Brent closed Friday at $109.86 and the futures market prices $100 oil into spring. Gas costs about nine times more in Europe and Asia than at Henry Hub, the U.S. benchmark, coal demand is headed for a record, and five of the world’s eight oil chokepoints have trouble. Here is what it means for your wallet, and why energy security starts at home.

By Stuart Turley, host of the Energy News Beat podcast  •  Published Oct. 18, 2026  •  Data Oct. 16 settlements; AAA as of 8:25 a.m. CT Sat., Oct. 17, 2026  •  Analysis and opinion: Stu’s views are labeled  •  Not investment advice

As of 8:25 a.m. CT Saturday, Oct. 17 (AAA national averages)

Fill a 30-gallon pickup with diesel this weekend and you will hand over about $190. A year ago the same tank cost about $109. A 15-gallon fill of regular is about $65, up from $46 (AAA; ENB calculations). The national diesel average is $6.33 a gallon, up $2.69, or 74%, in a year and 20 cents under the Sept. 22 record. Regular is $4.31, up $1.26 (AAA).

If you heat with oil, EIA expects your winter bill to run about 21% higher than last year. If you heat with natural gas, as about half of American homes do with gas or propane, EIA expects you to spend a little less. Homes on electric heat, about 40% of the country, are expected to spend about 4% more (EIA). Same country, same crisis, opposite results. That gap is the story of this whole deep dive. The fuels we have to import through a war zone are expensive. The fuel we produce at home is not.

So here are the four questions readers keep sending us. How long does $100 oil last? How do gas and LNG markets rebalance? Is coal really back? And which shipping chokepoints should you watch? We pulled the latest numbers from the EIA, IEA, OPEC, the big banks, ship trackers and market data, and we flag where they disagree.

Part 1. How long will $100 oil last?

Where Brent has been

As of Oct. 16 settlement (futures); Oct. 14 (EIA Dated Brent spot)

On Feb. 27, the last trading day before the war, Dated Brent closed at $71.32 (EIA). The next day U.S. and Israeli strikes on Iran began the war, and on March 2 Iran’s Revolutionary Guard announced it was closing the Strait of Hormuz (Anadolu; WorkBoat). Spot Brent passed $100 on March 12 and peaked at $138.21 on April 7. An April ceasefire and a June framework deal pulled it all the way down to $68.53 on July 2 (EIA).

Then it came back. September attacks on Saudi Arabia’s East-West pipeline and a jump in tanker attacks sent prices up again (IEA; Kpler). Physical Dated Brent was $126.55 on Oct. 14, and the IEA said it was trading around $134 when it wrote its October report (EIA; IEA). Spot Brent has closed at $100 or more on 82 of 158 trading days since March 1 (ENB count from EIA data).

Futures, the price most headlines quote, are lower than physical oil because they are for later delivery. December Brent settled Friday at $109.86, up $3.94, the first $110 touch since May (CNBC; The National). WTI for November settled at $101.41, up $3.44 (CNBC). The Wall Street Journal tied Friday’s jump to Ukraine’s renewed strikes on Russian refineries as well as Hormuz risk (WSJ). Brent futures are up about 81% this year (Yahoo Finance; ENB calculation).

What the futures curve is telling you

As of Oct. 16 settlements, checked 8:24 a.m. CT Oct. 17

The cleanest answer to “how long” is the futures curve. Traders will pay $109.86 for December 2026 oil but only $86.69 for December 2027. That $23.17 gap is called backwardation: the market pays a big premium for barrels now because there are not enough of them now (CNBC; ENB calculation). Every contract through March 2027 ($101.53) is above $100. April 2027 is the first one under, at $99.41.

OPEC’s own monthly report shows how tight the front of the curve got. In September the gap between the first and third Brent contracts averaged a $8.24 backwardation, and first-to-sixth averaged $15.08 (OPEC).

Two cautions. Futures are prices, not forecasts, and they have been wrong in both directions this year. And the curve already assumes things get better. If Hormuz stays as it is, a falling curve can be pulled back up.

What the forecasters say, with dates

Forecasts age fast in a war, so here is each one with the date it was made.

