Tag: Brent Crude

Saudi oil giant Aramco’s Chief Executive Amin Nasser said on Tuesday he sees the oil market as healthy and expects an additional 1.3 million barrels per day of demand this year.

Speaking to Reuters on the sidelines of the World Economic Forum in Davos, Nasser was responding to a question on the impact of U.S. President Donald Trump’s energy decisions, which could increase U.S. hydrocarbon output.

Oil demand this year will approach 106 million barrels per day after averaging about 104.6 million barrels per day in 2024, he said.

“We still think the market is healthy … last year we averaged around 104.6 million barrels (per day), this year, we’re expecting an additional demand of about 1.3 million barrels … so there is growth in the market,” he said.

Asked about U.S. sanctions on Russian crude tankers, he said the situation was still at an early stage.

“If you look at the impacted barrels, you’re talking about more than 2 million barrels,” he said. “We will wait and see how would that translate into tightness in the market, it is still in the early stage.”

Asked if China and India have sought additional oil volumes from Saudi Arabia on the back of the sanctions, Nasser said Aramco is bound by the levels the kingdom’s energy ministry allows it to pump. Saudi Arabia has been pumping at about three quarters of its output capacity, as part of agreements with OPEC+ to support the market.

“The kingdom and the Ministry of Energy is always looking at balancing the market. They take that into account when they give us the target of how much we should put in the market,” he said.

Aramco is working with MidOcean, an LNG firm in which it took a 51% stake, and “looking at expanding our position globally in LNG,” without giving details, Nasser said.

By Marwa Rashad, Reuters / January 21, 2025

Shell’s green hydrogen factory: a solar panel on a petrol pump – De Correspondent

ow a modest construction site on the windy Tweede Maasvlakte, soon Shell’s very latest factory. Under the sway of wind turbine blades, the oil and gas giant is building a place where, starting in 2026, sixty thousand kilos of ‘green hydrogen’ will be produced every day: Holland Hydrogen 1. ^*

Ben van Beurden, then CEO of Shell, at the announcement in 2022, said :

We are building the factory of the future

But the factory, which Shell sees as a ‘ new chapter in the energy transition’, ^* in reality hardly yields any gain for the climate. This becomes clear when we calculate the CO2 footprint of Shell’s products, with and without the green hydrogen from the new factory.

That sustainable energy experts ^* and even an environmental organization like Greenpeace ^* nevertheless see the factory as a good move, shows how complex the energy transition is in practice. Shell is the only one, they say, that can build such a factory at the moment. And that exposes a broader problem: we have become dependent on fossil companies, in the task of getting rid of fossil fuels.

Green hydrogen is the future

Hydrogen: the tiniest atom of all, perhaps best known for its presence in water (as the ‘H’ in ‘H2O’). Hydrogen is by far the most abundant element in the universe, and you could consider it the most fundamental building block of the universe. It’s not for nothing that hydrogen has atomic number 1. ^*

Unlike fossil fuels, pure hydrogen is not extracted from natural sources or pumped from the ground. Pure hydrogen, a colorless and odorless gas, is made in a factory. This can be done simply by electrifying water to separate the H’s and O’s – and voilà, pure hydrogen gas.

Like natural gas, hydrogen is flammable. ^* When hydrogen gas is burned, no CO2 is released, only water. This property makes it an alternative to fossil fuels.

When a hydrogen plant runs on renewable electricity from wind turbines or solar panels, the hydrogen produced has a zero CO2 footprint, is climate neutral and can be called ‘green hydrogen’.

A gas that you can produce and burn without CO2 emissions: that sounds ideal within the context of the energy transition.

Industry is eyeing green hydrogen. Particularly in sectors where it is difficult to replace fossil fuels such as coal or oil with electricity, green hydrogen is seen as the way to become CO2-free. Think of the steel industry, ^* the production of artificial fertilizer ^* or trucks that have to travel long distances. ^*

Another often-mentioned application of hydrogen: it can serve as a backup for the energy system, ^* necessary in a future with only green electricity. You can burn it – just like natural gas – in power stations to generate electricity during periods when the sun is not shining and the wind is not blowing

Shell’s Holland Hydrogen 1 plant, which will be connected to wind turbines in the North Sea, ^* will be Europe’s largest green hydrogen plant upon completion.

