plan later this year. By Eunice Bridges and Jasmine Davis Send comments and request more information at feedback@argusmedia.com Copyright © 2025. Argus Media group . All rights reserved.

Australia’s election gives LNG, fuels sector certainty


05/05/25
05/05/25

Australia’s election gives LNG, fuels sector certainty

Sydney, 5 May (Argus) — Australia's governing Labor party's second majority term could mean that changes to the offshore permitting regime promised last year are signed into law, while east coast LNG businesses will avoid a planned reservation system proposed by the opposition. Labor's victory at the 3 May election combined with the election of fewer members from the Greens party and climate-focused independents, could mean it faces less pressure to cancel fossil fuel projects. But it will remain reliant on the Greens to pass laws through the nation's upper house — the senate — meaning Labor may need to negotiate the passage of bills with the leftist party if the Liberal-National-based coalition opposes its measures. The Greens ran on a promise to ban new coal, oil and gas projects but won fewer seats than in 2022 because of preference flows. A federal decision on the lifetime extension of the Woodside Energy-operated 14.4mn t/yr North West Shelf (NWS) LNG delayed by Labor, is now looking more positive for the firm. The firm sees approval as vital to progressing its Browse gas development offshore northwestern Australia. Voters' rejection of the opposition Coalition on the nation's east coast means its policy to reserve a further 50-100PJ (1.34bn-2.68bn m³/yr) from the Gladstone-based LNG exporters will not proceed. The result provides an opportunity for certainty and stability for the energy sector, upstream lobby Australian Energy Producers said. The group urged the government to focus on new supply as Australia's gas reserves for domestic use rapidly deplete. The government will need to specify exactly how it aims to secure supplies to ensure stable supply, once coal-fired generators retire at the end of the 2020s and into the 2030s. This is because the nation's integrated system plan is based on Labor's policy of reaching 82pc renewable energy in the power grid, backed up by about 15GW of gas-fired power. Industry will await further direction stemming from the Future Gas Strategy which canvassed solutions to Australia's declining gas supply including new pipelines, storage and seasonal LNG imports. Permitting concerns In the government's previous three-year term, a series of court-ordered requirements to consult with affected Aboriginal groups briefly disrupted multi-billion dollar LNG developments. Labor promised to specify through new laws exactly which groups must be consulted before approvals could be granted. But these were dropped from the agenda in early 2024 following opposition by the Greens. Labor's resources minister Madeleine King blamed the Greens for obstructionist manoeuvres on this legislation, but it remains unclear if and when Labor might introduce such laws. Conversely, the Coalition promised to end government support for anti-gas lobbies such as law group the Environmental Defenders Office — set to continue under Labor. In liquid fuels, Labor's victory should boost Australia's electric vehicle (EV) sales, with emissions standards laws set to remain enforced. The Coalition had said it would soften the laws because of concern over cost of living pressures. Plans to temporarily cut the fuel excise will also not progress. Australia's EV take-up has stalled, and industry has blamed this on poor investment in recharging infrastructure and other policy settings, including the removal of the fringe benefits tax exemption for plug-in hybrid car models. A re-elected Labor government is likely to further policy towards a mandate for sustainable aviation fuel or renewable diesel, given the growing share of Australia's emissions projected to come from the transport industry. It pledged A$250mn ($162mn) for low-carbon liquid fuels development in March , for low-carbon liquid fuels development in March, as part of its commitment to the nascent sector. Local market participants are optimistic that further biofuels support will be provided as urgency to meet net zero ambitions builds, including a 2030 target of 43pc lower emissions based on 2005 levels. About A$6bn/yr of feedstocks like canola, tallow and used cooking oil are exported from Australia, while existing ethanol and biodiesel producers are running underutilised plants, making about 175mn litres/yr at present, because of poorly-enforced blending mandates. By Tom Major Send comments and request more information at feedback@argusmedia.com Copyright © 2025. Argus Media group . All rights reserved.

Chevron 'not surprised' Calif refineries shutting


02/05/25
02/05/25

Chevron 'not surprised' Calif refineries shutting

Houston, 2 May (Argus) — Chevron's chief executive said today he is not surprised that refineries in California are shutting down, because the state has made it "nearly impossible" to invest going forward. Independent refiner Valero on 16 April said it is planning to shut or re-purpose its 145,000 b/d refinery in Benicia, California, by April 2026. This comes as Phillips 66 is planning to shut its 139,000 b/d Los Angeles refinery later this year. "I'm not surprised to see the announcements that have come out," chief executive Mike Wirth said Friday on Chevron's first-quarter earnings call. Policies coming out of the state "make it nearly impossible to invest in California going forward", he said. The state inserting itself into operational matters like planning turnarounds is "an unwise move", Wirth said. Chevron operates two large refineries in the state — the 269,000 b/d El Segundo, refinery and the 245,000 b/d Richmond refinery. "We do not have any announcements on our refineries at this time," Wirth said. California governor Gavin Newsom last year signed into law AB X2-1, legislation authorizing the state's energy regulator to require refiners to maintain minimum gasoline inventories. The bill is part of a multi-year effort by Newsom to mitigate price spikes at the pump, authorizing the California Energy Commission (CEC) to regulate, develop and impose requirements for in-state refiners to maintain minimum stocks of gasoline and gasoline blending components. The agency is in the rule-making process for some of the regulations, but a vote on a refinery resupply rule was postponed last month to allow for more engagement with stakeholders. The closures of Valero's Benicia refinery and Phillips 66's Los Angeles refinery will eliminate 17pc of the state's crude refining capacity. PBF Energy, which also operates refineries in California, said Thursday that the shutdowns will cause a 250,000 b/d shortfall in gasoline in the state and lead to growing reliance on more expensive imports. Valero chief executive Lane Riggs said last week that California's regulatory and enforcement environment is "the most stringent and difficult" in North America due to 20 years of policies pursuing a move away from fossil fuels. California will require 100pc of in-state sales of new cars and trucks to be electric, plug-in hybrid or hydrogen models by 2035. Five days after Valero's announcement to shut Benicia, Newsom urged state regulators to work closely with refiners on short-term and long-term planning, including through "high-level, immediate engagement" to make sure Californians have access to transportation fuels, according to a letter sent to CEC vice chair Siva Gunda. Newsom ordered the CEC to work with a cross-agency task force to recommend by 1 July any changes in the state's approach that are needed to ensure adequate fuel supply during the state's energy transition. By Eunice Bridges Send comments and request more information at feedback@argusmedia.com Copyright © 2025. Argus Media group . All rights reserved.

