Australia's Refinery Decline: The Timeline And Impact
- 01. When did Australia stop refining oil?
- 02. How Australia's refining capacity unravelled
- 03. Timeline of major refinery closures
- 04. Refinery capacity and output in recent years
- 05. Why Australia stopped refining oil
- 06. The impact on Australia's fuel security
- 07. Future outlook: more imports or a refining comeback?
When did Australia stop refining oil?
Australia did not stop refining oil all at once; instead, the country's domestic oil refining sector has been shrinking in stages since the early 2010s, with the last major closures occurring between 2021 and 2023. By 2023, only two refineries-Shell's Geelong refinery in Victoria and Ampol's Lytton refinery in Queensland-still produced fuel from crude oil, while all other major plants had either shut down or been converted into import terminals. In practical terms, Australia effectively "stopped" refining oil at scale when the final big refineries ceased operations at the start of this decade, leaving the nation dependent on imported refined fuel rather than domestic crude-oil processing.
How Australia's refining capacity unravelled
At its peak, Australia had around seven large, crude-processing oil refineries, clustered around major cities. These refineries supplied virtually all of the country's petrol, diesel, and jet fuel, with small volumes supplemented by imports. Between 2013 and 2021, a wave of closures and conversions-driven by economics, regulation, and global competition-eroded local refining capacity so far that Australia now operates at a fraction of its historical throughput. By 2023, the remaining refineries were so small in global terms that they could not offset the country's 90-plus-percent dependence on imported fuel.
Each shutdown followed a similar pattern: declining margins, rising compliance costs (especially for lower-sulfur fuel), and the emergence of cheaper, more efficient competitors in Asia. Studies from the Australian Parliament and the International Energy Agency estimate that gross refining margins in Australia fell by roughly 30-40 percent between 2010 and 2020, making downstream operations increasingly unprofitable without government support. Industry analysts at the time warned that at least half of Australia's refineries were "at risk" by 2015, and events over the next decade largely validated that projection.
Timeline of major refinery closures
Over roughly two decades, Australia's refining landscape shifted from a self-sufficient domestic network to a system dominated by imported products. The following timeline captures the key moments when operating refineries left the stage, either by closing or converting to import terminals:
- 2003-2009: ExxonMobil's Port Stanvac refinery near Adelaide was mothballed in 2003 and permanently closed in 2009 after being deemed too small and inefficient to compete with larger Asian rivals.
- 2013: Shell's Clyde refinery in Sydney shut down; its site was reconfigured as a fuel import and storage terminal.
- 2014: Caltex Australia closed the Kurnell refinery in Sydney, which processed some of the heaviest crude in the region, and later converted it into an import terminal.
- 2015: BP shut down the Bulwer Island refinery in Brisbane, leaving the Lytton refinery as the only major crude processor in Queensland.
- 2021: BP Australia ceased crude-oil processing at the Kwinana refinery in Perth and converted it into a fuel import terminal, effectively ending Western Australia's local refining.
- 2021-2023: ExxonMobil's Altona refinery in Melbourne moved through a phased wind-down, with crude runs ceasing and the facility transitioning to an import-oriented terminal by 2023.
By the end of this sequence, only Geelong and Lytton remained as active refineries, together accounting for less than 20 percent of the country's total historical refining capacity. Even those plants now operate under tight margins and are highly sensitive to global fuel-price swings and shipping disruptions.
Refinery capacity and output in recent years
Below is a simplified table summarizing the historical role of Australia's major refineries and their 2023 status, illustrating how crude-oil throughput has collapsed over time. Capacity figures are rounded to the nearest thousand barrels per day (k bpd) and reflect the last full years of operation before closure or conversion.
| Refinery | Location | Peak capacity (k bpd) | Typical capacity ca. 2007-2010 | Status as of 2023 |
|---|---|---|---|---|
| Kwinana refinery | Perth, Western Australia | 120-130 | 79.6 | Converted to fuel import terminal |
| Kurnell refinery | Sydney, New South Wales | 110-120 | 75.4 | Converted to fuel import terminal |
| Geelong refinery | Geelong, Victoria | 100-110 | 63.8 | Still operating (Shell → Viva Energy) |
| Lytton refinery | Brisbane, Queensland | 100-110 | 62.7 | Still operating (Ampol) |
| Bulwer Island refinery | Brisbane, Queensland | 75-85 | 51.1 | Permanently closed, site repurposed |
| Clyde refinery | Sydney, New South Wales | 70-80 | 49.3 | Converted to fuel import terminal |
| Altona refinery | Melbourne, Victoria | 65-75 | 45.3 | Converted to fuel import terminal |
Industry data from 2023 show that Australia's total "effective" refining capacity from the two remaining plants amounted to roughly 235,000 barrels of crude per day, down from about 550,000-600,000 barrels per day at the turn of the millennium. That contraction-over a little more than 20 years-makes Australia one of the most rapidly de-industrialized refining regions in the high-income world.
Why Australia stopped refining oil
The decision to exit domestic oil refining was not the result of a single event but of converging economic, regulatory, and geopolitical forces. Analysts and parliament-level reports consistently highlight four main factors:
Global competition from larger, more efficient refineries in Asia dramatically undercut margins in Australia. Refineries in South Korea, China, and Singapore could process heavier crudes at lower costs due to scale and state-backed infrastructure, leaving Australia's relatively small plants at a structural disadvantage. By the mid-2010s, Australian refiners were earning roughly 2-3 dollars per barrel less than their Asian peers, even after accounting for import taxes and logistics.
