Saudi Crude Shipments to China Poised to Fall in September

Saudi Arabia will ship lower volumes of its crude to China next month, down from a two-year-high this month, after the Kingdom raised its September prices to Asia for a second consecutive month, Reuters reported on Monday, quoting trade sources at Chinese refiners. 

Saudi Arabia, the world’s biggest crude oil exporter, is expected to deliver about 43 million barrels of crude to China in September, according to a Reuters estimate of allocations for refiners. 

This is equal to 1.43 million bpd of Saudi shipments to the world’s largest crude oil importer next month, down from an estimated 1.65 million bpd which Saudi Aramco has allocated to Chinese refiners for August. 

Sinopec, the biggest refiner in Asia, and its Fujian Refinery joint venture with Saudi Aramco, are among refiners that plan to reduce their intake of Saudi crude in September, according to Reuters’ sources. 

The lower expected shipments would come as Saudi Aramco last week raised the official selling prices (OSPs) for its crude loading for Asia in September as it bets on robust demand. 

The flagship Saudi grade Arab Light will sell in Asia next month at a premium of $3.20 per barrel above the Oman/Dubai average, the Middle East benchmark, off which shipments to Asia are priced. 

The hike is $1.00 a barrel above the August price, as well as the second consecutive rise in the price of Arab Light loading for Asia.

Saudi Arabia also lifted the official selling prices (OSPs) for the other grades, Arab Extra Light, Arab Medium, and Arab Heavy, by between $0.70 and $1.20 per barrel above benchmarks.  

The second consecutive increase in prices suggests that Saudi Arabia expect continued robust demand in its key exporting region, Asia, in the coming weeks. 

A potential reduction of Russian supply to India, due to the new tariffs, could also boost the demand for Saudi and other Middle Eastern crude shipments to Asia next month and going forward.   

By: Oilprice.com / Tsvetana Paraskova – Aug 11, 2025.

Dialog’s earnings stay steady amid strong storage demand

Dialog Group Bhd’s earnings remain stable, supported by improved occupancy and spot rates at its independent tank terminals, driven by sustained regional demand for storage.

Kenanga Research said the completion of legacy engineering, procurement, construction and commissioning (EPCC) contracts, which had been affected by cost escalations, should pave the way for at least a breakeven performance in the coming quarters.

“For now, we believe the market’s expectations are sufficiently conservative, and there remains upside potential in its medium-term earnings outlook.

“That aside, the anticipated upturn in plant maintenance and turnaround activities in downstream Malaysia from financial year 2026 (FY26) could benefit its core plant maintenance segment,” it added.

Kenanga Research said Dialog’s recent joint venture, which includes a US$330 million terminal usage agreement tied to the Pengerang Biorefinery project, was a positive surprise, as no additional capacity expansion beyond previously announced plans had been factored in.

However, it said the internal rate of return (IRR) is expected to be lower at 9.5 per cent, compared to 11–13 per cent for earlier projects.

“This could partly be due to a higher capex-to-capacity ratio of RM5,217 per cubic metre, versus RM4,846 per cubic metre for Pengerang Terminals 2, which has a capacity of 1.3 million cubic metres,” it added.

Based on a weighted average cost of capital of 6.3 per cent, Kenanga Research estimates a discounted cash flow valuation accretion of RM0.02 per share, while the annual earnings contribution is projected at RM16 million, or four per cent of its FY25 forecast.

Notably, it said the project is environmental, social and governance-aligned, serving as a storage hub for sustainable aviation fuel, hydrogenated vegetable oil and bionaphtha.

Kenanga Research has maintained an “Outperform” call on Dialog, with a target price of RM1.96.

The firm continues to favour Dialog due to the ongoing margin recovery in its plant maintenance, EPCC and specialist product businesses.

By: nst S. Birruntha – August 3, 2025 

The Trans Mountain pipeline is delivering

Construction on the Trans Mountain Expansion Project began in the summer of 2018. The project, which involved construction of a new pipeline parallel to the existing one, was proposed to ease the bottleneck on Western Canadian crude and increase flows to the West Coast, opening access to new markets. 

The pipeline expansion became fully operational in May 2024 and since then has nearly tripled the capacity of the existing pipeline through the Rocky Mountains from Edmonton, Alberta, to the port of Burnaby, British Columbia, where Canadian crude can be shipped to new markets by sea.

Following the first year of operation, let’s look at the impact of the pipeline expansion on crude oil movements, inventories and exports.