The agencies agree on the direction and disagree on the size. The IEA says 2026 world oil demand falls 2.6 mb/d to 102.4 mb/d, and the market stays “in deficit through the end of the year” before “any eventual surplus emerges in 2027” (IEA). OPEC still has demand growing 0.2 mb/d this year, to 105.7 mb/d (OPEC; Enerdata). That is a gap of more than 3 million barrels a day between the two (ENB comparison; the two count demand on different bases). OPEC speaks for producers; the IEA speaks for importing countries. Read both with that in mind.

Three roads from here

We grouped the published forecasts into three scenarios. These are ENB groupings, not ENB forecasts.

• Road 1: Hormuz reopens and the deal holds ($62–80). Citi sees $70 this quarter and $65 next year if flows normalize, because the world swings to surplus (Citi). Goldman’s bear case is in the low $70s (Yahoo Finance). QatarEnergy’s CEO says LNG could return to normal “within weeks” of a reopening, though damaged trains take years (Baird Maritime). Julius Baer’s Norbert Rucker already argues that “we are not running out of oil, as flows out of the Middle East have largely recovered” (The National).
• Road 2: Stays constrained ($95–110). This is today’s path and roughly where EIA, Morgan Stanley and the futures curve sit: about $105 this quarter and $95–100 early next year (EIA; Morgan Stanley). Kpler’s ship tracking shows why. In preliminary figures (Kpler says early counts are usually revised up 1.5 to 2 times), oil cleared through Hormuz at about 68% of its pre-war baseline in the week to Oct. 13, and tanker crossings averaged 13 a day versus 50 before the war (Kpler).
• Road 3: Escalation ($115–140). Goldman’s bull case is $125 by December (Yahoo Finance). Spot Brent has already been to $138 (EIA). On Saturday, Al Jazeera reported that the U.S. and Iran are both claiming control of the strait amid new attacks on ships (Al Jazeera), and Kpler reported a strike on Aramco’s Dhahran headquarters on Oct. 13 (Kpler).

The shock absorbers: spare capacity, stock releases and demand

As of IEA Oil Market Report, Oct. 14; EIA weekly data for the week ending Oct. 9; IEA statement Oct. 15

Spare capacity is stuck behind the strait. On paper Saudi Arabia can pump 12.11 mb/d; it produced 8.3 mb/d in September. But the IEA puts *effective* spare capacity for all of OPEC+ at just 0.27 mb/d (IEA). Our reading: the idle Gulf barrels are not much use while they have to sail through a war zone. Gulf crude exports did recover to 13.9 mb/d in September, more than 75% of pre-war, helped by 5.6 mb/d of pipeline bypass exports (IEA). That is more than EIA’s 4.7 mb/d estimate of normal bypass pipeline capacity (EIA), so those routes look maxed out. (The two agencies measure different things: the IEA figure counts all bypass exports, which can include other ports and trucking.)

Emergency stocks are a bridge, and the bridge is getting short. IEA members have released about 330 million barrels since March, with about 100 million to go, including 20 million-plus barrels of diesel “as soon as possible” (IEA; ENB). The U.S. Strategic Petroleum Reserve is down to 283.0 million barrels, from 407.7 million a year ago (EIA). EIA expects it to fall to about 243 million by December before refilling starts in mid-2027 (EIA). Even with the releases, world inventories were 509 million barrels below pre-war levels at the end of September, and on-land stocks are the lowest since at least 2016 (IEA).

Demand destruction is doing the rest. The IEA counts year-on-year demand drops of 5 mb/d in the second quarter and 3.7 mb/d in the third, and expects 2.5 mb/d in the fourth (IEA). Goldman puts the third-quarter drop at 3.3 mb/d (Goldman Sachs). That is the polite name for families, truckers and factories using less because they cannot afford more. The IEA says diesel topped $200 a barrel in September and warns that, without Middle East supply, “further demand reductions and the heavy economic costs these will entail may be needed” (IEA). See ENB’s diesel outlook into 2027.

ENB answer to question one: the market says $100-plus Brent lasts about five more months, through the March contract. EIA says about two. The banks with the most recent calls say about $100 into the first quarter. Anything below $90 for long needs Hormuz open, and for that no one can give you a date.

Part 2. How do natural gas and LNG rebalance?

