There is no universal, one-for-one substitute for Russian oil. A refinery’s options depend on the crude it can process, the products it needs to make, available supply and transport, and the sanctions rules that apply to the cargo and its destination. For buyers, the first distinction is whether they need replacement crude for a refinery or replacement refined products, such as diesel.
Crude oil and refined products are different replacement problems
A refinery replacing Russian crude needs a feedstock that can be processed safely and efficiently in its particular plant. An energy buyer replacing Russian diesel may instead buy finished diesel from another refinery, without sourcing crude itself. These routes have different supply chains and compliance questions: the origin of a crude cargo is not the same as the origin and eligibility of a refined product.
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The International Energy Agency (IEA), in its report dated 11 September 2025, described Middle East Gulf countries, the United States, Türkiye and India as sources that replaced lost Russian diesel volumes to varying degrees in the period it analyzed. The Middle East was the largest supplier in that period. These are historical trade-flow observations, not a current ranking of suppliers or a guarantee of future availability.
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Which crude grades have been used as alternatives?
For Europe’s adjustment after Russian crude flows fell in 2022, the IEA identified the following examples. They are observed alternatives, not recommendations for every refinery.
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| Grade | Role identified by the IEA | What a buyer should not assume |
|---|---|---|
| CPC | Medium-sour alternative in the European replacement slate | That the grade will suit a particular refinery without a compatibility assessment |
| Basrah Medium | Medium-sour alternative in the European replacement slate | That it is interchangeable with Russian crude or with CPC at a specific plant |
| Johan Sverdrup | Domestic European grade used in the adjustment | That regional origin alone establishes adequate volume, timing or technical suitability |
Crude names do not establish equivalence. The U.S. Energy Information Administration (EIA) explains that feeding lighter crude to a refinery configured for heavier crude can create operational inefficiencies. Blending different crudes or investing in additional processing capacity may be options, but each has operating and economic trade-offs. The IEA’s examples do not provide refinery-by-refinery compatibility data.
How to screen a crude substitute for a refinery
A sound shortlist starts with the plant and the product slate, not with a grade’s name or an assumption that a nearby source is automatically suitable. Refinery engineers, crude procurement teams and compliance staff need to assess the same cargo from different angles.
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- Refinery fit: Compare the candidate crude’s properties with the plant’s configuration and operating limits. Establish whether the refinery is optimized for heavier or lighter inputs and whether blending or process changes would be required.
- Product output and operations: Assess how the feedstock could affect product yields, efficiency and utilization, and whether debottlenecking or new equipment would be needed. The available sources do not quantify those effects for the named grades.
- Supply and delivery: Confirm deliverable volume, route and timing, rather than relying on a grade’s presence in a historical trade-flow analysis. Longer routes and competition for replacement supplies can matter to the decision.
- Commercial terms: Compare delivered offers and contract conditions for the specific cargoes under consideration. No current delivered-price comparison is established by the cited material, so it cannot support a cost ranking of CPC, Basrah Medium and Johan Sverdrup.
- Origin and eligibility: Document the crude’s origin and any subsequent processing, then check the rules for the buyer, seller, services and destination. A technically suitable feedstock can still raise a compliance problem.
What the historical diesel flows show
IEA figures illustrate how replacement-product sourcing differed from crude substitution. The periods and regions matter: these statistics are historical observations from its 11 September 2025 report, not October 2026 market data.
| IEA figure | Period and scope | How to interpret it |
|---|---|---|
| Close to 850 kb/d | Average extra-regional diesel imports by the EU, UK and Norway over 3Q23–2Q25 | Combined imports across the named markets; not a figure for the EU alone |
| 340 kb/d | Middle East diesel supply to the EU, UK and Norway, as reported in the 2025 analysis | A regional supply figure for those markets, not a current offer or forecast |
| 160 kb/d | Average European diesel imports from India and Türkiye during 1H25 | A combined historical flow, not a statement that all such product is eligible for every destination |
The IEA also reported that India’s Jamnagar complex sourced 430 kb/d of Russian crude—approximately one-third of its crude—since the start of 2023, in the period covered by its analysis. That is historical reporting, not a current sourcing figure. It is relevant because crude origin can affect the eligibility of products made at a third-country refinery for particular importing markets.
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EU rules can affect products refined outside Russia
For EU-bound refined products, the European Commission advises enhanced due diligence when a refinery processes Russian crude. Its consolidated sanctions FAQ explains: “Oil is a fungible material that cannot be physically segregated once mixed.” The guidance therefore does not accept aggregate mass balancing alone as proof that a product is non-Russian in origin.
The Commission’s guidance describes evidence and conditions involving documented separation of production lines, or evidence that the relevant line did not receive or process Russian crude in the 60 days before the bill of lading date. Buyers should verify the documentation for the particular cargo and destination against the operative law. This guidance concerns EU imports; it should not be treated as a global sanctions rule.
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The Commission’s sanctions summary states that the EU prohibits imports of Russian seaborne crude and refined petroleum products from Russia. Its page, updated 23 July 2026, lists a US$47.6-per-barrel Russian seaborne crude price cap following the 18th sanctions package and describes changes to the adjustment mechanism. These are date-specific details, not a substitute for checking the current rule. Before a transaction, verify the applicable requirements for the parties, cargo, services and destination.
How to make the sourcing decision
- Define what must be replaced. Specify whether the requirement is crude feedstock for a refinery or a finished product such as diesel, along with the required volume and delivery window.
- Screen technical fit if buying crude. Have the receiving refinery assess candidate properties against its configuration, operating limits and target product slate. Do not treat the IEA’s European examples as drop-in replacements.
- Build a deliverable shortlist. Check available volume, transport route, arrival timing and commercial terms for the actual cargoes—not just broad regional supply trends.
- Trace origin and processing. For products refined in a third country, establish the crude origins and relevant production-line history needed for the destination’s rules.
- Confirm compliance before contracting or shipment. Obtain cargo-specific documentation and check current legislation and official guidance with qualified compliance advisers. Trade-flow statistics do not establish legal eligibility.
What European policy milestones do—and do not—tell buyers
The European Commission’s REPowerEU roadmap of 6 May 2025 called on EU countries to prepare national plans by the end of 2025 describing how they would contribute to phasing out Russian oil, gas and nuclear energy imports. That was a policy-planning milestone for member states, not a sourcing instruction or a substitute for assessing an individual cargo.
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