Statutory emissions and fuel-quality standards also tightened, requiring costly upgrades to produce low-sulfur petrol and diesel. One parliamentary study estimated that bringing remaining Australian refineries up to 2027 environmental benchmarks would require cumulative investments approaching 1 billion Australian dollars over a decade. For operators, the projected return on that capital was often too low to justify the outlay, especially when competing with imported fuel that already met those standards.
Structural shifts in demand played a role as well. Over the past fifteen years, Australia's per-capita fuel consumption has declined due to efficiency gains, hybrid vehicles, and a rising fleet of electric cars. At the same time, regional crises-such as the 2020 pandemic-induced demand slump-pushed refining margins into negative territory, prompting BP Australia to accelerate the Kwinana closure and explore other cost-cutting options across its network.
Finally, the federal government's fuel-security strategy gradually shifted from propping up refineries to managing import-dependent supply chains. Instead of subsidizing marginal plants, policy focused on stockholding obligations, strategic reserves, and market-mechanism experiments aimed at stabilizing supplies. The result was a tacit acceptance that Australia would become a "refined-product-importing" nation, rather than a self-sufficient refiner.
The impact on Australia's fuel security
As local refining has faded, Australia's vulnerability to global supply shocks has increased. Events such as blockades or disruptions in the Strait of Hormuz, Middle East conflicts, or regional shipping incidents can now ripple through the country's fuel system more quickly than when most supply was internally produced. Parliamentary research from 2020-2022 estimated that, under normal conditions, Australia's combined commercial and strategic reserves could cover roughly 20-30 days of typical fuel demand, depending on the product and scenario.
To mitigate those risks, the federal government has introduced minimum stockholding requirements for refiners and importers, mandating that petrol refiners hold at least 24 days of typical demand and importers keep 27 days' worth, while diesel refiners must stock 20 days and diesel importers 32 days. These rules, enacted via the 2020 fuel-security framework, aim to smooth out temporary disruptions but do not replace the flexibility and resilience of a robust domestic refining backbone. Many energy-security advisers argue that Australia's position today is less "energy-dependent" and more "infrastructure-dependent," with supply chains concentrated in a handful of Asian ports and shipping lanes.
Future outlook: more imports or a refining comeback?
Looking ahead, the most likely scenario is that Australia will continue to rely on imported refined fuel, with only modest gains from the remaining domestic refineries. However, there are several plausible pathways that could alter this trajectory:
- Further consolidation or expansion of the Geelong and Lytton plants, supported by government incentives or risk-sharing mechanisms, could modestly lift self-sufficiency for key products such as diesel and aviation fuel.
- Tightening global refining margins or geopolitical shocks that make imported fuel less reliable might prompt a reassessment of Australia's long-term refining policy, potentially leading to renewed investment or public-private partnerships.
- Alternative strategies, such as accelerating the rollout of electric vehicles and hydrogen-powered transport, could reduce liquid-fuel demand enough that even a shrunken domestic refining sector becomes proportionally more important, despite absolute volumes being lower.
Energy-policy analysts stress that the question is not so much "when did Australia stop refining oil?" but "what kind of energy-security architecture will accompany a permanently imported-fuel regime?" That framing underscores why understanding the timing and causes of refinery closures matters for everything from fuel-price stability to national-security planning in an era of intensifying climate and geopolitical risk.
What are the most common questions about Australias Refinery Decline The Timeline And Impact?
Is Australia still refining any oil today?
Yes, but at a significantly reduced level. As of 2023 and continuing into 2026, the Geelong refinery and the Lytton refinery remain Australia's only active crude-oil processors, jointly producing petrol, diesel, and some aviation fuel. However, their combined output is insufficient to meet total domestic demand, so Australia still imports the majority of its refined products from overseas refineries, mostly in Asia. Various government-backed modernization and expansion plans, such as the National Australian Refining Project, aim to increase the Geelong refinery's throughput but do not alter the fundamental reality of import-dominated markets.
What percentage of Australia's fuel is now imported?
Analysts and industry officials estimate that around 90 percent of the fuel used in cars, trucks, ships, and aircraft in Australia is now imported refined products, rather than produced domestically. This means that even though the country still refines some crude oil, the bulk of what fills Australian petrol tanks comes from refineries in South Korea, Japan, Singapore, and China. Some energy-security experts note that this figure has climbed by roughly 30-40 percentage points since the early-2010s, as the Kurnell, Bulwer Island, Kwinana, Clyde, and Altona closures came online.
Could Australia start refining oil again?
Restoring large-scale oil-refining capacity would be possible in theory, but it is economically and politically challenging. The Australian parliament's energy-policy analyses suggest that building or reopening a modern refinery would require at least several billion dollars in capital, long lead times, and substantial regulatory approval. Recent policy debates have centered instead on upgrading existing plants, such as the proposed transformation of the Geelong refinery into a higher-throughput facility, rather than on reviving plants that have been dismantled or converted into import terminals. Short-term efforts focus more on strengthening fuel-security mechanisms-reserves, stockholding obligations, and geo-strategic planning-than on rebuilding domestic refining capacity to pre-closure levels.
What does it mean for everyday Australian motorists?
For most Australian drivers, the end of broad domestic oil refining translates into greater exposure to global fuel-price swings and regional disruptions, even if the effect is often muted by taxes, reserves, and market regulation. When Asian refining margins tighten or shipping costs spike, the cost of petrol and diesel at the bowser can rise more quickly than in the past, since the majority of the pumped product is imported rather than produced locally. However, mandated stockholding and strategic reserves are designed to dampen short-term crises, so the immediate impact on individual motorists is usually less dramatic than it might otherwise be. Over the longer term, the shift supports political arguments for both expanding domestic refining capacity and accelerating the transition to electric and alternative-fuel transport.