WTI CRUDE

Steinbeck said:
And a refinery set up for that also handles lighter oil just fine. thanks for playing.
Click to expand...


AI response:

Yes, a refinery designed for Brent crude can also process lighter oils such as West Texas Intermediate (WTI). However, the efficiency of the operation may be compromised. Refineries are typically optimized for specific types of crude oil, and switching to a different type can lead to operational challenges.

Efficiency Considerations​

When a refinery that is set up for heavier crude like Brent runs lighter oil, it may not utilize its equipment effectively. This can result in:

  • Underutilization of Upgrading Units: Equipment designed for breaking down heavier molecules may not operate at optimal capacity with lighter crude.
  • Operational Bottlenecks: The higher volume of lighter products can overwhelm certain parts of the refining system, reducing overall throughput.

​

 
Mahmoud Ahmadinejad said:
AI response:

Yes, a refinery designed for Brent crude can also process lighter oils such as West Texas Intermediate (WTI). However, the efficiency of the operation may be compromised. Refineries are typically optimized for specific types of crude oil, and switching to a different type can lead to operational challenges.

Efficiency Considerations​

When a refinery that is set up for heavier crude like Brent runs lighter oil, it may not utilize its equipment effectively. This can result in:

  • Underutilization of Upgrading Units: Equipment designed for breaking down heavier molecules may not operate at optimal capacity with lighter crude.
  • Operational Bottlenecks: The higher volume of lighter products can overwhelm certain parts of the refining system, reducing overall throughput.

​

Click to expand...

And of course it says nothing about Gulf Coast refineries somehow not being able to process lighter oils. That's because they can indeed process any oil. Gulf Coast refineries are full refineries.
 
US-produced WTI crude oil cannot make up global demand for oil products.

WTI (West Texas Intermediate) is a specific grade of light, sweet crude oil produced in the United States, primarily from regions like the Permian Basin in Texas and surrounding areas.

It serves as the main benchmark for US oil pricing.

While not every barrel of US crude is labeled exactly "WTI," the vast majority of recent US production (especially tight oil from shale) is light sweet crude that trades as or very similarly to WTI. So, "US-produced WTI" essentially refers to total US crude oil field production.

Current production and demand figures (as of early 2026)
  • US crude oil production: Approximately 13.6 million barrels per day (b/d).
    • This is a record high level achieved in 2025 (13.586 million b/d) and is expected to remain around 13.5–13.6 million b/d in 2026.

      ycharts.com +2
  • Global oil demand (for refined products such as gasoline, diesel, jet fuel, heating oil, etc.): Roughly 105 million b/d (with some forecasts showing slight growth or minor contraction depending on economic and geopolitical factors, but the base level exceeds 105 million b/d).

    mckinsey.com +2
US production therefore represents only about 13% of global oil demand.

Even if every barrel of US WTI were refined into products and shipped worldwide, it would fall far short of meeting total consumption.

Why volume is the decisive factor: Oil products are made by refining crude oil. Global demand for those products requires roughly the same volume of crude input (refineries have modest gains/losses, but the scale is comparable). The world relies on a broad supply base:
  • Major producers include Saudi Arabia, Russia, Canada, Iraq, China, and others (OPEC+ alone accounts for a large share).
  • The US is the world’s largest single crude producer, but it is still only one piece of the puzzle.

    eia.gov
Other practical limitations include:
  • Refining mismatch: US refineries are optimized for a mix of light (domestic WTI) and heavy imported crudes. The US exports some light crude and imports heavier grades to balance its own product slate.
  • Logistics and markets: Crude must be transported, refined in facilities designed for specific grades, and distributed globally. US WTI alone cannot physically or economically replace supply from dozens of other countries.
  • Domestic vs. global: The US consumes about 20 million b/d of petroleum products but produces only ~13.6 million b/d of crude, so it already participates in international trade rather than being self-sufficient even for its own needs.
In short, US WTI production is substantial and has grown dramatically thanks to shale technology, making the US a top global supplier and net exporter of refined products. However, it is nowhere near enough—by volume or infrastructure—to single-handedly satisfy worldwide demand for oil products. Global oil markets remain interdependent.
 
