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Grid recap · Saturday 14 November 2026 (UTC day)

Published from data as then available; later operator revisions are not applied.

Electricity used on 14 Nov, by market

Partial day, not in the totals: PJM 75D %, MISO 75D %, ERCOT 75D %, SPP 75D %, ISO-NE 75D %.

Cheapest hour SA 14:30–15:30 ACDT · −87.69D AUD/MWh

Most expensive hour GB 09:00–10:00 GMT · 203.31D GBP/MWh

Below zero SA 7 h 50 minD · TAS 1 h 50 minD · VIC 1 h 50 minD

What happened on 14 November

On 14 November, 3 markets paid buyers to take power at some point: South Australia for 7 h 50 minD, Tasmania for 1 h 50 minD and Victoria for 1 h 50 minD. The longest unbroken run was in South Australia, 1 h 50 minD from 08:35–10:25 ACDT; the lowest price there during the day was −A$148D/MWh. The run sat inside local daytime hours, when rooftop and utility solar in the NEM is producing. This site does not publish a generation mix for the NEM regions, so the solar and wind share in those intervals is not shown.

Denmark had the cleanest mix of the grids we meter, 80.3D % renewable over the day, with wind at 76.2D % and solar at 4.1D %. Great Britain followed at 48.9D % renewable with wind 38.3D % (transmission-metered; solar on local networks is not in this data). Taiwan followed at 6.5D % renewable with wind 2.8D % and solar 2.2D %. Across the 8D markets with a full day of metered demand, 1,846,770D MWh was used, Taiwan the largest at 35.4D % of it.

Time below zero across all markets added up to 11 h 30 minD, more than the 1 h 45 minD on 13 November. Tasmania went below zero after staying positive the day before. Queensland stayed above zero this time. Electricity used fell in every market compared, most in South Australia (−20.7D %) and least in New South Wales (−1.5D %). Denmark's renewable share fell by 3.6D points, from 83.9D %. Great Britain's renewable share rose by 7.2D points, from 41.7D %. Taiwan's renewable share fell by 2.8D points, from 9.3D %. The cheapest hour anywhere cost about −60D USD/MWh, against −4D on 13 November.

How to read this. The 14 November recap covers 15D markets (8D with a full day of demand) and was frozen at 00:30 UTC on 15 November; later operator revisions are not applied. A D badge marks a number we calculated from the operators' metered data, an M badge one published as is. Durations add up priced intervals below zero, clock times are each market's local time, and shares are energy-weighted over the day. Definitions and limits are in the methodology.

ⓘ How this recap is made

Built once after the UTC day ended, then frozen. Electricity used is the metered demand of each market added up over the day (Great Britain: transmission generation); only markets with at least 95 % metered coverage of the day are added up. Hours are UTC hours priced as the mean of the source periods. Below zero is the sum of priced intervals under zero. Nothing is estimated or filled in.

ⓘ Sources & licences

Source: Australian Energy Market Operator (AEMO), NEMWEB (licence); Source: U.S. Energy Information Administration, Hourly Electric Grid Monitor (EIA-930) (licence); Contains BMRS data © Elexon Limited copyright and database right 2026 (licence); Source: Energinet (www.energidataservice.dk); Taiwan Power Company 2026 台灣電力公司各機組發電量即時資訊(含外購電力) / 台灣電力公司今日系統供需狀況 — Open Government Data License: https://data.gov.tw/license. Derived numbers and charts: CC BY 4.0, SolarCostData Data Desk. Source data keeps its own licence.

Not for trading or operational decisions. Provisional data.