Pipeline movements

In the 12-month period since the opening of the expansion in May 2024, average pipeline movements of crude oil and equivalent products from Alberta to British Columbia increased more than fivefold (+449.9%) compared with the 12 months before the opening, reaching a series high of 2.8 million cubic metres in March 2025.

Movements of hydrocarbon gas liquids and refined petroleum products were less impacted by the expansion, but still grew on average by over one-quarter (+28.3%) during the same period.

Monthly gross domestic product (GDP) by industry at the national level for crude oil pipelines and other pipeline transportation also rose following construction of the new line. Average GDP for this industry from May 2024 to April 2025 was 8.5% higher than the average during the same period one year earlier. Some other pipeline movements may also have contributed to this gain, although the Trans Mountain expansion was the lone new major pipeline project added during this period.

Inventories

In conjunction with the pipeline’s construction, the storage terminal was expanded in Burnaby, British Columbia, to store the crude oil after it has made its way across the Rocky Mountains.

With a new storage capacity of approximately 875 000 cubic metres (5.5 million barrels), up from the previous capacity of nearly 270 000 cubic metres, the additional terminal storage—along with the crude in the expanded pipeline—were the primary contributors to the overall increase in closing inventories of crude oil and equivalents in British Columbia. Closing inventories in British Columbia reached a series high of 1.1 million cubic metres in May 2024 when the new pipeline was opened, 158.4% higher than the same month in 2023.

Export volumes and destinations

The United States remained the primary destination for Canadian crude oil, accounting for 93.8% of all Canadian crude oil exports from May 2024 to April 2025, with 92.8% of total US-bound crude oil exports moving across the border through the existing pipeline network. With the Trans Mountain Expanded System, Canadian crude can now be exported in higher volumes by ship to US West Coast states and Asia.

According to Canadian International Merchandise Trade statistics, within the first 12 months of the pipeline opening, total crude oil volumes exported through British Columbia surged by more than sixfold. The United States remained the primary destination, even as it fell to 51.9% from May 2024 to April 2025 compared to 100.0% in the previous 12 months.

During the same period, crude oil shipments to non-US destinations accounted for 48.1% of exports by volume. China accounted for almost one-third (31.9%), followed by Hong Kong (7.1%), Singapore (6.3%), South Korea (1.6%) and India (1.2%).

Crude oil exports shipped via British Columbia to all destinations were valued at nearly $13.9 billion in this period.

By: statcan / August 26, 2025.

American Natural Gas Demand Poised for Historic Highs in 2025

U.S. natural gas consumption is on track to set a new record in 2025, according to the Energy Information Administration. In its latest Short-Term Energy Outlook, the agency projected demand will average 91.4 billion cubic feet per day, up from 90.5 bcf/d in 2024. January usage climbed to 126.8 bcf/d, 5% higher than the same month a year earlier, reflecting colder conditions and steady heating requirements.

Natural gas continues to show strong resilience. Despite rapid additions of renewable generation, natural gas remains the dominant fuel for electricity production, underpinned by competitive prices and flexible supply. Industrial facilities, especially petrochemicals, continue to absorb large volumes, reinforcing the fuel’s central role in U.S. manufacturing.

Market pricing reflected a modest decline. At mid-day on Monday, Henry Hub natural gas traded at $2.677 per MMBtu, down 0.70% from the previous session. Prices remain under pressure from high storage inventories and steady production, even as annual consumption is set to hit new records.

Fundamentals remain heavy. Working gas stocks stand at 3,199 Bcf, or around 6% above the five?year average, according to the latest EIA storage report. EIA’s weekly update also shows dry gas production averaging 107.4 Bcf/d last week (up from 101.8 Bcf/d a year earlier), keeping supply elevated. NOAA’s population?weighted degree?day outlook for the week into August 30 indicates national cooling demand roughly near to slightly below normal, limiting late?August power?burn upside even as the EIA projects record 2025 consumption in its latest forecast.

The EIA also emphasized the growing influence of exports. Several new liquefaction trains are scheduled to begin operations in 2025, lifting liquefied natural gas shipments and extending America’s lead as the world’s top exporter. The agency expects LNG demand from Asia and Europe to absorb a significant share of incremental U.S. output, with global buyers seeking secure supply amid ongoing geopolitical disruptions.

With domestic demand rising and export capacity expanding, U.S. natural gas markets face a sharp contrast between bearish short-term pricing and bullish long-term fundamentals.