Steinbeck said:
And of course it says nothing about Gulf Coast refineries somehow not being able to process lighter oils. That's because they can indeed process any oil. Gulf Coast refineries are full refineries.
Click to expand...


Gulf Coast refineries cannot supply European and Asian demands for oil products by processing and exporting American (U.S.-produced) crude oil.

businesstats.com
The U.S. Gulf Coast (primarily Texas and Louisiana, PADD 3) is the world’s premier refining export hub, with complex facilities optimized for high-value product yields and direct access to export terminals like the Houston Ship Channel. It accounts for roughly 55% of total U.S. refining capacity, or about 9.5–10 million barrels per day (b/d) out of the national total of ~18.1–18.4 million b/d as of early 2026. Utilization routinely runs at 92–97% (often above 95% recently), meaning the region processes and can produce roughly 9–10 million b/d of refined products when running flat out.

ycharts.com +3
Even if every barrel of that output were redirected exclusively to Europe and Asia (which is impossible—U.S. domestic product demand is ~20 million b/d, and exports serve many markets including Latin America), the volume is far too small to meet those regions’ needs. European and Asian product demand (context for 2025–2026)
  • Europe (OECD Europe): Petroleum product consumption is roughly 12–14 million b/d (gasoline, diesel, jet fuel, etc.).
  • Asia (Asia-Pacific, including China, India, Japan, South Korea, Southeast Asia): This is the dominant global demand center, with China alone at ~16–18 million b/d and total regional demand exceeding 40–45 million b/d.
  • Combined Europe + Asia: Easily 55+ million b/d of product demand.
U.S. Gulf Coast output represents only a small fraction of that—even before accounting for Europe’s and Asia’s own massive domestic refining capacity (global refining is ~103 million b/d, with Asia and Europe having large shares).

businesstats.com
Current U.S./Gulf Coast exports to those regionsU.S. total refined product exports have hit records recently (~6–7 million b/d overall in early 2026, with clean products like gasoline, diesel, and jet fuel around 3 million b/d in peak months), driven partly by Middle East supply disruptions. However:
  • Exports specifically to Europe: Diesel and other fuels have surged (e.g., ~414,000 b/d total fuels in March 2026; diesel to Europe more than doubled in some months to ~396,000 b/d).
  • Exports specifically to Asia: Smaller but growing (e.g., ~224,000 b/d in March 2026, with occasional spikes to hundreds of thousands b/d amid geopolitical shifts).
These are helpful supplements during shortages, but they are orders of magnitude below what would be needed to “supply” either region’s total demand or even their net import needs.

reuters.com +2
Processing “American oil” (U.S.-produced WTI/light sweet crude) adds further constraintsU.S. crude production is ~13.5–13.8 million b/d (record levels in 2025). Gulf Coast refineries have shifted toward more domestic light crude from the Permian and other shale plays since the 2010s, and some facilities have been reconfigured to run lighter slates. However:
  • Many Gulf Coast refineries are complex coking units optimized for heavier, sour crudes (historically from imports like Canada, Mexico, or Venezuela). Running only light sweet U.S. crude changes the product mix (typically more gasoline, less diesel/jet fuel) and can reduce overall yields or efficiency for the distillate-heavy slate that Europe and Asia often demand.
  • The U.S. as a whole still imports ~3–4 million b/d of crude to balance its refining slate, even with high domestic output. Gulf Coast refiners continue to import heavies for economic and operational reasons.
There is enough U.S. crude volume in theory to feed the Gulf Coast fully, but the refining configuration, logistics, and optimal product yields limit how much “pure American oil” processing can realistically be ramped up without major (and costly) changes.

eia.gov +1
Bottom line: Gulf Coast refineries are highly efficient exporters and have stepped up during global disruptions, but their total capacity (~10 million b/d) and actual export volumes to Europe/Asia (hundreds of thousands of b/d) cannot come close to meeting the continents’ combined demand of 55+ million b/d. The world’s oil product markets remain deeply interdependent, with Europe and Asia relying primarily on their own refineries plus supplies from the Middle East, Russia (where not sanctioned), and other producers. U.S. Gulf Coast exports play a valuable balancing role—but they are a supplement, not a substitute.
 