Expectations are high. Rotterdam wants to become the green hydrogen hub of Europe. ^* The hydrogen pipeline from Holland Hydrogen 1 will be expanded in the coming decades to a network that not only covers the Netherlands, but is also connected to the rest of the continent via Belgium and Germany. ^* The EU sees green hydrogen as a ‘key component’ of its transition strategy and wants it to cover no less than 10 percent of the total energy requirement in 2050. That share is currently almost zero. ^*

You could say that Shell is doing well with Holland Hydrogen 1 in promoting the energy transition and combating climate change.

From green to gray

But the green sheen quickly disappears when you follow the route of the (now partly constructed) underground gas pipe – the pipe through which the future green hydrogen will leave the factory and travel to its destination

By: hydrogen-central. January 18, 2025

Funds will go to the construction of green marine fuel storage facilities and new bunkering vessels by 2030

First project involves constructing additional liquid cargo storage facilities at Hyundai Oil Terminal in Ulsan. The port has been designated by the government as a hub for supplying greener marine fuels

SOUTH Korea is launching a green marine fuel infrastructure fund to support the development of environmentally friendly fuel facilities and bunkering vessels.

The fund, co-established by the Ministry of Oceans and Fisheries and the Korea Ocean Business Corporation (KOBC), will invest a total of Won1trn ($680m) by 2030, according to a government statement.

Of the total, Won600bn will be allocated for building port storage facilities for LNG, methanol, and ammonia, while Won400bn is earmarked for constructing four bunkering vessels.

The initiative is designed to meet growing demand for green fuels from South Korea-flagged vessels and ensure reliable fuel supplies for foreign ships calling at domestic ports.

The fund’s first project will involve the construction of additional liquid cargo storage facilities at Hyundai Oil Terminal in Ulsan, at a total cost of Won240bn. Of this, Won130bn will be provided by the fund, with the goal of stabilising methanol fuel demand for both domestic and international vessels.

Hyundai Oil Terminal, which began operations in 2012, features dock facilities for vessels up to 50,000 dwt and approximately 280,000 kilolitres of storage capacity on an 86,821 m² landfill site. Initially established by HD Hyundai Oilbank, the terminal became an independent company after the refiner sold its majority stake in 2021.

The fund’s second project will focus on the construction of the Yeosu Myodo LNG hub terminal, with a total budget of Won1.4trn. The terminal will be built on 270,000 m² of reclaimed land and will include a 100,000 tonne pier, three LNG storage tanks, transportation pipelines, and other facilities. Completion is expected by the end of 2027.

An MoF official told Lloyd’s List the fund was a follow-up to the ministry’s 2023 policy announcement. At the time, the government outlined plans to provide 10%-30% subsidies for the construction of environmentally friendly bunkering vessels and to encourage private investment in green marine fuels through KOBC’s financial backing and guarantees.

The port of Ulsan has been designated as a hub for supplying environmentally friendly marine fuels, as part of the government’s broader strategy to enhance the global competitiveness of South Korea’s ports.

A signing ceremony for the fund’s investment will be held on January 14, with participation from major stakeholders, including Korea Development Bank, Kyobo Life Insurance, Woori Asset Management, MoF, KOBC, and Hyundai Oil Terminal.

The MoF said in a statement: “The ability to supply environmentally friendly marine fuel determines the competitiveness of ports. We will continue to gain competitive advantage through the management of the fund.”

By: Moyoun Jin / 13 Jan 2025

Nigerians may experience a rise in petroleum product prices in the coming days due to the increase in the cost of Brent, the global benchmark for crude. Crude oil price is a key commodity that sets the price of refined petroleum products.

Crude oil prices rise in the international market According to reports, on Sunday, January 12, 2025, Brent crude price reached $79.76 per barrel.

The increase in the commodity price from $72.88 recorded in December 2024 impacted fuel prices across Nigerian depots.