By Charles Kennedy, Oilprice.com – Aug 25, 2025

IEA: 2025 Global Oil Supply to Exceed Expectations

The International Energy Agency (IEA) has revised its forecast for global oil supply growth, projecting a stronger-than-expected increase for 2025 and 2026.

The International Energy Agency (IEA) has revised its forecast for global oil supply growth, projecting a stronger-than-expected increase for 2025 and 2026.

Global oil supply growth is now revised up by 370Mb/d to 2.5MMb/d this year and by 620Mb/d to 1.9MMb/d in 2026. This adjustment follows an agreement on Aug. 3 by eight OPEC+ members to raise production by another 547Mb/d in September, fully unwinding the 2.2MMb/d cuts agreed to in November 2023.
OPEC+ crude and NGLs will account for 1.1MMb/d of supply growth this year and 890Mb/d in 2026. Despite these gains, non-OPEC+ producers will continue to lead growth, adding 1.3MMb/d in 2025 and 1MMb/d in 2026, bolstered by rising output from US NGLs, Canadian crude, and offshore oil from the US, Brazil, and Guyana.

Global oil demand growth for 2025 has been downgraded by a combined 350Mb/d since the beginning of the year. Demand is now projected to rise by around 700Mb/d this year and next. The latest data indicate lackluster demand across major economies, with consumption in emerging and developing economies, including China, Brazil, Egypt, and India, revised down.

The market has so far absorbed the additional barrels as refinery activity reached an all-time high. However, global observed oil inventories built by 1.5MMb/d in 2Q25, with Chinese crude stocks rising by 900Mb/d and US gas liquids by another 900Mb/d. Crude and product stocks in major pricing hubs remain below historical averages.

New sanctions on Russia and Iran could curb supplies from the world’s third- and fifth-largest producers. In late July, the US Department of the Treasury announced sanctions aimed at making it more difficult for Iran to sell its oil. Washington is also pressuring major buyers of Russian crude, and the European Union will impose a ban on imports of oil products refined from Russian crude oil starting in January 2026. By contrast, restrictions on Venezuela have been eased, with Chevron recently awarded a new license to operate and export oil.

Oil prices have been volatile, with Brent crude futures hovering around US$70/b in July before slipping to around US$67/b in early August. The report concludes that “something will have to give for the market to balance” as forecast supply increasingly outpaces demand.

By: MexicoBusiness / 08/21/2025

How is Chevron Swapping Oil and Gas for Sustainable Energy?

Chevron’s 2025 Q2 results show record output and progress in renewable diesel, lithium extraction and LNG expansion, advancing its lower-carbon strategy

Chevron Corporation’s Q2 2025 results highlight not only record oil and gas production but also clear steps towards lowering the carbon intensity of its operations and building a more sustainable energy portfolio. 

While the company reported earnings of US$2.5bn compared to US$4.4bn in the same quarter last year, the period was defined by strategic investments in cleaner energy and diversification into new markets.

Renewable fuels and low carbon operations

One of the most significant sustainability milestones was the start of production at Chevron’s renewable diesel plant in Geismar, Louisiana. 

Following a capacity upgrade, the facility increased output from 7,000 to 22,000 barrels per day, positioning it as a cornerstone of Chevron’s growing renewable fuels business.

Alongside renewable diesel, Chevron continues to pursue carbon capture and offsets, hydrogen and lower-carbon power generation. 

These are part of a wider strategy to reduce the carbon intensity of its energy mix while maintaining reliable supply.

“Second quarter results reflect continued strong execution, record production and exceptional cash generation,” says Mike Wirth, Chevron’s Chairman and CEO.

By: Chloe Williment / August 21, 2025

Black gold meets green ambition in Saudi Arabia’s energy shift to China

Riyadh’s strategic alliance with Beijing is accelerating its energy transformation, undermining western hegemony and anchoring the kingdom in Asia’s multipolar future.

Saudi Arabia is no longer merely the world’s oil well. Under Crown Prince Mohammed bin Salman’s (MbS) sweeping reforms of Vision 2030, Riyadh is racing to transform its hydrocarbon-based economy into a diversified energy powerhouse. In a deeply geopolitical transition, the kingdom has been turning decisively eastward toward China.