There are significant logistical (shipping and loading) barriers that would prevent U.S. Gulf Coast exports from realistically replacing the Persian Gulf’s usual crude oil export volumes, even if sufficient U.S. production and refining balance existed.

jensendavid.substack.com +1

The Persian Gulf (primarily Saudi Arabia, UAE, Iraq, Kuwait, and Iran via the Strait of Hormuz) historically exported roughly 15–21 million barrels per day (b/d) of crude and condensate in normal pre-2026 conditions—accounting for a huge share of global seaborne trade (often ~20+ million b/d through Hormuz in peak years). The 2026 Iran-related disruptions have slashed this dramatically (e.g., 13–14.5 million b/d offline), prompting a surge in U.S. exports, but the scale mismatch and shipping constraints remain decisive.

finance.yahoo.com +1

U.S. crude exports (almost entirely from the Gulf Coast) have hit record levels of ~4.9–5.2 million b/d in April/May 2026 amid the crisis—up from typical 3.5–4.5 million b/d—but analysts describe this as already testing or nearing the practical ceiling (monthly sustainable ~5–5.5 million b/d, with weekly peaks possibly to 6–6.5 million b/d).

Total Gulf Coast nameplate export capacity is estimated at ~7.1 million b/d across terminals, but real-world throughput is constrained far below what would be needed to offset Persian Gulf volumes.

energynewsbeat.com +2

Key logistical shipping and loading barriers
  1. Limited terminal and VLCC loading infrastructure: The U.S. Gulf Coast relies on a handful of key terminals (e.g., Corpus Christi’s Ingleside Energy Center and South Texas Gateway, Houston-area facilities, Energy Transfer’s Nederland, and Louisiana’s LOOP offshore port). Only LOOP can fully load Very Large Crude Carriers (VLCCs, ~2 million barrels each) directly in deep water. Most onshore terminals (Corpus Christi, Houston Ship Channel) have channel depths of ~45–54 feet after recent dredging—insufficient for a fully laden VLCC (requires ~72 feet).
    • Result: Partial loading at the dock (often 1–1.2 million barrels), followed by reverse lightering offshore in the Gulf using smaller tankers (Aframax/Suezmax) to top up VLCCs. This process adds days per cargo, requires extra vessels, and creates scheduling bottlenecks.
    • Direct VLCC-capable berths are few (e.g., only ~500,000 b/d effective direct VLCC loading in Corpus Christi despite higher overall port volumes). Docks are already pushing limits with the current surge. Proposed offshore deepwater terminals (for full VLCC loads) have faced delays or stalls.

      energypolicy.columbia.edu +2
  2. Tanker fleet availability and scheduling constraints: The current crisis has already tightened the global tanker market: VLCC availability along the U.S. Gulf Coast dropped ~41% in recent weeks (halved to ~10 vessels at times), with Suezmax and Aframax also scarce. An “armada” of 60–80+ empty VLCCs has been steaming toward the Gulf, but loading them takes time—each VLCC requires 1–3 days to load, plus transit and berthing queues.
    • At current rates, filling dozens of VLCCs could take weeks to a month, creating backlogs. Incremental barrels beyond ~5 million b/d become exponentially more expensive due to higher freight and logistics.
    • Persian Gulf terminals (e.g., Ras Tanura, Fujairah) were designed for massive, simultaneous VLCC loadings with minimal lightering. U.S. operations lack that scale.

      reuters.com +2

  3. Longer transit times and route inefficiencies:
    • Persian Gulf to Asia (main destination for ~89% of Hormuz flows): Typically 25–30 days (or up to a month).
    • U.S. Gulf Coast to Asia: Substantially longer—~40–50+ days (via Panama Canal or around South America/Cape routes). This requires more tankers in circulation to deliver the same daily volume to buyers, inflating costs and fleet demand.
    • To Europe: U.S. routes are competitive or shorter in some cases, but Asia drives the volume mismatch. Higher freight rates (already surging on U.S. Gulf–Asia routes) and longer voyages reduce economic viability versus Persian Gulf supply.

