ERCOT Wholesale Prices Stayed Under $35 per MWh Through the July 22 All-Time Peak: Read-Through for Texas 2027 Commercial Fixed Rates

Key Takeaways

• ERCOT set a new all-time system peak of 91,308 MW on July 22, 2026, and no Energy Emergency Alert was declared, per ERCOT operational reporting.
• S&P Global Commodity Insights reported that real-time North hub prices stayed below $30 per MWh over the peak hour on July 22, with day-ahead on-peak clearing at about $75.98 per MWh.
• ERCOT's Cal 2027 North hub forward strip printed at about $43.92 per MWh on June 25, 2026 (heat rate near 12.73), per a Vistra/TXU market snapshot.
• EIA's February 2026 Short-Term Energy Outlook baseline puts ERCOT North average wholesale prices near $47.39 per MWh for 2027, and a high-demand data-center scenario adds 78.9% to that figure.
• The TxCP catalog (1,000 active commercial plans, market average $0.0880 per kWh) shows long-term contracts (24-plus months) averaging $0.0741 per kWh versus $0.1024 per kWh on short-term plans, a 38% short-vs-long premium consistent with a market that has not fully priced out its scarcity risk yet.

What Happened With ERCOT Wholesale Prices During the July 22 Peak?

ERCOT wholesale prices stayed low. Day-ahead on-peak prices at the ERCOT North hub settled at about $68 per MWh on July 21, 2026 and $75.98 per MWh on July 22, 2026, and real-time settlement point prices at the ERCOT North hub stayed under $30 per MWh over the peak hour, according to S&P Global Commodity Insights. That is well under the $35 per MWh threshold that would typically start to draw broker attention as a scarcity signal.

The grid conditions themselves were extreme. ERCOT reached an all-time system peak of 91,308 MW on July 22, breaking the prior record of 85,508 MW set in August 2023, per ERCOT's April 15, 2026 preliminary long-term load forecast release. Doug Lewin, publisher of the Texas Energy and Power Newsletter, framed the outcome directly on July 23: the grid held above 91 gigawatts through triple-digit heat, and wholesale prices stayed roughly 95% below the ERCOT price cap for the duration of the peak, meaning no material scarcity adders were triggered.

For a commercial buyer, the value of that data point is what it tells you about the risk premium embedded in short-term plans. When a record demand day clears at normal prices, the market is telling you the marginal MW was cheap. That is not a guarantee about future days, but it is data.

Why Did Wholesale Prices Stay Under $35 per MWh During a Record Peak?

Three factors compressed the peak-hour price. First, ERCOT solar and battery output was strong through the afternoon peak. ERCOT now has more than 25 GW of installed solar and over 15 GW of battery storage capacity, and both fleets ran near capacity into the 5 PM to 7 PM peak window, according to a corroborating July 22 report from Energy News Beat. Second, natural gas fuel cost was moderate. Henry Hub was trading near $3.29 per MMBtu through July, keeping the marginal gas-plant offer curve well below scarcity levels. Third, ERCOT's operating reserves were comfortable enough that the Operating Reserve Demand Curve (ORDC) adder, which is what turns a tight day into a $500 per MWh day, never activated.

The important structural point for 2027 buyers is that this peak was met without new capacity coming online. It was met with the summer 2026 resource mix ERCOT already has, plus the summer 2026 gas curve. Any bearish revisions to the 2027 forward strip that price in solar and batteries meeting the peak now have a data point to lean on.

What Is the Peak-Day Price Test, and How Do You Apply It?

Commercial buyers who follow ERCOT news often see a scary peak-demand headline and assume forward prices are about to move against them. The reverse is often true. Here is a simple, three-check test you can apply to any ERCOT peak day, called the Peak-Day Price Test.

1. Did real-time settlement prices at the North hub stay under $50 per MWh during the peak hour? If yes, scarcity did not trigger, and the marginal MW cleared at close to variable cost.
2. Did day-ahead prices clear without a scarcity adder (roughly under $150 per MWh on the peak day)? If yes, the market was not pricing tight conditions into the next day.
3. Did the Cal 2027 forward strip at the North hub move up materially (more than $2 per MWh) in the trading session after the peak? If no, the forward market absorbed the event without repricing.

July 22, 2026 passed all three checks. Real-time cleared under $30 per MWh in the peak hour, day-ahead settled at $75.98 per MWh (well inside the non-scarcity band), and the Cal 2027 forward strip near $44 per MWh at the ERCOT North hub had already been trading in the low $40s all of June per the Vistra June 25 snapshot cited below. A passing Peak-Day Price Test is a bullish confirmation for the forward strip, not a threat to it.