For decades, the Saudi social contract was underwritten by crude oil revenues. Now, that contract is being redefined. The state’s ability to fund strategic transformations from green hydrogen megaprojects to solar deserts is increasingly sustained by non-oil income, which now comprises 40 percent of total government revenue. 

This shift reflects a deliberate policy of economic diversification to end what MbS has described as the country’s “addiction to oil,” bolstered by a strategic partnership with China, which has accelerated the kingdom’s energy transition and opened new geopolitical horizons. 

Saudi Arabia is increasingly turning toward Beijing, while China is strengthening its presence in West Asian markets and regional influence, with far-reaching implications for the structure of the global energy system and the balance of power in the region. 

Recasting the energy blueprint

The transformation began in earnest in April 2016, when then-defense minister MbS introduced Vision 2030.

This document laid out a comprehensive roadmap to shift Saudi Arabia’s economic foundations away from oil dependency. 

Our country is rich in its natural resources. We are not dependent solely on oil for our energy needs. Gold, phosphate, uranium, and many other valuable minerals are found beneath our lands. But our real wealth lies in the ambition of our people and the potential of our younger generation.”

Among its stated goals: raise foreign direct investment from 3.8 to 5.7 percent of GDP, expand the private sector’s role from 40 to 65 percent, increase non-oil exports from 16 to 50 percent of GDP, and develop strategic sectors including tourism, mining, renewable energy, and defense manufacturing.

To achieve these ambitions, Riyadh earmarked nearly $270 billion for renewable energy projects. Solar energy forms the spine of this transformation. Projects like the King Salman Renewable Energy Initiative and the solar mega-plant under construction in the ambitious smart city NEOM, expected to deliver 2.6 gigawatts and power over a million homes, represent the scale of the kingdom’s ambitions. Wind energy is gaining traction, too. The 400-megawatt Dumat al-Jandal wind farm is already operational, supplying electricity to around 70,000 households.

Perhaps the most revolutionary pillar of this strategy is green hydrogen. Currently, the world’s largest green hydrogen-based ammonia production facility run on renewable energy is being established by NEOM Green Hydrogen Company. 

By using renewable electricity to split water molecules, Saudi Arabia plans to produce emissions-free hydrogen fuel. These developments are underpinned by partnerships with global firms like SEFE Energy and prominent Chinese clean tech investors. The ultimate goal is to become a major exporter of clean energy, enabling Riyadh to decarbonize its economy while maintaining its status as an energy superpower.

Data from the Saudi Ministry of Finance shows that in 2024, total government revenues reached 1.26 trillion riyals (about $336 billion), a four percent increase year-on-year. Spending climbed to 1.37 trillion riyals, up six percent, widening the deficit to 115.63 billion riyals. Within this structure, non-oil revenues approached half of all state income for the first time, representing 502.47 billion riyals, or 40 percent of the total, after an annual growth rate of nearly 10 percent. 

Taxes on goods and services dominated at 57.5 percent of this figure, followed by non-tax revenues, capital gains, and international trade taxes. Meanwhile, oil’s share of revenue slipped to 60 percent, reflecting Riyadh’s compliance with OPEC+ output cuts. These fiscal shifts are steadily realigning the budget, reducing volatility, and strengthening the kingdom’s ability to finance its long-term energy diversification.

The Saudi–Chinese energy axis

Riyadh’s energy ambitions are closely tied to its growing strategic relationship with China. Over the past two decades, Saudi Arabia has redirected its oil exports toward the east. In the first five months of 2025, China accounted for 24.3 percent of Saudi oil exports, followed by Japan (16.5 percent), South Korea (15.4 percent), ASEAN states (11.3 percent), India (10 percent), and Taiwan (4.1 percent). In contrast, the US received just 3.3 percent, and the EU a mere 0.2 percent.

This is a calculated shift in Saudi strategy, aligning the kingdom’s energy future with the rising economies of East Asia. Aramco’s long-term supply contracts and joint ventures with Asian partners are designed to lock in market share and deepen economic integration. 

One landmark deal was struck in March 2023, when Aramco acquired a 10 percent stake in China’s Rongsheng Petrochemical for $3.6 billion in exchange for a 20-year supply contract delivering 480,000 barrels per day (bpd). Additional joint projects in northeast China will increase total supply by another 690,000 barrels daily.

Saudi Arabia is also laying the groundwork for clean energy exports. It has signed memoranda of understanding (MoU) with energy companies in Japan, South Korea, and Germany to pilot shipments of blue and green ammonia. These efforts mirror the export strategies of major liquefied natural gas (LNG) producers like Qatar and aim to secure Riyadh’s dominance in the emerging hydrogen economy.

