Latest / The Commodities Economy with Fexingo: Oil, Gold, Wheat, and Raw Material Markets / How Saudi Crude Output Cuts Reshape Global Oil Logistics
Transcript
- Lucas: So Brent crude closed tonight at eighty-four thirty, WTI at seventy-eight thirty-eight — that six-dollar gap is the widest we've seen since early April. And I think the story everyone's telling is geopolitical — Strait of Hormuz, Iran tensions, all that. But there's a quieter, almost mechanical reason this spread is persisting, and it has to do with exactly what kind of crude is moving where. Luna: You mean the quality differential. Heavy sour versus light sweet. That's been a theme for years, but something's different now. Lucas: Right. And it's not just the grade — it's the physical logistics of how barrels get from point A to point B. Saudi Arabia announced last week it's maintaining its extra one-million-barrel-per-day voluntary cut through September. That's on top of the broader opec plus cuts. So roughly two million barrels a day of medium to heavy sour crude are staying in the ground. Luna: And that's the stuff that Asian refiners are built for. Japan, South Korea, India — their complex refineries are optimised for that heavier, higher-sulfur crude. Lucas: Exactly. So they're having to bid up competing grades from Iraq, Kuwait, even Russia's Urals blend. That's lifting the entire Brent complex because Brent is the benchmark for those seaborne, non us crudes. Meanwhile, WTI — which is light sweet crude from the Permian and the Bakken — is staying relatively cheaper because there's plenty of it. US production hit thirteen point four million barrels a day in June, according to the EIA. Luna: So you've got this bifurcation where Brent is being pulled higher by Asian demand for heavier grades, and WTI is being held down by ample domestic supply. But that should mean US exports surge, right? If WTI is cheap relative to Brent, American crude becomes attractive to foreign buyers. Lucas: And that's exactly what's happening. US crude exports hit a record two point one million barrels per day to Europe in June. That's up from about one point six million a year ago. European refineries are configured for medium-sour crude too, but they can blend light sweet WTI with heavier grades to get the right mix. So they're taking advantage of the discount. Luna: But that creates a logistical puzzle. You've got tankers loading in the Gulf Coast, sailing across the Atlantic, offloading in Rotterdam or Trieste. That's a ten-to-fourteen-day voyage. Meanwhile, the Saudis are sending their barrels east, around the Cape of Good Hope or through the Suez Canal to Asia. The whole global tanker map is shifting. Lucas: And the economics of those routes matter. The freight rates for Very Large Crude Carriers on the Middle East-to-Asia route have jumped about fifteen percent in the last month because demand for those bigger ships is up. On the us to europe route, you're seeing more Suezmax vessels — smaller than VLCCs, but they can fit through the expanded Panama Canal or just do the Atlantic crossing efficiently. Luna: So the spread isn't just about geopolitics or even just about grade — it's about who's willing to pay for the transport. And right now, Asian refiners are paying a premium because they need the heavy stuff that's being withheld. Lucas: That's the core of it. But here's where it gets interesting for traders. The futures curve for WTI is in contango right now — meaning near-term contracts are cheaper than later-dated ones. That's a signal that the market sees ample supply today and expects prices to rise later. Brent, by contrast, is in backwardation — near-term contracts are more expensive — which suggests current supply is tight. Luna: So you can actually trade this. Buy WTI now, store it, sell it forward at a higher price. But only if you have storage capacity. Lucas: Right. And storage is getting tight. Cushing, Oklahoma — the main delivery point for WTI futures — inventories fell by one point two million barrels last week, to thirty-two million barrels. That's about ten percent below the five-year average. So the contango isn't as wide as it could be because storage isn't as available as it was in 2020. Luna: But if you're a refiner on the Gulf Coast, you're probably running full tilt. Margins are decent — crack spreads for gasoline are around twenty-two dollars a barrel, which isn't spectacular but it's not bad. And you've got cheap feedstock in WTI. Lucas: Meanwhile, European refiners are paying more for Brent-linked crude, but they can pass some of that on to consumers. Diesel demand in Europe is actually up year-over-year — partly because of post-pandemic industrial recovery, partly because natural gas prices are still elevated relative to history, so some industrial users are switching to diesel for heating. Luna: So we've got this three-way dance: Saudi cuts tighten heavy crude supply, Asian refiners bid up Brent, US exporters fill the Atlantic Basin gap