Experts have attributed the rise in price to geopolitical tensions, particularly sanctions on Russian oil exports by the US. Also, supply issues and seasonal demand fluctuations in colder regions may be responsible for the rise in crude prices.

Marketers adjust prices at depots Findings showed that several fuel depots began reporting diesel price increases on Friday, January 10, 2025, marking the beginning of a rise in fuel costs.

Experts have said the Brent crude oil price surge is a major driver, as many Nigerian depot owners depend on it to meet diesel demand.

The relationship between crude oil prices and refined products is well-established, as Brent is a global benchmark for petroleum product pricing.

With crude prices increasing, importers are likely to implement new prices to cover higher procurement and shipping costs.

The Nigerian government’s oil price benchmark in the 2025 budget projects price at $75 per barrel. According to available data, diesel price movements at the loading depot indicate that NIPCO depot, in law, increased their prices by N70 from Friday, January 10, 2025, from N1,050 to N1,120 per litre.

Punch reports that Prudent Depot increased its prices to N1,045 from N1,025 per litre. Marketers give reason for the slow distribution of fuel Energy analysts disclosed that depots were on standby to increase loading prices of refined petroleum products beginning Monday, January 13, 2025.

Meanwhile, marketers have blamed the slow pace of construction work on the East-West Road for the poor distribution of petroleum products from the Port Harcourt refinery.

The Petroleum Retail Outlet Owners Association of Nigeria (PETROAN) said the slow pace of work on the East-West Road has impacted about 60 filling stations.

Marketers and oil companies partner to build new refinery Legit.ng earlier reported that Petroleum products marketers and three oil firms inked a deal to build a 50,000 barrels per day capacity refinery, PETROAN signed the agreement with Claridge Petroleum Company Limited, Oasis Petroleum Products Limited and another company on Wednesday, January 8, 2025.

By:Pascal Oparada, Legit / January 13, 2025.

ADNOC Gas plc and its subsidiaries (“ADNOC Gas”), a world-class integrated gas processing company, announced on January 9 the awarding of three enabling contracts worth $2.1 billion for an LNG pre-conditioning plant (LPP), compression facilities and transmission pipelines to supply feedstock to the Ruwais LNG Project.

The LPP and compression facilities will be located within ADNOC Gas’ Habshan 5 plant, part of one of the world’s largest integrated gas processing complexes. The five plants of the Habshan Complex have a combined capacity to process 6.1 billion standard cubic feet of gas per day. The newly awarded transmission pipelines will connect the Habshan Complex with the Ruwais LNG facility.

The largest contract, valued at $1.24 billion for the LPP, was awarded to a consortium consisting of Engineering for the Petroleum and Process Industries (ENPPI) and Petrojet. A $514 million contract for transmission pipelines was awarded to the China Petroleum Pipeline Engineering Company, while Petrofac Emirates LLC will develop the new compression facilities under a $335 million contract. 

Fatema Al Nuaimi, Chief Executive Officer of ADNOC Gas, said: “These contract awards reaffirm ADNOC Gas’ commitment to delivering sustainable growth and maximizing shareholder value. We are investing in world-class infrastructure and innovative technologies as we expand our capacity in LNG liquefaction and strengthen our position as a global player.
 
The awards also underline our commitment to making strategic and targeted investments that enable the delivery of our most significant projects, allowing us to continue meeting our customers’ demands internationally.”

ADNOC Gas is developing the Ruwais LNG project on behalf of its largest shareholder, ADNOC. The capital expenditure (CAPEX) for the LPP, compression facilities and transmission pipelines, does not form part of the costs previously outlined by ADNOC Gas for its intended acquisition of ADNOC’s majority stake in the Ruwais LNG project once the plant becomes operational in 2028.

The three contracts will establish the key infrastructure needed to supply feedstock to the Ruwais LNG export facility. This investment is part of the $15 billion CAPEX plan through 2029, as outlined in ADNOC Gas’ recent strategy update.