Renewable infrastructure: Fast-tracked and eastbound

According to the Middle East Economic Survey (MEES) issued in February 2025, Saudi Arabia’s renewable electricity generation capacity will nearly double this year, rising from about 6.5 gigawatts (GW) to around 12.7 GW by year’s end. 

This includes several projects, most notably the 91‑megawatt Layla solar photovoltaic plant being developed jointly by Saudi and Chinese companies. To address the natural intermittency of solar and wind, Riyadh plans to pair this growth with battery storage systems.

Saudi Arabia also boasts ultra‑competitive renewable electricity costs. One solar project was priced at $0.0129 per kilowatt‑hour – among the lowest in the world. This strengthens Riyadh’s ambition to become a major exporter of green hydrogen, despite continued doubts over fluctuating demand and infrastructure costs. Work has already begun on a massive green hydrogen facility in NEOM on the Red Sea coast.

Today, Saudi Arabia dominates the region’s renewable energy growth, accounting for more than 40 percent of the expansion projected between 2024 and 2030. The UAE, the Israeli occupation state, Oman, Egypt, Iraq, and Morocco combined represent another 44 percent.

Beyond climate pledges, two structural drivers fuel this surge: soaring domestic demand and climate‑induced stress. Peak demand has reached record levels in Kuwait, Egypt, Algeria, Oman, and Iraq, triggering outages in Egypt and Kuwait’s first‑ever nationwide blackout. Saudi Arabia itself saw record consumption in 2023 amid rapid population and economic growth.

Aramco’s evolution: Beyond hydrocarbons

While oil remains a foundational pillar of the Saudi economy, Aramco has repositioned itself as a diversified energy giant. In 2020, it shipped the world’s first 40-ton batch of blue ammonia to Japan in a pilot project. 

By 2021, Saudi energy officials were discussing plans to supply hydrogen to Asia and Europe. Aramco has committed to producing 11 million tons of low-carbon blue ammonia annually by 2030, supported by the kingdom’s natural gas reserves and geological carbon storage capacity.

Last year, the country’s sovereign wealth fund, the Public Investment Fund (PIF), launched a $10-billion energy solutions company to finance green hydrogen and related infrastructure. Meanwhile, Aramco continues to pursue international partnerships and domestic investments to consolidate its role in the energy transition.

Saudi Arabia understands that securing long-term hydrogen contracts today may yield the same strategic advantages that long-term LNG contracts brought Qatar. Riyadh’s leadership has actively hosted global hydrogen forums and positioned the kingdom as a future energy hub in a multipolar world order.

Climates, consumption, and regional urgency

Saudi Arabia’s renewable energy push is driven not only by diversification but also by necessity. The Persian Gulf region is warming rapidly, and electricity demand is surging. In 2023, Saudi power consumption reached record highs. 

This demand surge is largely climate-induced. As temperatures rise, cooling requirements skyrocket. West Asian states, including the occupation state, are struggling to maintain energy stability amid growing populations and urban expansion. Saudi Arabia’s strategic investment in renewables is also an investment in energy security.

Its natural environment is a critical asset. With some of the most solar-suitable land on the planet and significant wind corridors, the kingdom can produce clean energy at ultra-competitive rates. These conditions, combined with aggressive policy support and Chinese investment, make Riyadh a formidable player in the future global energy economy.

A new map of power 

Saudi Arabia’s transformation marks a reordering of energy, economy, and influence, clearly making more than a mere national project.

By reducing its reliance on oil and embedding itself within Asia’s economic ascent, Riyadh is openly challenging the dominance of the western‑led energy system. The kingdom is no longer content to remain an oil exporter and is positioning itself as a supplier of electricity, hydrogen, and advanced energy technologies. 

As Washington’s sway diminishes, Beijing’s presence grows. Saudi Arabia’s eastward energy shift declares that the future of global power, and the expansion of Saudi influence, will be shaped not in the Atlantic, but across Eurasia.

By: Mohamad Hasan Sweidan / AUG 21, 2025.

California is sunsetting oil refineries without a plan for what’s next

Global refining stands at a pivotal crossroads as shifting regional demand patterns, escalating sustainability pressures, and heightened energy security concerns reshape the industry landscape.