with cheap light sweet, and the futures curves reflect different regional balances. That's a lot of moving parts. Lucas: And the question is how long it lasts. The Saudi cuts are voluntary, so they could reverse in October. But if opec plus decides to unwind production cuts gradually, you could see more heavy crude coming back online, which would narrow the brent wti spread. On the other hand, if US shale production growth slows — and there are signs that Permian well productivity is plateauing — then WTI could start to tighten too. Luna: What are the signs? I've seen some EIA data suggesting new-well productivity per rig in the Permian has dropped about five percent from its peak in 2023. Lucas: Yeah, that's exactly right. The sweet spots are getting drilled out. Companies like Exxon and Chevron are still adding rigs, but the incremental barrels per rig are declining. So US production growth might slow from about three hundred thousand barrels per day annually to maybe half that. If that happens, WTI could start to converge with Brent — not because Brent falls, but because WTI rises. Luna: That would be a bet on the spread narrowing from the WTI side. Some hedge funds are already positioning for that — I saw that managed money net long positions in WTI futures increased by about twelve thousand contracts last week. Lucas: It makes sense if you think the physical dynamics are temporary. But if Saudi Arabia extends cuts into Q4, which some OPEC watchers think is possible, then the spread could widen further. Brent could test eighty-six or eighty-seven while WTI stays around seventy-eight. Luna: So the range of outcomes is pretty wide. What's your base case? Lucas: I think the spread stays wide through August, maybe September, then begins to narrow as we head into fall. The Saudis have signaled they want to support prices ahead of a possible production increase later in the year — they have budget breakevens around eighty-five dollars Brent — so they'll keep cuts in place until they see inventories draw down enough. But US exports will keep a lid on WTI, so I don't see WTI breaking above eighty-two anytime soon. Luna: That's a pretty specific call. For listeners who trade this stuff, what's the one thing to watch? Lucas: The weekly EIA inventory report for Cushing. If you see Cushing stocks dropping below thirty million barrels, that contango could flip to backwardation, and the whole trade changes. Also watch the Saudi OSP — the Official Selling Price — for Asia. If they cut that for August loading, it would signal they're worried about losing market share, and the spread could compress. Luna: So the devil is in the barrels — literally in the tanks and on the tankers. I love this level of granularity because it's so easy to just say 'geopolitics' and move on. Lucas: Honestly, if walking through the economy with us has made something click — like the physical mechanics of oil flows — that's the kind of insight we try to deliver every episode. If it was worth a coffee to you, that's the link: buy me a coffee dot com slash fexingo. No pressure, just if you find yourself referring to the brent wti spread at dinner. Luna: Yeah, it's a small way to keep the show ad-free and focused on the actual market structure rather than sponsored narratives. Lucas: Anyway — back to the crude map. One other thing I'm watching is the impact on refined products. If WTI stays cheap relative to Brent, US Gulf Coast refiners have a cost advantage. That means more gasoline and diesel exports to Latin America and Europe. Already, US gasoline exports hit one million barrels per day in May, highest since 2019. That's putting downward pressure on European gasoline margins. Luna: So the cheap WTI isn't just a crude story — it ripples through the entire product chain. European refiners are squeezed on both ends: higher crude input costs and cheaper product imports from the US. Lucas: Exactly. And that's why some European refineries are considering run cuts. Petroineos in Scotland announced last month it's evaluating a shutdown of its Grangemouth refinery by 2027. That's a big deal — it's one of only six refineries left in the UK. Luna: So the structural shift in crude flows is accelerating a structural shift in refining capacity. The winners are US Gulf Coast refiners and maybe some Asian complex refineries that can process the heavy stuff. Losers are simple refineries in Europe and anywhere else that relies on imported Brent-linked crude. Lucas: And the tanker market benefits either way — more miles traveled per barrel as crude moves from the Permian to Rotterdam, and from the Middle East to Singapore. It's a fascinating real-time reconfiguration of the global oil map, driven not by a single political event but by a sustained production decision in Riyadh and a productivity plateau in West Texas. Luna: Which is the kind of story you only get if you look at the actual barrels, not just the headlines. Lucas: Exactly. And that's what we'll keep doing.