Gas fell again on Monday, to $2.60. Oil eased. Stocks recovered. So why is your power bill still climbing? Because the bill is no longer mostly fuel — it is the price of reserving a seat on a crowded grid, plus the cost of money to build the next one. Today we put numbers and dates on both, and tell you exactly what to check on Wednesday and Thursday.
Executive thesis: Monday, October 26 calmed every commodity that scares people. Brent crude settled at $115.81 a barrel, down 0.78%, as Saudi and Iranian officials talked in Tehran. Natural gas settled at $2.602 per million British thermal units, down 1.44% — its fifth-lowest settlement of the year. The fear gauge fell 5.45% to 18.39.
The claim: none of that relief reaches your electricity bill this winter, because the two costs driving bills are not fuel costs at all. They are two. First, capacity — the fee paid to generators just to promise power on the worst day. In the mid-Atlantic PJM grid, that fee is pinned at its $325-per-megawatt-day cap. A megawatt-day is one megawatt of promised power for one day. The cap is 11.2 times its price two delivery years ago. A delivery year is the year the promised power must be ready. Second, financing. The 10-year Treasury yield sits at 4.99% on the morning the Federal Reserve opens its meeting. The mechanism: fuel is bought by the hour and fell on Monday; capacity and interest are locked in for years and did not.
What is priced in is wholesale power — the bulk price utilities pay before delivery costs — averaging $52 per megawatt-hour in 2026, up 11%, with PJM up 41%. What would prove this wrong is below, with dates and thresholds.
Green: watching, tracked and normal. Amber: warning, look closer. Red: danger, act. Every card states its meaning in words, not colour alone. Markets last closed Monday, October 26.
Monday in one table: everything frightening got a little cheaper, everything structural stayed exactly where it was.
| Monday, October 26 | Close | Move |
|---|---|---|
| S&P 500 | 7,676.77 | +0.70% |
| Dow Jones Industrial Average | 52,361.58 | +0.28% |
| Nasdaq Composite | 26,169.38 | +0.82% |
| Fear gauge (VIX) | 18.39 | −5.45% |
| 10-year Treasury yield | 4.99% | unchanged |
| WTI crude | $101.76 | −1.46% |
| Brent crude | $115.81 | −0.78% |
| Natural gas, November contract (per MMBtu — a million British thermal units, the standard unit gas is priced in) | $2.602 | −1.44% |
| Gold | $4,026.30 | +0.46% |
Read it plainly: stocks rose as an artificial-intelligence listing filing revived the tech trade, oil slipped as diplomacy took some premium out, and gas kept sliding on warm forecasts. The two rows that did not move — the 4.99% borrowing rate and, off-table, the $325 capacity cap — are the rows your bill actually reads. Sources: Dow Jones Market Data via Morningstar (Dow Jones Data Talk), October 26, 2026; closing reports, October 26, 2026.
Your move, with numbers: pin the three trigger levels in the Tuesday checklist below. Check them once, at Thursday's close, not hourly.
The Federal Reserve opens its two-day meeting today and decides Wednesday, October 28 at 2:00 p.m. ET. Markets give a hold at 3.75% to 4.00% about a 91% chance. A Reuters poll of 100 economists found 94 expecting a hold — and all 100 expecting a rise in December. September consumer prices rose 3.7% over the year, against a 2% target, with expensive energy part of the pressure.
Why a power desk cares about a rate meeting: a power plant is almost all upfront cost and decades of payback, so its economics are set less by this year’s gas price than by the interest rate on the day it is financed. At a 10-year yield of 4.99%, that financing is expensive. A December rise to a 4.00% to 4.25% range would make it more so — and would land exactly when utilities are filing the spending plans that become 2027 and 2028 bills.
The demand those plans must serve is not hypothetical. The Energy Information Administration expects U.S. electricity sales of 4,135 billion kilowatt-hours in 2026, up almost 2%, and 4,211 billion in 2027 — growth driven by data centres and factories after two flat decades. McKinsey’s Global Energy Perspective 2026, published September 30, calls data centres the fastest-growing source of new electricity demand in developed markets, growing at 24% a year through 2030, and finds power supply falling short of computing demand in nearly every scenario it modelled. Treat McKinsey as context, not gospel — but the EIA’s own sales numbers point the same way.
Your move: Wednesday, 2:00 p.m. ET — ignore the headline rate (a hold is 91% priced) and score the statement on one question: does it name energy prices as an inflation risk? If yes, price in a December rise and expect utility borrowing costs — and future bills — to stay at today’s highs. If no, the December odds, now roughly 3 in 4, should fall within the hour; that is your signal that project money gets no worse this year.
The molecules are abundant and getting cheaper. Gas storage stood at 3,644 billion cubic feet in the week ended October 16, after a build of 77 billion, and the November futures contract has fallen 14.01% this month to $2.602. Producers are responding to tomorrow’s demand, not today’s price: On Monday, EQT agreed to buy Range Resources. The price is 0.987 of an EQT share per Range share. That is an equity value — the value of the shares being bought — of $12.83 billion, or $54.91 a share — a premium of about 20.6%. The deal creates a producer of more than 9 billion cubic feet equivalent a day (gas plus liquids, all counted as gas). It spans nearly 3 million acres. Its combined value is above $50 billion including debt. It is expected to close in the first quarter of 2027. Sellers of gas are consolidating for scale; buyers of gas-fired power should note the date — that scale arrives in 2027, not this winter.