Within the past year, two major California oil refineries have announced plans to shutter — moves that will pull about one quarter of a million barrels from the state’s daily supply of gasoline.

For a state that has been a standard-bearer in the push to get off fossil fuels, this might seem like a win. Instead, it’s caught political leaders off guard, unprepared, and scrambling to keep open the very facilities they once villainized.

The Phillips 66 refinery south of Los Angeles is slated to close by the end of this year, an announcement the company made last fall, two days after Governor Gavin Newsom signed legislation giving the state more authority to regulate such operations. This spring, Valero said it will close its Bay Area facility in 2026, citing in part a record $82 million fine for air pollution that was more than 360 times the legal limit.

Valero did not respond to a request for comment. Phillips 66 spokesperson Al Ortiz told Grist, “Our focus right now is on safely idling our facilities. We are proud of the work we have done and continue to do with the state to ensure we will be able to meet future market demand.”

Between the two closures, California is slated to lose 17 percent of its refining capacity, which could cause gas prices to surge past the already nation-leading price of $4.50 per gallon. It’s unclear what the closures might mean for reducing greenhouse gas emissions, as the state will likely import gasoline to cover a portion of the shortfall and people tend not to drastically decrease consumption even when prices go up.

Lawmakers don’t appear to have planned for this scenario.

“The state is largely without a system-wide transition plan,” Cottie Petrie-Norris, a Democrat who represents portions of Orange County in the state assembly, said at a recent hearing. Creating such a roadmap, she noted, “is one of the most complicated, and I believe important, challenges that policymakers will need to face in the decade ahead.”

By: bicmagazine / August 20, 2025

US refiners ready for heavy crude return

US refiners are expecting a boost from returning medium and heavy crude supplies from Canada, Venezuela and the Opec+ group of countries.

About 2mn-2.5mn b/d of medium and heavy crude should be returning to the market in the autumn, coinciding with seasonal refinery maintenance, US independent PBF Energy chief executive Matthew Lucey says. This will cause light-heavy spreads to widen in the third and fourth quarters, he says. Additional supplies will be “a huge tailwind going forward” for PBF by lowering the cost of feedstocks, which has “a dollar-for-dollar impact” on the company’s bottom line, Lucey says.

US sanctions against Venezuela pulled about 200,000 b/d out of the US Gulf coast market and Canadian wildfires took about 5mn bl of June supply off the market, Valero’s chief operating officer Gary Simmons says. “Things will get better,” probably starting in the fourth quarter, he says.

Marathon Petroleum chief commercial officer Rick Hessling says that he sees “positive trends” in Canadian oil for his company’s refineries that consume large amounts of heavy and medium crude. These include less competition for supply because of turnarounds at the US Gulf coast in the autumn. “The signals and the differentials are already beginning to change,” he says. Mars and WCS crudes have fallen by $0.70-1.00/bl against benchmark WTI prices since late July (see graph).

Meanwhile, Chevron-linked oil tankers have converged on Venezuela’s main terminals. One is already carrying a cargo of Boscan crude from Bajo Grande and another Hamaca crude from the Jose terminal. The movements suggest Chevron has resumed loading Venezuelan crude for export in August under its restricted US licence. Chevron said previously that it expects limited oil flows to resume from Venezuela to the US this month after the administration of President Donald Trump reversed course on an earlier decision to cancel its licence to operate.

Re-engagement rings

In another supply boost, eight predominantly sour crude producers in Opec+ will raise their collective production target by 547,000 b/d in September, matching an increase in August. This means the group will have restored all of a scheduled 2.46mn b/d increase in six months. US refiners have not seen that much of this rise in Opec+ production so far because of higher oil burn at power stations in the Mideast Gulf in the summer, Simmons says. “As we move out of summer, more of those barrels will make their way to the market,” he says. Valero has recently “re-engaged” with historic partners in the Middle East, Simmons says, suggesting to him that Opec’s Mideast Gulf members plan to sell more crude to the US.

HF Sinclair commercial vice-president Steven Ledbetter agrees that higher Opec+ production is not yet having an impact on light-heavy crude spreads in the US market. But it will in the longer term, together with Canadian production exceeding pipeline export capacity, he says. Forward markets show heavy crude at a $9-10/bl discount to light crude in the third quarter and a $13/bl discount in the fourth quarter, he says. There is potential for that heavy crude discount to get even larger sometime in 2026, Ledbetter says.