The Qatar hole

As of Kpler data via Reuters, Oct. 12; IEA Gas Market Report Q3-2026

Before the war, Hormuz carried about 11.4 Bcf/d of LNG, more than a fifth of world LNG trade, almost all of it from Qatar and the UAE (EIA). Qatar alone has nearly 80 million tonnes a year of capacity, about a fifth of world supply (Reuters via Cyprus Mail). Missile attacks on March 18–19 damaged two Ras Laffan trains with 12.8 Mtpa, about 17% of Qatar’s capacity, and QatarEnergy says repairs take three to five years (IEA full report; Baird Maritime).

Exports have collapsed. Kpler data show Qatar shipped 1.6 million tonnes in September, less than a quarter of its pre-war pace, and about a third of that went to Kuwait. October is on track for about 0.6 million tonnes (Reuters via Cyprus Mail). That is roughly 9% of a normal month (ENB calculation). The IEA puts cumulative LNG losses from the war at about 140 bcm over 2026–2030 (IEA).

Prices: one world, three very different gas bills

As of Oct. 16 settlements and assessments

Asian spot LNG for December hit $29.30 per million Btu on Friday, the highest since Dec. 23, 2022, up from $26.50 a week earlier (Reuters via P&GJ). Europe’s TTF benchmark closed at €87.55 per megawatt-hour, about $28.77 per million Btu (ENB conversion at the Oct. 16 EUR/USD close of 1.1213; Yahoo Finance; Yahoo Finance). TTF is up about 211% this year. U.S. Henry Hub for November settled at $3.116, with December at $3.386 and January at $3.759 (CNBC). Henry Hub futures are down about 15% this year (Yahoo Finance; ENB calculation).

Put simply, a European or Japanese utility pays about nine times what an American utility pays for the same gas (ENB calculation). EIA expects Henry Hub to average $3.48 this year and $3.16 next year (EIA). That is why gas-heated American homes are getting a break this winter while the rest of the world is not (EIA).

Europe’s winter math

As of GasRadar briefing Oct. 16 (GIE AGSI+ data)

EU gas storage is 74.2% full, against a five-year norm of about 90.2% for mid-October. On GasRadar’s median path, EU storage ends winter around 26.1% on April 1 (GasRadar). Germany is at 60.6% (gas day Oct. 15) (GIE AGSI+). Our Oct. 15 piece, Europe’s Gas Prices Close to 2022 High as LNG Market Shifting, walks through why: Europe and Asia are now bidding against each other for every flexible cargo. Morgan Stanley sees TTF around €90 this winter, with a €135 risk case (Reuters via P&GJ). Citi, in September, had TTF in the mid-€50s for the fourth quarter (Citi). That is a wide range, and the cold will decide it.

Asia: buying less, burning coal

Asia rebalanced the hard way. The IEA estimates China’s gas demand fell about 4% year-on-year from March to June, and its LNG imports fell 12%. Across Asia, high prices brought demand-side measures and switching from gas to coal (IEA). The fertilizer shock is real too: Gulf fertilizer exports have “largely been halted,” and high gas prices cut fertilizer output in Bangladesh, India and Pakistan (IEA). Columbia University’s Center on Global Energy Policy called Asia’s response a playbook of “coal, curtailment, and competing for LNG” (CGEP).

The American LNG wave

As of EIA STEO Oct. 6; WorkBoat Sept. 13; IEA Gas Market Report Q3-2026

This is where the rebalancing really happens. U.S. LNG exports averaged 17.4 Bcf/d in the first half of 2026, up 23% (Rig & Refinery). EIA expects 17.6 Bcf/d for 2026 and 18.6 for 2027, reaching about 21.1 Bcf/d of exports by December 2027 (EIA). The IEA says new projects in North America, Africa and Australia add close to 50 bcm of supply this year, which mostly offsets the Gulf loss (IEA).