When it becomes fully operational, the Ruwais LNG plant will more than double ADNOC Gas’ current LNG production capacity to more than 15 million tonnes per annum (mtpa). The export facility will feature two liquefaction trains, each with a processing capacity of 4.8 mtpa, powered by clean grid electricity—a first in the Middle East and North Africa region.

Upon completion, Ruwais LNG will be one of the lowest-carbon intensity LNG plants in the world, leveraging artificial intelligence and other advanced digital technologies to enhance safety, minimize emissions and drive efficiency.

ADNOC Gas which refers to ADNOC Gas Plc and its subsidiaries, is a world-class, large-scale integrated gas processing company operating across the gas value chain, from receipt of feedstock from ADNOC through large, long-life operations for gas processing and fractionation to the sale of products to domestic and international customers. ADNOC Gas supplies approximately 60% of the UAE’s sales gas needs and supplies end-customers in over twenty countries.

By: portnews / January 11 2025

Worker safety has come a long way in the past few decades with less than half the number of incidents and worker deaths per 100 workers in 2024 than there were in the 1970s. 

But there are innate dangers in the oil and gas sector where workers may be exposed to hazardous environments, exposure to hydrocarbon gases and vapors, heavy machinery and equipment and innately dangerous working spaces (such as high up on an oil platform).

In 2020, the U.S. Bureau of Labor Statistics recorded 44 employee deaths in the oil and gas extraction industry.

The Occupational Safety and Health Administration (OSHA) in the United States recommends that all oil and gas companies have strict policies and procedures in place to help mitigate the risk from these hazards and ensure that all workers and contractors have the appropriate levels of training and PPE to prevent injury.

READ: How Chevron and Chevron Phillips Chemical are Prioritizing Worker Safety in Remote and Hazardous Environments

Here are the top 5 key safety risks in oil and gas:

#1: Vehicle Collisions

The Center for Disease Control says that motor vehicle crashes cause almost half (over 40%) of work-related deaths in the oil and gas extraction industry. Long shifts patterns and/or long-distance travel to remote well sites may contribute to these crashes as can driver fatigue.

#2: Struck-By/ Caught-In/ Caught-Between

Oil and gas worksites have all sorts of moving vehicles and heavy equipment (such as cranes or hoists), high pressure lines, elevator bales, and others. Getting hit by or caught between falling or moving equipment causes approximately 60% of on-site work fatalities in oil and gas extraction.

#3: Explosions and Fires

By its very nature, oil and gas workers operate around explosive and flammable gases. These gases may come from many sources, according to OSHA, including production equipment, tanks, shale shakers, trucks, and wells. Workers must take extra care when performing operations such as welding in environments where explosive potential exists.

#4: Falls

Falling from a high platform such as a mast or drilling platform is another risk that workers in the oil and gas industry face. To mitigate these risks, employers must ensure that workers have appropriate training and “fall arrest” mechanisms – such as safety harnesses – must be in place when workers are at height. Some fall deaths in the industry can be attributed to incorrectly following procedures or inadequately applied safety mechanisms.

#5: Confined Spaces

Oil and gas operations include confined spaces such as storage tanks and pits. When workers enter these environments, they can be exposed to hazardous or flammable chemicals. Extra care must be made to wear protective equipment and continuously monitored if they are known to harbor potential atmospheric hazards.

Other risks include lifting heavy items, which may result in back or muscle injuries, risks of blowouts from lines or equipment under high levels of pressure, and electrical or other energy hazards.

Interested in learning more?

Join over 300 digital and operations leaders at The Connected Worker: Energy Summit, taking place March 18-20, 2025, in Houston, TX. Discover how to create a safer work environment, boost compliance, and improve efficiencies through automation. This year’s summit will focus on increasing collaboration, eliminating organizational silos, and enabling cross-functional decision-making across the asset lifecycle and supply chain.

By: Oil & Gas IQ , 08 January 2025

The volume of global crude exports in 2024 declined 2%, the first fall since the COVID-19 pandemic, shipping data showed, due to weak demand growth and as refinery and pipeline changes reshuffled trade routes.