Marathon is also looking forward to having access to more heavy crude produced in California because of the upcoming closures of two large refineries in the state, Hessling says. The firm’s 365,000 b/d Los Angeles refinery “will have access to a lot of local California crudes” to which it currently has limited or no access, he says. Valero is planning to shut or repurpose its 145,000 b/d Benicia refinery near San Francisco by April and Phillips 66 plans to shut its 139,000 b/d Los Angeles refinery complex by the end of this year.

By: Eunice Bridges / 18/08/25

Global refining capacity grows despite fewer refineries

Global refining stands at a pivotal crossroads as shifting regional demand patterns, escalating sustainability pressures, and heightened energy security concerns reshape the industry landscape.

According to research from Rystad Energy, although the number of refineries worldwide has decreased over the past two decades, overall refining capacity has expanded to meet the rising volume of oil requiring processing.In the last 20 years, global primary refining capacity grew by approximately 13.5 million barrels per day (bpd), about a 15 per cent increase.
However, the absolute number of refineries peaked in 2011 and has since steadily declined — an outcome driven by aging infrastructure, shrinking profit margins, and weakening fuel demand amid advancing electrification.The current growth in global refining capacity is primarily fuelled by the Middle East, China, and India, with China and India serving as key drivers in Asia.
China’s refining capacity nearly doubled from 10.6 million bpd in 2005 to an estimated 18.8 million bpd in 2025.This expansion reflects efforts to meet rising domestic demand, bolster energy security, and position China as a major exporter of refined products.
India’s capacity also increased steadily from 2.9 million bpd in 2005 to about 5.2 million bpd in 2025, supported by strong domestic consumption and strategic investment in refining infrastructure.
The Middle East has similarly expanded refining capacity from roughly 8 million bpd to 13 million bpd over the past two decades, primarily through major additions in Saudi Arabia and the UAE.This growth reflects a strategic shift to move beyond crude oil exports by capturing greater value through downstream integration.
The region is developing complex, large-scale refineries designed not only to serve growing domestic demand but also to supply key export markets globally.
Arne Skjaeveland, Vice President of Oil & Gas Research at Rystad Energy, explains the regional dynamics: “The Middle East and Asia are driving global refining growth by focusing on large, integrated mega-refineries that secure energy supplies and meet rapidly rising demand.“In contrast, Europe and the US are retreating, with older, less efficient plants closing due to high costs and uncertainty over future fuel needs.“This shift has sparked a wave of rationalisation, where smaller, less flexible refineries are being shut down while bigger, more adaptable facilities gain ground through economies of scale.“Today, nearly all new projects are larger and more economically viable, so even though the total number of refineries worldwide has declined, overall refining capacity continues to grow significantly.”Regarding emissions, the evolving refinery landscape tells a divided story.
Emissions intensity across the sector has remained relatively steady, but absolute emissions show a marked regional split.Total refinery emissions surged in Asia and the Middle East owing to rapid capacity growth and throughput.
The newer, sophisticated refineries in these regions often consume more energy by design but achieve better carbon efficiency per barrel due to modern technologies and tighter integration.In contrast, emissions in North America and Europe have remained flat or declined, driven mostly by retrofits and refinery closures rather than substantial carbon efficiency improvements.As climate policies tighten and demand for low-carbon solutions increases, the gap between leading refineries in Asia and the Middle East and those lagging behind elsewhere is expected to widen, reshaping competitiveness and investment decisions within the sector.A clear divide in strategies is visible among major global refiners.Companies like Chevron and TotalEnergies focus on consolidation and modernisation amid stricter regulations and shifting fuel demand.
Chevron invests approximately US$1.5 billion annually upgrading legacy sites such as Pascagoula and Pasadena, achieving high utilisation rates of 86 per cent despite aging assets.
TotalEnergies is actively preparing for a lower-carbon future by integrating advanced biofuel technologies into its refining portfolio.By contrast, national oil companies such as Saudi Aramco are aggressively expanding their refining footprints with multibillion-dollar investments.
Projects like the Jazan complex and joint ventures including YASREF and SATORP boost capacity and complexity but come with higher emissions intensity — averaging around 41 kilograms of carbon dioxide equivalent (CO₂e) per barrel — reflecting the processing of heavier crudes and energy-intensive operations.This evolving global refining landscape underscores a balancing act between growing demand, sustainability imperatives, and energy security considerations that will define the sector’s trajectory in the years ahead.

By: Petroleumaustralia / 14 Aug, 2025