• Online: Venture Global’s Plaquemines is exporting at full capacity, and Cheniere’s Corpus Christi Stage 3 reached substantial completion Aug. 28. Together they add about 4 Bcf/d, and both were already exporting part of that in 2025 (WorkBoat). Golden Pass, owned by QatarEnergy and ExxonMobil, shipped its first cargo April 22. Its Trains 2 and 3 come “in turn,” for about 18 Mtpa in all (Golden Pass).
• 2027–2029: Rio Grande LNG (first LNG in the first half of 2027), Port Arthur (2027, second train 2028), CP2 (guided second half 2027, “slippage risk into 2028”), Corpus Christi Midscale 8–9 (second half 2028) and Woodside Louisiana (2029) (WorkBoat; EIA).
• New FIDs: 2025 brought a record six U.S. final investment decisions (Poten), including Rio Grande Trains 4 and 5 (NextDecade Train 4; NextDecade Train 5). Since March, CP2 Phase 2, Delfin’s first floating LNG vessel and Commonwealth LNG have also reached FID, all for around 2030 (IEA).

Add it up and about 21.5 Bcf/d of new U.S. LNG capacity is online, building or sanctioned (ENB tally; Mtpa and bcm converted to Bcf/d by ENB). For scale, U.S. exports averaged 15.1 Bcf/d in 2025, though some of the new capacity, Plaquemines and Corpus Christi Stage 3, was already exporting in 2025, so the two numbers overlap. The IEA expects North American export capacity to approach about 340 bcm a year by 2030 (IEA). Qatar is building too: the first train of its North Field East expansion should be ready to start in November, two people familiar with the plans told Reuters (Baird Maritime). The IEA says the full 44 bcm/yr project could be delayed by more than a year (IEA full report).

ENB answer to question two: gas rebalances in three steps. This winter it rebalances through price: Asian demand cuts, coal switching and European storage drawdowns. In 2027 new supply arrives, with about 7 Bcf/d of U.S. capacity due that year by our tally plus North Field East. By 2028, if Hormuz is open, the wave the IEA was already expecting before the war returns, minus the damaged Qatari trains. Our June deep dive, The New Energy Boom: Data Centers, LNG and America’s Gas Advantage (June 24), covers the tug-of-war at home between LNG exports, data centers and your utility bill.

The fair counterpoint: more exports tie U.S. prices more closely to the world. The Industrial Energy Consumers of America, a manufacturers’ group that buys gas, asked DOE in January to suspend spot LNG exports to bring down gas and power prices, while saying it is not against LNG exports (IECA). For now the numbers favor the exporters: Henry Hub is down this year while LNG exports hit records, including record first-half volumes (CNBC; WorkBoat).

Part 3. Is coal making a comeback?

As of IEA Coal Mid-Year Update (published Sept. 2026); Newcastle futures Oct. 16

Yes, at least this year. The IEA now expects world coal demand to rise 1.2% to a record 8.94 billion tonnes in 2026, reversing its earlier call for a decline. It blames the Middle East war and an unusually strong El Niño: expensive gas pushed power plants to switch to coal, and some countries temporarily allowed more coal burning (IEA). If tensions ease, the IEA sees a slight dip to 8.91 billion tonnes in 2027 (IEA).

• China: demand up about 1% to roughly 5 billion tonnes, more than half the world’s coal, helped by strong power demand, weak wind and expensive LNG (IEA). September imports were 43.37 million tonnes, down 5.7% from a year earlier but up 3% from August, as domestic prices hit a near three-year high (OilPrice; SXCoal).
• India: up 4.2% to 1,353 Mt, back on its long growth trend (IEA).
• Japan: down 1% to 161 Mt, but coal power runs higher than expected because of gas prices, and the government removed limits on which coal plants can earn capacity payments (IEA). Rystad says Japan’s coal imports ran more than 20% above a year earlier in May (Rystad).
• Korea: up 6% to 119 Mt, reversing an expected decline; coal generation jumped 30% year-on-year in the first quarter (IEA). Rystad says Korea’s coal imports ran more than 50% above a year earlier in May (Rystad).
• Germany and Europe: a counterpoint, not a surge. Destatis data show German coal generation was down 0.5% in the first half to 49.4 TWh while gas generation rose 6.4% (Clean Energy Wire). Hard coal did jump 23.5% in the second quarter, to 5.7 TWh (SMARD). Reuters reported in September that European coal generation could rise about 25% over six months as gas stays expensive (Reuters via Euronext). The IEA puts EU coal use at 276 Mt this year, a slower decline than it expected (IEA). See ENB’s European coal coverage.
• United States: coal use rose more than 9.5% to 410 Mt in 2025, and the IEA expects a 7% drop in 2026 because U.S. gas is cheap. Emergency orders and postponed retirements are slowing the decline (IEA).