  4. Additional operational frictions:
    • Port/channel congestion: Surge loadings strain docks, channels, and support infrastructure (pilots, tugs, storage).
    • Pipeline feed to terminals: While not purely shipping, Permian-to-Gulf pipelines are often near capacity, limiting sustained high export rates.
    • Weather and seasonal risks: Gulf hurricanes can disrupt operations for days/weeks.
    • Cost escalation: Every extra barrel beyond current levels incurs higher per-barrel freight/logistics penalties; VLCC rates have rallied sharply on the demand spike.

      finance.yahoo.com +1
In practice, U.S. Gulf Coast exports have proven highly responsive during the 2026 disruptions (stepping up to fill part of the gap), but they function as a supplement, not a replacement.

Scaling to Persian Gulf volumes (~3–4× current U.S. export rates) would require years of new infrastructure, a vastly larger dedicated tanker fleet, and fundamentally different port designs—none of which exist or could be built quickly. Global oil shipping remains optimized around the Persian Gulf’s massive, efficient export hubs.
 
Mahmoud Ahmadinejad said:
There are significant logistical (shipping and loading) barriers that would prevent U.S. Gulf Coast exports from realistically replacing the Persian Gulf’s usual crude oil export volumes, even if sufficient U.S. production and refining balance existed.

jensendavid.substack.com +1

The Persian Gulf (primarily Saudi Arabia, UAE, Iraq, Kuwait, and Iran via the Strait of Hormuz) historically exported roughly 15–21 million barrels per day (b/d) of crude and condensate in normal pre-2026 conditions—accounting for a huge share of global seaborne trade (often ~20+ million b/d through Hormuz in peak years). The 2026 Iran-related disruptions have slashed this dramatically (e.g., 13–14.5 million b/d offline), prompting a surge in U.S. exports, but the scale mismatch and shipping constraints remain decisive.

finance.yahoo.com +1

U.S. crude exports (almost entirely from the Gulf Coast) have hit record levels of ~4.9–5.2 million b/d in April/May 2026 amid the crisis—up from typical 3.5–4.5 million b/d—but analysts describe this as already testing or nearing the practical ceiling (monthly sustainable ~5–5.5 million b/d, with weekly peaks possibly to 6–6.5 million b/d).

Total Gulf Coast nameplate export capacity is estimated at ~7.1 million b/d across terminals, but real-world throughput is constrained far below what would be needed to offset Persian Gulf volumes.

energynewsbeat.com +2

Key logistical shipping and loading barriers
  1. Limited terminal and VLCC loading infrastructure: The U.S. Gulf Coast relies on a handful of key terminals (e.g., Corpus Christi’s Ingleside Energy Center and South Texas Gateway, Houston-area facilities, Energy Transfer’s Nederland, and Louisiana’s LOOP offshore port). Only LOOP can fully load Very Large Crude Carriers (VLCCs, ~2 million barrels each) directly in deep water. Most onshore terminals (Corpus Christi, Houston Ship Channel) have channel depths of ~45–54 feet after recent dredging—insufficient for a fully laden VLCC (requires ~72 feet).
    • Result: Partial loading at the dock (often 1–1.2 million barrels), followed by reverse lightering offshore in the Gulf using smaller tankers (Aframax/Suezmax) to top up VLCCs. This process adds days per cargo, requires extra vessels, and creates scheduling bottlenecks.
    • Direct VLCC-capable berths are few (e.g., only ~500,000 b/d effective direct VLCC loading in Corpus Christi despite higher overall port volumes). Docks are already pushing limits with the current surge. Proposed offshore deepwater terminals (for full VLCC loads) have faced delays or stalls.