Global crude flows have been roiled for a second year by war in Ukraine and the Middle East, with tanker shipments rerouted and suppliers and buyers split into regions. Middle East oil exports to Europe declined and more U.S. oil and South American oil went to Europe. Russian oil that formerly went to Europe has been redirected to India and China.

These shifts have become more pronounced as oil refineries have shut in Europe amid continued attacks on Red Sea shipping. Middle Eastern crude exports to Europe tumbled 22% in 2024, ship tracking data from researcher Kpler showed.

The shift in oil flows “is creating opportunistic alliances,” said Adi Imsirovic, an energy consultant and former oil trader, citing closer relationships between Russia and India, China and Iran that are reshaping oil trade.

“Oil is no longer flowing along the least cost curve, and the first consequence is tight shipping, which raises freight prices and eventually cuts into refining margins,” said Imsirovic.

The U.S. with its surging shale production has been a winner in the global oil trade. The country exports 4 million barrels per day, boosting its share of global oil trade to 9.5%, behind Saudi Arabia and Russia.

Trade routes have also been reshuffled by startup of the massive Dangote oil refinery in Nigeria, expansion of Canada’s Trans Mountain pipeline to the country’s west coast, falling oil output in Mexico, a brief halt in Libyan oil exports, and rising Guyana volumes.

In 2025, suppliers will keep grappling with falling fuel demand in major consuming centers such as China. Also, more countries will use less oil and more gas, while renewable energy will keep growing.

“This kind of uncertainty and volatility is the new normal – 2019 was the last ‘normal’ year,” said Erik Broekhuizen, a marine research and consulting manager at ship brokering firm Poten & Partners.

FURTHER ROOM TO FALL

Changes in oil demand forecasts have pulled the rug out from historical long-term oil market growth assumptions, Broekhuizen said.

“In the past, you could always say that there will be healthy long-term demand growth, and that solves a lot of problems over time. That can’t really be taken for granted anymore,” he said, citing weaker demand in China and Europe.

China’s imports fell about 3% last year with gains in electric and plug-in hybrid cars, and growing use of liquefied natural gas in its heavy trucking. In Europe, lower refining capacity and government mandates to reduce carbon have shaved crude imports by about 1%.

NEW SUPPLIERS, NEW ROUTES

Europe’s refiners initially cut Russian imports and increased both U.S. and Middle Eastern oil purchases after Russia invaded Ukraine. Attacks on ships in the Red Sea following Israel’s war on Gaza pushed up the cost of shipping from the Middle East. Refiners stepped up imports from the U.S. and Guyana to record highs.

Exports from Iraq declined 82,000 bpd and United Arab Emirates exports fell 35,000 bpd in 2024. Europe added 162,000 bpd from Guyana and 60,000 bpd from the U.S.

Escalating Middle East conflict around late September and fears of more sanctions from U.S. President-elect Donald Trump led to tighter supply and higher prices of Iranian oil. This prompted Chinese refiners to look at oil from West Africa and Brazil.

NEW REFINERIES, PIPELINES

Nigeria’s new Dangote refinery consumed enough domestic supply to keep around 13% of Nigeria’s crude exports in the country in 2024, up from 2% in 2023, according to Kpler. That cut Nigeria’s exports to Europe, and Nigeria also imported 47,000 bpd of U.S. WTI, unusual for a major net exporter.

New refining capacity ramping up in Bahrain, Oman and Iraq as well as Dos Bocas in Mexico are also likely to soak up oil production in those regions.

In Canada, the expanded Trans Mountain pipeline can now ship an extra 590,000 bpd to the Pacific Coast, lifting the nation’s waterborne exports to a record 550,000 bpd in 2024.

This has had a ripple effect: With increased Canadian crude flowing to the U.S. West Coast, refineries in the region bought less Saudi Arabian and Latin American crude, while direct shipments from Canada to Asian countries have cut re-exports from the U.S. Gulf Coast.

While China has been Canada’s major buyer, the crude has also found importers in India, Japan, South Korea and Brunei and more Asian refiners are likely to purchase the oil, analysts noted.

Trump’s proposed 25% tariff on Canadian and Mexican crude, the top two foreign oil suppliers to the U.S., could also change oil flows in 2025, analysts said.