Prices: Newcastle thermal coal futures settled at $150.40 a tonne on Oct. 16, close to the 52-week high of $152.25 and up from a low of $103.70 (Investing.com). The IEA says Newcastle averaged $139 a tonne in June and $131 in August, and was assessed at $136 by late August (IEA). Kpler argues that “three shocks are resetting coal’s winter ceiling” (Kpler).

America’s coal fleet and DOE 202(c)

As of DOE 202(c) orders page, checked Oct. 17

Here at home, the Department of Energy is using Section 202(c) of the Federal Power Act to keep retiring plants running. Current coal orders include J.H. Campbell in Michigan (through Nov. 14; it was supposed to close May 31, 2025), Centralia Unit 2 in Washington (through Dec. 11), Schahfer 17 and 18 and Culley 2 in Indiana (through Dec. 18), Craig 1 in Colorado (through Dec. 25) and Stanton 1 in Florida (through Nov. 30). DOE’s latest order, 202-26-50, went to PJM on Oct. 12 (DOE).

Energy Bad Boys, the Always On Energy Research team of Isaac Orr and Mitch Rolling, is a think tank that is openly critical of wind and solar mandates. Its June analysis of FERC data for 82 plants found existing coal plants produce power for an average of $45.57/MWh, and nearly eight in ten for under $60 (Energy Bad Boys; see ENB’s repost). To its credit, the same report names the outliers at both ends, and three are under DOE orders: Schahfer, second-most expensive at $110.03/MWh; Culley, at $86.86; and Campbell, among the cheapest at $30.36 (Energy Bad Boys). It argues cost is not the only test, because Schahfer ran near full output when supply was tight (Energy Bad Boys). Its work on NERC’s blackout warnings and on near-misses in grid regions like SPP makes the same reliability case (Energy Bad Boys; Energy Bad Boys).

The other side: on Sept. 11 the D.C. Circuit vacated DOE’s first Campbell order, finding the agency had not shown an imminent emergency (D.C. Circuit). Consumers Energy reported a $259 million net cost of compliance, after $239 million in MISO market revenues (Utility Dive). Rystad Energy says Asia’s shift is “not a coal comeback but a reality check” for the energy transition (Rystad).

ENB answer to question three: coal is back as the world’s shock absorber. It is a comeback in Asia this year and a slower decline in Europe. In the U.S. it is mostly a fight over keeping existing plants open. How long it lasts depends on LNG prices, and those depend on Hormuz and the 2027 supply wave. See Coal Making a Comeback: How Fast and How Long?.

Part 4. The chokepoints to watch

As of UKMTO weekly data to Oct. 14 (via Anadolu, Oct. 17); other sources as dated in the table

About 80 million barrels a day of oil moves by sea, and much of it squeezes through a handful of narrow straits (EIA). Here is EIA’s pre-war map of flows with where each stands this week.

Saudi Arabia’s escape route is the Red Sea. Kpler shows Red Sea exports averaging about 3.25 mb/d over seven days, above a 2.80 mb/d baseline, after Yanbu loadings resumed Sept. 17 following the East-West pipeline attack (Kpler). But that route runs past the Houthis at Bab el-Mandeb, which is why two chokepoints now matter for the same barrel. ENB’s Hormuz escape-routes piece and tanker-attack coverage have more. The U.S. imported only about 0.4 mb/d through Hormuz before the war (EIA). We feel it through world prices, not empty terminals.

Energy security starts at home

As of EIA weekly data, week ending Oct. 9; EIA STEO Oct. 6

If there is one lesson from 2026, it is that energy security beats energy policy goals when supply is on the line. Look at what America did this year. Crude exports have averaged 4.26 mb/d, up from 3.87 in 2025, and petroleum product exports 7.55 mb/d, up from 6.84 (EIA; EIA; ENB averages). U.S. crude output was 13.68 mb/d last week (EIA), and EIA expects 14.3 mb/d in 2027 (EIA). LNG exports are set to rise 16% this year, and coal exports about 11% to 102 million short tons (EIA).

Those exports are what “energy dominance” looks like in practice: allies in Europe and Asia buying American molecules instead of waiting on a strait. It also explains the gas-bill gap at home. The fuels America produces in surplus, natural gas and coal, are cheap here. The ones we trade at world prices, crude and especially diesel, are not. ENB has covered this on the podcast in Energy Security Starts at Home and in The New Energy Boom.