      energypolicy.columbia.edu +2
  2. Tanker fleet availability and scheduling constraints: The current crisis has already tightened the global tanker market: VLCC availability along the U.S. Gulf Coast dropped ~41% in recent weeks (halved to ~10 vessels at times), with Suezmax and Aframax also scarce. An “armada” of 60–80+ empty VLCCs has been steaming toward the Gulf, but loading them takes time—each VLCC requires 1–3 days to load, plus transit and berthing queues.
    • At current rates, filling dozens of VLCCs could take weeks to a month, creating backlogs. Incremental barrels beyond ~5 million b/d become exponentially more expensive due to higher freight and logistics.
    • Persian Gulf terminals (e.g., Ras Tanura, Fujairah) were designed for massive, simultaneous VLCC loadings with minimal lightering. U.S. operations lack that scale.

      reuters.com +2
  3. Longer transit times and route inefficiencies:
    • Persian Gulf to Asia (main destination for ~89% of Hormuz flows): Typically 25–30 days (or up to a month).
    • U.S. Gulf Coast to Asia: Substantially longer—~40–50+ days (via Panama Canal or around South America/Cape routes). This requires more tankers in circulation to deliver the same daily volume to buyers, inflating costs and fleet demand.
    • To Europe: U.S. routes are competitive or shorter in some cases, but Asia drives the volume mismatch. Higher freight rates (already surging on U.S. Gulf–Asia routes) and longer voyages reduce economic viability versus Persian Gulf supply.
  4. Additional operational frictions:
    • Port/channel congestion: Surge loadings strain docks, channels, and support infrastructure (pilots, tugs, storage).
    • Pipeline feed to terminals: While not purely shipping, Permian-to-Gulf pipelines are often near capacity, limiting sustained high export rates.
    • Weather and seasonal risks: Gulf hurricanes can disrupt operations for days/weeks.
    • Cost escalation: Every extra barrel beyond current levels incurs higher per-barrel freight/logistics penalties; VLCC rates have rallied sharply on the demand spike.

      finance.yahoo.com +1
In practice, U.S. Gulf Coast exports have proven highly responsive during the 2026 disruptions (stepping up to fill part of the gap), but they function as a supplement, not a replacement.

Scaling to Persian Gulf volumes (~3–4× current U.S. export rates) would require years of new infrastructure, a vastly larger dedicated tanker fleet, and fundamentally different port designs—none of which exist or could be built quickly. Global oil shipping remains optimized around the Persian Gulf’s massive, efficient export hubs.
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It is complete fantasy.
 
Im just going to assume what all the players say is true.

Saudi Arabia says they have a pipeline that brings some portion of their production to the red sea.

UAE says they have some portion of their production going to Oman by the Habshah pipeline.

Oman is on the other side of Hormuz and says it is not affected

Iran says their tankers are piercing thru the blockade and that they are sending oil to china via train.

Given that so much oil is getting out thru various means why would prices go that high?
 
tsuke11 said:
Im just going to assume what all the players say is true.

Saudi Arabia says they have a pipeline that brings some portion of their production to the red sea.

UAE says they have some portion of their production going to Oman by the Habshah pipeline.

Oman is on the other side of Hormuz and says it is not affected

Iran says their tankers are piercing thru the blockade and that they are sending oil to china via train.

Given that so much oil is getting out thru various means why would prices go that high?
Click to expand...


Easily answered with a simple search of the Internet.

Do you lack the ability, or the will to discover the facts?
 
Mahmoud Ahmadinejad said:
There are significant logistical (shipping and loading) barriers that would prevent U.S. Gulf Coast exports from realistically replacing the Persian Gulf’s usual crude oil export volumes, even if sufficient U.S. production and refining balance existed.
Click to expand...

lol unlike the massively open logistics of passing through the Hormuz Straits, the Bosphorus, the Suez Canal, and the Malacca choke points? lol yeah sure thing ... Try looking at a map once in a while.
 
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