The megawatts are scarce and priced at the ceiling. PJM, the grid serving 67 million people in 13 states and Washington, D.C., held its 2028/29 capacity auction at the $325-per-megawatt-day cap — the third straight auction at the ceiling — collecting about $16.4 billion, yet still finished 6,831 megawatts short of its requirement. Its reserve margin — the safety cushion of spare power above expected demand — was 14.7%, against a 20% target. Only about 525 megawatts of new generation cleared — clearing means it won a place in the auction. PJM’s own market monitor attributes $29.4 billion of the $63.6 billion spent across the last four auctions to data-centre load. That is the dispersion in one sentence: the fuel to run a plant costs $2.60; permission to count on the plant costs eleven times what it did two years ago.
Regulators are splitting the difference — visibly. PJM's new registry covers very large users: 50 megawatts or more at one site. Who gets cut first in a crunch is a choice for states, not the federal regulator. PJM's follow-up filing — the paperwork that shows the rules were followed — is due Monday, November 9. Its emergency backstop — a last-resort plan to buy extra power, capped at $555 per megawatt-day — is refiled around Thursday, October 29.
Abroad, the same argument ended in compromise on Monday: Bloomberg reports Spain softened its draft data-centre rules. It replaced an immediate 80% hourly renewable-matching duty — a duty to match power use with renewable power, hour by hour. The new rule asks for 60% at peak hours until 2029. It rises to 70% in 2029 and 80% in 2032. It covers sites above 10 megawatts. Sources: Reuters, October 26, 2026 (EQT and Range Resources; Spain draft, cited by name) · Bloomberg, October 27, 2026 (Spain rules, cited by name) · PJM auction results and Independent Market Monitor, via Who Pays for Data Centers (PJM auction dataset).
Your move: if you run or advise any site drawing 50 megawatts or more in PJM territory, confirm this week — before November 9 — that the site is on the new large-load registry; that is now a compliance fact, not a choice. If you buy power for a business in PJM, ask your supplier one question in writing: how much of my 2027 quote is the $325 capacity charge? A supplier who cannot split it out cannot help you manage it.
Your move — capital, dated: the EQT–Range deal is expected to close in the first quarter of 2027. Until then, judge it on its stated terms — 0.987 of an EQT share per Range share, a premium of about 20.6% — not on this winter's gas price. For Spain: judge any data-centre plan against the new steps — 60% at peak until 2029, then the rises in 2029 and 2032 — not against the old 80% duty.
The week is unusually legible: three events, three numbers, three decisions. In order:
1 · Wednesday, October 28, before the open — GE Vernova earnings. The turbine maker is the grid’s bottleneck in listed form. Consensus — the average of analysts' forecasts — expects earnings of $4.01 a share on $11.99 billion of revenue, up from $1.64 a share a year ago. Ignore the headline beat or miss; read two backlog numbers. Gas equipment backlog stood at 116 gigawatts last quarter against a promise of at least 125 gigawatts by December 31 — anything below 120 gigawatts on Wednesday means the year-end promise needs a heroic quarter. Data-centre orders passed $5 billion in the first half, more than double all of 2025; a third-quarter figure that keeps that pace confirms the build-out is still accelerating. For you — capital: Wednesday's backlog print is the line for the turbine maker, not for the whole thesis. At or above 120 gigawatts, GE Vernova's year-end promise is on track, and its stock story strengthens. That same print means more supply is coming, which softens the scarcity story over time.
2 · Wednesday, October 28, 2:00 p.m. ET — the Fed. Covered above: the test is the statement’s energy language, and the December odds moving within the hour.
3 · Thursday, October 29, 10:30 a.m. ET — gas storage. The report covers the week ended October 23. The cushion over the five-year average was 35 billion cubic feet, less than 1%; analysts expect Thursday to show it narrowed to about 0.7%. Read it against one line: 3,609 billion cubic feet, the five-year average. A total still above it keeps the calm-gas story alive into winter; a total below it — the first deficit of the season — is the trigger to expect winter price spikes on any cold forecast.
Beyond the 48 hours, the firm megawatts remain slow and real: Three retired nuclear plants total 2,250 megawatts. Palisades in Michigan adds 800 megawatts, contracted by March 2027. Crane in Pennsylvania adds 835 megawatts, targeted for 2027 under a 20-year Microsoft deal. Duane Arnold in Iowa adds 615 megawatts, by 2029 with Google. Federal loans of up to $4.4 billion back the restarts. None of it is available this winter. For you — capital, dated: price these restarts as 2027-to-2029 assets, not as relief for this winter's bills. The fast megawatts remain flexible: Google and Voltus adding 1,070 megawatts of pay-people-to-use-less capacity in PJM, on top of a 100-megawatt start. For you, dated: watch that 100-megawatt start this winter. It can grow now. The nuclear restarts cannot arrive before 2027. Sources: company consensus via MarketBeat, October 2026 · Associated Press, October 16, 2026 · Voltus and Google announcement (GlobeNewswire), October 22, 2026.
Value creation this week is unglamorous and enormous: gas in the ground, gas in storage, turbines on order, reactors being refuelled. Almost none of it got cheaper or dearer on Monday.
Value capture went somewhere narrower. It went to whoever already owns a seat: generators whose existing plants collect $325 a megawatt-day for a promise, a gas major buying scale at a 20.6% premium while its product sells at $2.60, and flexibility providers who can sell 1,070 megawatts of using-less within months while firm plants take until 2027 or 2029. Bloomberg’s tally makes the household version plain: American electricity prices are up 38.3% since 2020, against overall inflation of roughly 29%, to an average residential price of about 18 cents a kilowatt-hour. The fuel did not do that. The seat did.
The takeaway: do not watch the fuel gauge this week. Watch the seat price, the money price, and the three dates above — they are the bill.