Counterarguments, fairly stated. Supporters of wind and solar say this crisis shows why homegrown renewables matter, since they need no tankers. The IEA noted that stronger renewable output helped cut Europe’s gas use in the first half (IEA). ENB’s view is that weather-dependent power still needs firm backup in a crisis, and that subsidies hide its true cost to ratepayers (see The Subsidy Cliff and Your Power Bill). Energy Bad Boys’ reliability work points the same way, but it comes from a mandate-critical think tank (Energy Bad Boys). Others warn that exports and refineries cannot be built fast enough to help this winter, and they are right: new refining, like the planned Brownsville plant, is years away (ENB).

Consumers vs. investors

As of AAA, 8:25 a.m. CT Oct. 17; Yahoo Finance closes Oct. 16

Consumers: Pew Research Center found 74% of Americans are very concerned about “the price of gas and energy” (Pew). Diesel is up $2.69 a gallon in a year, and regular is up $1.26 (AAA). EIA’s retail forecast has diesel averaging $5.19 this year and $4.49 next, and gasoline $3.91 and $3.56 (EIA). So EIA expects relief, slowly. Gas-heated homes do better this winter, oil-heated homes worse, and electric-heated homes (40%-plus) about 4% worse (EIA).

Investors: the Energy Select Sector fund (XLE) closed Friday at $68.24, up about 52.6% this year on price alone (about 55.7% with dividends), against about 11.9% for the S&P 500 fund (Yahoo Finance; Yahoo Finance; ENB calculations). Wall Street is split on what comes next. Morgan Stanley just raised its oil call Morgan Stanley). Goldman calls the risk from the Iran war “significant” but still sees oil easing (Yahoo Finance). Citi and Julius Baer lean bearish (Citi; The National). U.S. gas investors have the opposite problem from consumers abroad: Henry Hub futures are down about 15% this year. None of this is investment advice.

Drivers pay; energy shareholders gain. Sources: AAA; Yahoo Finance. ENB calculations. Not investment advice.

What to watch

• Weekly: UKMTO’s Hormuz transit counts and attack tally (UKMTO); EIA’s Wednesday stocks and exports data (EIA); AAA prices every morning (AAA).
• 10: EIA’s next Short-Term Energy Outlook, the first to include October’s price spike (EIA). Mid-November: the next IEA and OPEC monthly oil reports.
• November: Qatar’s first North Field East train is due to be ready (Baird Maritime); Qatar’s November export count from Kpler.
• This winter: EU storage against the 26% end-of-winter median path (GasRadar); JKM versus TTF as Europe and Asia compete for cargoes (Reuters via P&GJ).
• 14–Dec. 25: expiry dates for the current DOE 202(c) coal orders, starting with Campbell (Nov. 14) and Stanton (Nov. 30), and whether DOE renews them (DOE).
• 2027: the U.S. LNG wave: Golden Pass Trains 2–3, Rio Grande, Port Arthur and CP2 (WorkBoat).

The bottom line

How long will $100 oil last? The honest answer is as long as the Strait of Hormuz stays half open, and the market is betting on at least through the winter. Gas and LNG will rebalance the slow way: high prices this winter, then a wave of American and Qatari supply in 2027 and 2028. Coal is the world’s emergency fuel again, and the chokepoints, from Hormuz to the Red Sea to the Bosporus, are where the next surprise will come from. Through all of it, the country with its own oil, gas and coal has the cheapest bills and the most options. Energy security starts at home. Keep following the numbers with us at Energy News Beat.

Appendices

At Energy News Beat we Make Appendices Great Again. Everything below backs up the article: every source with a link and a label for its point of view, the key numbers, the timeline, the exact words behind our quotes, how we did the math, and what we could not confirm. Every figure in the charts is in the companion workbook, “How Long Will $100 Oil Last – Hormuz, LNG and Coal Are Writing Your Winter Fuel Bill – Data.xlsx,” with a source and URL on each sheet.

Appendix A. Sources, with perspective labels

“Perspective” tells you who is speaking. Official agencies, market data, news outlets, banks, think tanks, advocacy groups and companies all have points of view; we label them so you can weigh them.