Shell’s 1Q European gas production up


02/05/25
02/05/25

Shell’s 1Q European gas production up

London, 2 May (Argus) — Shell's European gas production for sale in January-March slightly stepped up on the year, but the company expects works to limit global oil and gas production this quarter. Shell produced 24.9mn m³/d in the first quarter, up from 24.8mn m³/d a year earlier but below the 25.2mn m³/d in fourth-quarter 2024. Shell has stakes in UK and Dutch fields, as well as a 17.8pc share in Norway's Ormen Lange field and an 8.1pc stake in the giant Troll field. Output from the two Norwegian fields was down on the year in January-February, the latest months for which data are available. Ormen Lange produced 19.8mn m³/d in January-February, down from 22.6mn m³/d a year earlier. Troll production averaged 123.6mn m³/d over those two months, also down from 126.2mn m³/d a year earlier. Shell's integrated gas business was the company's top performing segment with profits of $2.8bn, slightly higher on the year. Lighter maintenance at the Pearl gas-to-liquids plant in Qatar supported production, but unplanned works and weather constraints in Australia left the company's LNG volumes at 6.6mn t in January-March from 7.6mn t a year earlier, Shell said. Meanwhile, Shell's upstream division posted $2.1bn in profit, down 8.5pc on the year earlier but double compared with the fourth quarter 2024. The segment was hit with a $509mn tax bill related to the UK's Energy Profits Levy in the first quarter, partially offset by gains from asset sales. Across the entire company, Shell reported first-quarter profits adjusted for inventory valuation effects and one-off items of $5.6bn, surpassing analysts' expectations of $5.3bn . Shell's first-quarter worldwide oil, liquids and gas production was 2.84mn boe/d, down from 2.91mn boe/d a year earlier but up from 2.82mn boe/d in the previous quarter. The company expects lower oil and gas production this quarter in a 2.45mn-2.71mn boe/d range because of maintenance across its integrated gas portfolio and an absence of volumes from its SPDC business in Nigeria, which Shell sold off in March. By Aleksandra Godlewska and Jon Mainwaring Send comments and request more information at feedback@argusmedia.com Copyright © 2025. Argus Media group . All rights reserved.

Shell’s 1Q profit falls but beats expectations


02/05/25
02/05/25

Shell’s 1Q profit falls but beats expectations

London, 2 May (Argus) — Shell's Integrated Gas business segment delivered a solid performance in the first quarter, helping the UK major exceed analysts' earnings estimates despite ongoing struggles in its downstream Chemicals and Products business. Shell reported a first-quarter profit of $4.8bn, down from $7.4bn a year earlier. Adjusted for inventory valuation effects and one-off items, profit was $5.6bn, surpassing analysts' expectations of $5.3bn. Integrated Gas was Shell's top-performing segment, with a profit of $2.8bn, slightly higher than the first quarter of 2024. Production was down by 6.6pc year-on-year at 927,000 b/d oil equivalent (boe/d), but up 2pc from the previous quarter. Less maintenance at the Pearl gas-to-liquids plant in Qatar had a positive impact on production, Shell said. But the company's LNG volumes were affected by unplanned maintenance and weather constraints in Australia, falling to 6.6mn t from 7.6mn t a year earlier. The Upstream segment posted a profit of $2.1bn, down by 8.5pc on a year earlier but double what it made in the fourth quarter of 2024. The segment was hit with a $509mn tax charge related to the UK's Energy Profits Levy in the first quarter, partially offset by gains from asset sales. Production for the segment was slightly down compared to a year earlier at 1.86mn boe/d, partly due to the divestment of Shell's SPDC business in Nigeria. Overall, Shell's first-quarter production was 2.84mn boe/d, down from 2.91mn boe/d a year earlier but up from 2.82mn boe/d in the previous quarter. Shell expects lower production in the current quarter, ranging from 2.45mn boe/d to 2.71mn boe/d due to maintenance across its Integrated Gas portfolio and the absence of volumes from the SPDC business. The Chemicals and Products segment reported a $77mn loss for the first quarter, compared to a $1.3bn profit a year earlier. Refinery runs were down by 4.8pc year-on-year, and chemicals sales volumes were marginally lower. Despite persistent low margins in the downstream, Shell noted that refining and chemicals margins improved compared to the fourth quarter. Shell expects capital spending for 2025 to be within a $20bn-$22bn range, in line with last year's spending. The company is maintaining its dividend at 35.8¢/share and its share buyback programme at $3.5bn a quarter. By Jon Mainwaring Send comments and request more information at feedback@argusmedia.com Copyright © 2025. Argus Media group . All rights reserved.

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