By Tank Terminals 01.08.2025

Phillips 66 (NYSE:PSX) announced today that it has entered into a definitive agreement to buy EPIC Y-Grade GP, LLC and EPIC Y-Grade, LP, which own various subsidiaries and long haul natural gas liquids pipelines, fractionation facilities and distribution systems (“EPIC NGL”) for total cash consideration of $2.2 billion, subject to customary purchase price adjustments. Upon closing, this transaction is expected to be immediately accretive to earnings per share.

“This transaction bolsters Phillips 66’s position as a leading integrated downstream energy provider,” said Mark Lashier, chairman and CEO of Phillips 66. “This transaction optimizes our Permian NGL value chain, allows Phillips 66 to provide producers with comprehensive flow assurance, reaching fractionation facilities near Corpus Christi, Sweeny, and Mont Belvieu, Texas, and is expected to deliver attractive returns in excess of our hurdle rates.”

The EPIC NGL business consists of two fractionators (170 MBD) near Corpus Christi, Texas, approximately 350 miles of purity distribution pipelines and an approximately 885-mile NGL pipeline (175 MBD) linking production supplies in the Delaware, Midland and Eagle Ford basins to such fractionation complexes and to the Phillips 66 Sweeny Hub. EPIC NGL is in the process of increasing its pipeline capacity to 225 MBD and has sanctioned a second expansion to increase capacity to 350 MBD. Phillips 66 does not expect to increase its recently announced 2025 capital program in connection with that expansion. EPIC NGL has also identified a third fractionation facility that could bring its fractionation capacity up to 280 MBD. The facilities connect Permian production to Gulf Coast refiners, petrochemical companies, and export markets and will be highly integrated with the Phillips 66 asset base.

The transaction is subject to customary closing conditions, including required regulatory clearance.

By: Business Wire / January 07, 2025

Climate experts have warned that continued investments in fossil fuels will create the risk of assets worth $557 trillion being left useless by 2050

Some of the world’s biggest oil companies are abandoning promises to shift to renewable energy, and planning to expand their fossil fuel exploration despite growing call for an urgent energy transition.

Top energy companies including BP, Shell, Exxon and Chevron doubled down on oil and gas in 2024 to focus on near-term profits.

That shift came at the cost of their plans to decarbonise — a trend that is on track to continue into 2025.

European Big Oil firms BP and Shell sharply slowed their plans to spend billions on wind and solar power projects this year and shifted spending to higher-margin oil and gas projects.

That was despite both firms lobbying for billions of dollars in subsidies for carbon capture, a climate technology aimed at capturing CO2 emissions from large sources, such as oil refineries. Climate experts say the technology cannot be a substitute for targeted emission reductions.

BP, which had aimed for a 20-fold growth in renewable power this decade to 50 gigawatts, announced in December it would spin off almost all its offshore wind projects into a joint venture with Japanese power generator JERA.

Shell, which once pledged to become the world’s largest electricity company, largely stopped investments in new offshore wind projects, exited power markets in Europe and China and weakened carbon reduction targets.

Shell told Reuters it remained committed to becoming a net zero emissions energy business by 2050 and continues to invest in the energy transition.

Meanwhile, Norway’s state-controlled Equinor also slowed spending on renewables.

BP, Shell and Equinor reduced low-carbon spending by 8% in 2024, Rohan Bowater, analyst at Accela Research, told Reuters.

Similarly, American big oil firms Exxon and Chevron have also firmed up their commitment to fossil fuel expansion.

Early this month Exxon Mobil said it was looking to increase its oil and gas output by 18% between 2026 and 2030. It is looking to increase its earnings by 2030 by $20 billion over this year’s projected $34.2 billion.

Meanwhile, Chevron increased its oil and gas volumes by 7% year-over-year, while planning to cut back spending on low-carbon projects by 25%.

Both Exxon and Chevron are now planning to enter the electricity business eyeing increasing energy demands at data centres, fuelled by an artificial intelligence boom. The firms are looking use natural gas to power the technology industry’s AI data centres.