Appendix B. Key figures

Appendix C. Timeline

Appendix D. Key passages, verbatim

“Despite lower demand, oil market balances are forecast to remain in deficit through the end of the year, with constrained middle distillate supplies likely to persist well into 2027.”

Source: IEA Oil Market Report, Oct. 14

“Cumulative global observed inventories were a steep 509 mb below pre-war levels by the end of September, with on-land stocks hovering at their lowest levels since at least 2016.”

Source: IEA Oil Market Report, Oct. 14

“Failing this, further demand reductions and the heavy economic costs these will entail may be needed to balance markets.”

Source: IEA Oil Market Report, Oct. 14

“Global coal demand is set to increase by 1.2% in 2026 to reach 8.94 Bt, reversing previous forecasts of a decline.”

Source: IEA Coal Mid-Year Update 2026

“The losses resulting from the Middle East conflict are equivalent to 15% of the amount of new LNG supply that is set to be added globally over the 2026-2030 period.”

Source: IEA Gas Market Report, Q3-2026

“We are not running out of oil, as flows out of the Middle East have largely recovered.” — Norbert Rucker, Julius Baer

Source: The National (Reuters), Oct. 16

“The bank raised its winter forecast for the Dutch TTF benchmark to €90/MWh and said prices could reach €135/MWh if a prolonged Qatar outage, colder weather or other LNG disruptions occur.”

Source: Pipeline & Gas Journal (Reuters), Oct. 16, on Morgan Stanley

“Despite the damage, Qatar would be able to resume normal gas operations within weeks once the strait reopens, Kaabi said last month.”

Source: Baird Maritime (Reuters), Oct. 7

“What we are seeing is not a coal comeback but a reality check for APAC’s energy transition.”

Source: Rystad Energy, June 8

“Existing coal plants operate at $45.57 per MWh, and nearly eight out of ten in our analysis produce electricity for less than $60 per MWh.”

Source: Energy Bad Boys, June 27

“There’s only two ways diesel and gasoline prices can come down. One, demand destruction. Number two, … more refineries.” — Stuart Turley

Source: Daily Caller News Foundation, Oct. 12

Appendix E. Methodology and ENB calculations

Price times: futures are Friday, Oct. 16 settlement prices, read from CNBC quote pages at 8:24 a.m. CT Saturday, Oct. 17. AAA prices are “Price as of 10/17/26,” checked 8:25 a.m. CT. EIA Dated Brent spot runs through Oct. 14. Markets are closed for the weekend; re-check Monday.

Backwardation [ENB CALC]: Dec. 2026 settle $109.86 minus Dec. 2027 settle $86.69 = $23.17.

Days at $100+ [ENB CALC]: count of EIA daily Dated Brent closes at or above $100 from March 1 to Oct. 14, 2026 (82 of 158).

TTF conversion [ENB CALC]: €87.547/MWh × EUR/USD 1.1213 (Yahoo Finance, Oct. 16 close) ÷ 3.412 MMBtu per MWh = $28.77/MMBtu. Reuters’ intraday figure of €88.57 ≈ $29.20 is consistent. “About nine times” = TTF (9.2x) or JKM (9.4x) ÷ Henry Hub November $3.116.

Qatar share [ENB CALC]: 0.6 Mt ÷ (80 Mtpa ÷ 12 = 6.7 Mt a month) ≈ 9%. Reuters puts capacity at “nearly 80 Mtpa,” so normal is an approximation.

LNG wave tally [ENB]: EIA Today in Energy capacities in Bcf/d for Rio Grande Phase 1 (2.1), Port Arthur Phase 1 (1.6), Woodside Louisiana (2.2), Golden Pass (2.1, split one-third to Train 1 by ENB) and CP2 Phase 1 (2.0); WorkBoat’s 4 Bcf/d for Plaquemines plus Corpus Christi Stage 3. Others converted by ENB at about 0.13 Bcf/d per Mtpa and 0.0967 Bcf/d per bcm/yr: CC Midscale 8–9 (>3 Mtpa ≈0.4), Rio Grande 4–5 (~12 Mtpa ≈1.6), Port Arthur Phase 2 (~13 Mtpa ≈1.7), CP2 Phase 2 (40 bcm/yr total minus Phase 1 ≈1.9), Commonwealth (13 bcm ≈1.3), Delfin FLNG 1 (6 bcm ≈0.6). Total about 21.5 Bcf/d. Plaquemines and part of Corpus Christi Stage 3 were already exporting in 2025, so the tally overlaps 2025’s 15.1 Bcf/d of exports. Rio Grande Trains 4 and 5 reached FID Sept. 9 and Oct. 16, 2025 (NextDecade). Timing buckets are ENB’s reading of company and press guidance; nameplate and peak ratings differ, and dates slip.

