WTI settled at $100.05 as the IEA said August drained 95 million barrels
Front-month WTI rose 9.4% to $100.05 in the week ended September 11; the IEA said global oil inventories have fallen 507 million barrels since the start of the war.
The International Energy Agency said Friday that August took another 95 million barrels out of observed global tanks, a 3.1 million barrel-a-day draw, and that more than 10 million barrels a day of Gulf output remained shut in. OECD commercial tanks actually rose 23 million barrels that month. Non-OECD stocks fell 52 million barrels, led by China, and oil on the water dropped 65 million barrels as tanker traffic out of the Middle East came under attack. The drain is elsewhere, and it is products as much as crude.
Since the start of the war the IEA has now counted 507 million barrels of inventory gone, equal to 2.8 million barrels a day. Supply is falling faster than demand: the agency put 2026 production at 100.7 million barrels a day, down 5.7 million from a year earlier, and 2026 demand down 2.5 million barrels a day. The barrels that filled the gap came out of storage. Front-month WTI still settled Friday at $100.05 a barrel, up 9.4% from $91.48 a week earlier, after giving back $2.43 in the session. Brent settled at $104.61, up 8.7% on the week. Reuters said Friday's closes were the first weekly finishes above $100 in nearly four months.
A $6 Thursday, then a quieter Friday
The prompt barrel did the loud work in the middle of the week. Brent settled at $101.21 on Wednesday, September 9, after Reuters tied the move through $100 to an escalation of U.S.-Iran strikes. North Sea Dated, the physical benchmark, printed $113.48 that day, the IEA said, against an August average of $91.00. On Thursday both futures contracts pushed further: Brent settled at $107.63, up 6.3%, and WTI at $102.48, up 6.7%. Reuters tied that session to intensified tanker attacks and supply-disruption fear.
OPEC+ had already held still. On Sunday, September 6, Saudi Arabia, Russia, Iraq, Kuwait, Kazakhstan, Algeria, and Oman said they would keep September's required production in place for October and meet again on October 4. In a market missing more than 10 million Gulf barrels a day, an unchanged quota is not a supply event.
Friday was the fade, not the reversal. Brent dropped $3.02.
WTI spiked to $102.48 Thursday, then faded to $100.05
- WTI · $100
- Brent · $105
Saudi Arabia's energy ministry said the same day it had shut the East-West crude pipeline as a precaution after drone strikes a day earlier. The IEA, publishing into that session, said ICE Brent was around $105 at the time of writing, $21 above the start of August and 45% above pre-war levels, with backwardation (prompt barrels costing more than later ones) at extreme levels. Refinery runs peaked at 81.4 million barrels a day in August, still 4.2 million below a year earlier.
The U.S. Energy Information Administration's September Short-Term Energy Outlook, completed on September 3 and released Wednesday, still had Brent averaging about $90 in the second half of 2026. Friday's $104.61 close sits above that forecast. The next STEO is October 6.
U.S. crude tanks sat on the five-year average
The tightness is not in U.S. crude tanks. The EIA's Weekly Petroleum Status Report, out Thursday for the week ended September 4, showed commercial crude inventories down 0.4 million barrels to 424.1 million, matching the five-year average. Distillate stocks rose 2.1 million barrels to 106.3 million and remain 13% below that average. Gasoline rose 1.3 million barrels and is 5% light.
Refiners are still running the system hard: crude inputs averaged 17.5 million barrels a day over the four weeks through September 4, at 97.6% of capacity. The EIA's Wednesday outlook, written before this week's $100 prints, already had U.S. distillate inventories falling below 100 million barrels in September and staying under the five-year low through much of 2027, with global middle-distillate output still below last year. A 2.1 million-barrel weekly rebuild does not refill that hole.
Near-month oil funds tracked; the energy-stock fund did not
The funds that hold the barrel captured the week. United States Oil Fund USO, a $2.08 billion pool of near-term WTI futures, rose 9.1%. Invesco's DB Oil Fund DBO, a WTI futures fund, rose 9.1%. ProShares' K-1-free crude fund OILK rose only 4.3%. That fund tracks three WTI contract tenors at equal weight, rebalanced in March and September, so a front-month spike is exactly the move it is built not to match in full. Year to date OILK is up 73.3%, against 74.2% for WTI itself. USO is not that close: it is up 124.0% year to date against 74.2% for the front-month contract. The fund sells the nearby WTI contract each month and buys the next. In backwardation, which the IEA said Friday is extreme, that monthly roll adds to the price gain the front-month series prints.
Front-month WTI is the October contract. USO's largest line is the November 2026 WTI future; DBO's is the October 20, 2026 WTI contract. The near-month gas fund UNG holds the October 2026 contract as its largest line.
Producer equities are a different claim. State Street's $42.6 billion fund of S&P 500 energy companies XLE rose 1.7%, to $65.14, trailing WTI by 7.7 percentage points.
The oil fund tracked Thursday; XLE sat it out
- USO · 154.9
- OILK · 56.88
- XLE · 65.14
Fidelity's broader U.S. energy index fund FENY rose 1.6%. Inside XLE, which holds 21 stocks and has 20.1% in Exxon Mobil and 15.2% in Chevron, the week's math was concentrated and mixed. Exxon rose 4.1% and accounted for about half the fund's gain. Valero, a refiner sitting on that distillate shortage, rose 5.3%. Baker Hughes fell 7.0% and SLB fell 2.5%. The oilfield-services fund XES finished down 0.4%. Global X's midstream fund MLPX fell 0.6%.
The usual energy holding in a U.S. stock portfolio does not own oil. It owns the companies that pump, refine, and move it, at 0.08% a year in XLE. USO files a K-1. Those are not interchangeable wrappers for a 9% week in the prompt barrel.
On the week, front-month WTI did the work. The energy-stock fund, and the balanced crude fund, did not.
Natural gas injected 40 Bcf and the contract fell
U.S. natural gas is not in that oil market. Front-month NYMEX gas settled at $2.831 per MMBtu on Friday, down 4.8% from $2.975 a week earlier. UNG fell 3.7%.
The EIA reported Thursday a 40 Bcf injection for the week ended September 4, leaving working gas at 3,254 Bcf. The September STEO has inventories on track for 3,969 Bcf at the end of October, 5% above the five-year average, with Permian and Haynesville production still rising. Henry Hub is a storage-and-production story heading into winter. Brent is an inventory-draw-and-shut-in story. They do not hedge each other this year.
The IEA has now pushed a full recovery of Middle East supply into 2027. Demand is shrinking, and supply is shrinking more. Until that gap closes, the prompt barrel is a claim on remaining tanks, and the fund that matched this week was the one that held the contract.
Frequently asked
Why did oil jump above $100?
Escalating U.S.-Iran strikes and tanker attacks, with more than 10 million barrels a day of Gulf output shut in, drove the move, and Thursday did most of the week's work.
Why did USO beat front-month WTI so badly this year?
USO sells the nearby WTI contract each month and buys the next, and in the current extreme backwardation that monthly roll adds to the front-month price gain.
Why didn't energy stocks keep up?
The S&P 500 energy fund rose 1.7%, trailing WTI by 7.7 points, because it owns the companies that pump, refine and move oil rather than the barrel itself.
Are U.S. oil inventories tight?
U.S. commercial crude sat at 424.1 million barrels, matching the five-year average, though distillate stocks remain 13% below it.