Researchers say the carbon footprint of natural gas is 33% worse than that of coal.

Faltering policies

The retrenchment by oil majors comes after governments around the world slowed the rollout of clean energy policies and delayed targets as energy costs soared following Russia’s full-scale invasion of Ukraine in 2022.

European oil giants that had invested heavily in the clean energy transition found their share performance lagging US rivals Exxon and Chevron, which had kept their focus on oil and gas.

“Geopolitical disruptions like the invasion of Ukraine have weakened CEO incentives to prioritise the low-carbon transition amid high oil prices and evolving investor expectations,” Accela Research’s Bowater said.

Meanwhile, Equinor blamed supply-chain bottlenecks and high prices for its slow moves on wind energy.

“The offshore wind segment has been through demanding times in the last couple of years due to inflation, cost increase, bottlenecks in the supply chain,” Equinor told Reuters.

The company “will continue to be selective and disciplined in our approach,” it added.

The scenario is the same in the US, where both Exxon and Chevron have blamed a lack of “clarity” on rules on energy subsidies for holding back investments in climate technologies and renewables.

Tougher days ahead

Global heat-trapping carbon emissions are forecast to climb to a new high in 2024, which will be the warmest year on record.

And 2025 is shaping up to be another tumultuous year for the $3 trillion energy sector, with climate-sceptic Donald Trump returning to the White House.

China, the world’s biggest crude oil importer, is also trying to revive its faltering economy, potentially boosting oil demand.

Meanwhile, Europe also faces continued uncertainty over the war in Ukraine and political turmoil in Germany and France.

All those tensions were laid bare at the annual United Nations climate conference in Baku in Azerbaijan in November, when the host country’s President Ilham Aliyev, hailed oil and gas as “a gift from God”.

That summit yielded a global climate finance deal but disappointed climate advocates who had hoped governments would coalesce around a phase-out of oil, gas and coal.

The energy companies will be watching to see if Trump follows through on promises to repeal President Joe Biden’s landmark green energy policies, which have spurred investments in renewables across the United States.

Trump has vowed to remove the United States from global climate efforts, and has appointed another climate sceptic, oil executive Chris Wright, as his energy secretary.

Oil and gas pitfalls

Despite those concerns, however, there are potential pitfalls in the energy majors’ renewed emphasis on oil and gas.

Demand growth in China, which has driven global prices for two decades, is slowing, with growing signs that its gasoline and diesel consumption is plateauing.

At the same time, OPEC and top oil producing allies have repeatedly delayed plans to unwind supply cuts as other countries, led by the United States, increase oil output.

As a result, analysts expect oil companies to face tighter financial constraints next year. Net debt for the top five western oil giants is expected to rise to $148 billion in 2024 from $92 billion in 2022, based on LSEG estimates.

There is also mounting regulatory pressure on oil companies, with states like New York planning to fine fossil fuel companies a total of $75 billion over the next 25 years to pay for damage caused to the climate.

Meanwhile, climate experts have warned that continued investments in fossil fuels create the risk of assets worth $557 trillion being left useless by 2050.

Researchers say no new fossil fuel projects are needed for the world to reach net-zero emissions by the middle of the century.

By: Vishakha Saxena, Asiafinancial / 8 January 2025

Lipow Oil Associates President Andy Lipow discusses 2025’s global oil outlook under the upcoming Trump administration on Catalysts.
OIL.

Lipow identifies Trump’s expected deregulation policies and “drill baby drill” stance as potential catalysts for increased oil production efficiency.
However. he warns of “the biggest impediment” to reaching substantial
growth this coming year. The global oil market already faces oversupply heading into 2025.
The oil market is not particularly concerned about supply over the next few years, especially in an environment where Chinese oil demand growth has disappointed,” he tells Yahoo Finance, highlighting Chinas lower-than-expected consumption in 2024.
Regarding industry consolidation under Trump. Lipow notes. “There’s not many large players left.” Nevertheless, he emphasizes that oil producers must consolidate to enhance operational efficiencies.

By: Oil Companies News / 08 January 2025