Export averages [ENB CALC]: mean of EIA weekly U.S. crude oil exports and total petroleum product exports for weeks ending Jan. 2–Oct. 9, 2026, versus all 2025 weeks.

Fill-ups [ENB CALC]: 30 gallons × AAA diesel and 15 gallons × AAA regular, today and a year ago.

Investor returns [ENB CALC]: Yahoo Finance closing prices, Oct. 16, 2026 versus Dec. 31, 2025. Brent and Henry Hub use continuous front-month futures, which roll between contracts. Not investment advice.

Coal: U.S. 2026 tonnage is ENB’s 410 Mt × (1 − 7%) ≈ 381 Mt; China 2026 is the IEA’s “5 Bt.” Germany data are generation (TWh), not tonnes.

Scenario ranges: ENB groupings of published forecasts and the 2026 price record. They are not ENB forecasts.

Rounding: dollars to the cent where quoted; percentages to whole numbers unless a decimal matters.

Appendix F. Perspective guide: who said what

Appendix G. What ENB could not confirm

• Morgan Stanley’s full note. We relied on the investingLive summary; Quantum Commodity Intelligence’s story is paywalled. Aggregator reports crediting the same raise to JPMorgan quoted Morgan Stanley’s Martijn Rats, so we did not use them; we found no JPMorgan note or release.
• Any Citi oil forecast newer than Sept. 3, 2026.
• A primary JKM settlement. We used the Reuters-reported December assessment ($29.30); a CNBC quote page showed 29.93 in an unsettled, synthetic quote that we did not use.
• Kpler’s Hormuz figures are preliminary (Kpler says early counts are typically revised up 1.5–2x) and, by Kpler’s own notes, exclude Iranian-origin cargo and depend on how ship-to-ship transfers are dated.
• Qatar’s exact pre-war monthly export average; ENB used Reuters’ “nearly 80 Mtpa” ÷ 12.
• Firm start dates for Golden Pass Trains 2–3; the company says only that they come online “in turn.” LNG wave timing in general is ENB’s reading of guidance.
• An IEA or EIA publication of the OPEC+ spare-capacity reasoning; the “stranded behind the strait” wording is ENB’s interpretation of the IEA table.
• A source confirming that Istanbul Strait traffic has fully resumed after the Oct. 11 suspension, or the exact date Panama moved to 33 daily transits (DataPortuaria reported it Oct. 16).
• Whether the U.S. and Iranian claims of “control” of Hormuz reported by Al Jazeera on Oct. 17 change any shipping patterns; UKMTO’s next weekly count will tell.
• A WSJ analyst-survey figure that appeared in early notes; we could not find it in the WSJ text and did not use it. The WSJ market story we cite was updated: its headline now says oil prices rose, while its web address still reads “oil-prices-fall.”

Appendix H. Glossary

Brent / WTI: The world and U.S. crude oil price benchmarks.

Dated Brent: The physical North Sea cargo price, which this year has run far above futures because of freight and insurance.

Backwardation: When near-term futures cost more than later ones, a sign of scarcity now.

TTF / JKM / Henry Hub: European, Asian and U.S. natural gas price benchmarks.

LNG: Liquefied natural gas, shipped by tanker.

Mtpa / Bcf/d / bcm: Million tonnes per year; billion cubic feet per day; billion cubic meters.

FID: Final investment decision, the point when a project is funded and built.

Effective spare capacity: Oil output that can be added quickly and actually delivered.

SPR: The U.S. Strategic Petroleum Reserve.

202(c): The Federal Power Act section DOE uses to order plants to keep running in an emergency.

Newcastle: The Asian seaborne thermal coal price benchmark.

mb/d: Million barrels per day