What Does the July 22 Outcome Signal for the ERCOT 2027 Forward Strip?

The ERCOT North hub Cal 2027 forward strip printed at about $43.92 per MWh on June 25, 2026 and $44.28 per MWh on June 24, 2026, with implied heat rates near 12.73 and 12.94 respectively, per a Vistra/TXU ERCOT Market Snapshot dated June 26, 2026. ERCOT's own Summer 2026 Markets Outlook, filed May 2026, describes forward settlement prices for the 2026 through 2030 strip clustering in the mid-$50s per MWh. That places Cal 2027 at the low end of the visible curve, and the July 22 peak-day outcome is consistent with why the market has priced it there.

The EIA baseline view is slightly higher. EIA's February 2026 Short-Term Energy Outlook forecast average ERCOT North hub wholesale prices of $47.39 per MWh in 2027. In a high-demand scenario where 2026 and 2027 load growth ran 50% above baseline (driven largely by data centers), EIA modeled ERCOT prices 78.9% higher, or roughly $84.79 per MWh, per Utility Dive's coverage of the EIA analysis. The July 22 peak-day outcome is a modest vote against the high-demand scenario. If 91,308 MW clears at $30 per MWh, the marginal-cost story implicit in the baseline $47 forecast is intact.

None of this is a call on what 2027 wholesale prices will actually do. It is a read on what the observable data is currently telling the forward strip. As of early August 2026, the forward strip is closer to the low-$40s than the mid-$80s.

How Does This Read Through to Texas Commercial Fixed Rates?

A commercial fixed-rate plan in the ERCOT market has two big cost pieces. The energy component tracks the wholesale forward strip and Henry Hub gas. The transmission and distribution component covers TDU delivery charges plus 4CP demand allocations. The July 22 outcome moves the energy component only. It does not relieve the 4CP transmission exposure a record peak day creates for 2027 (that is covered in the sibling article, ERCOT Set a 91,308 MW All-Time Peak: 2027 Commercial Transmission Charges).

Where TxCP's live catalog data confirms the signal: as of the August 2, 2026 scrape, the active commercial plan catalog holds 1,000 plans across five TDU territories at a market average of $0.0880 per kWh. Long-term contracts (roughly 24 months and up) average $0.0741 per kWh with a median of $0.0698. Short-term contracts (roughly 12 months and under) average $0.1024 per kWh with a median of $0.0990. That 38% short-vs-long premium is unusually wide, and it means REPs are still asking buyers to pay a premium for the option to re-price. A quiet peak-day outcome and a Cal 2027 forward strip anchored in the low $40s per MWh both argue that some of that premium is available to a buyer willing to sign 2027 fixed rates now.

For a commercial buyer with a contract expiring between now and mid-2027, three concrete actions follow from a passing Peak-Day Price Test.

1. Ask your broker or REP for a Cal 2027 fixed-rate quote and check the implied energy component against the low-$40s per MWh forward strip.
2. Do not confuse energy relief with transmission relief. The 4CP exposure the July 22 peak set for your 2027 transmission bill is a separate line item that requires its own load-shaping response.
3. Sign carefully into 2027 rather than into 2028 or later, because the EIA high-demand scenario, if it starts to be confirmed by data-center interconnection queue actuals, prices back into the forward curve first at the 2028 tenor.

Related market reads from the last two weeks: Henry Hub prompt-month futures fell to $2.70, a buyer window for Texas commercial fixed rates, and Texas short-term commercial electricity plans now cost 50 percent more than mid-term contracts.

Data Sources and Methodology

Wholesale prices sourced from S&P Global Commodity Insights (July 21-22, 2026 ERCOT North hub day-ahead and real-time coverage). Peak-demand data from ERCOT operational reporting and ERCOT's April 15, 2026 preliminary long-term load forecast release. Cal 2027 forward strip and heat rate from a Vistra/TXU ERCOT Market Snapshot dated June 26, 2026, summarizing ICE forward power prices for ERCOT North 345 kV hub delivery. EIA forecast figures from the February 2026 Short-Term Energy Outlook, as reported by Utility Dive. TxCP catalog figures from the August 2, 2026 scrape of the active commercial plan set. Aggregate market data only. No per-REP rates are published here.

Frequently Asked Questions

What were ERCOT wholesale electricity prices during the July 22, 2026 all-time peak?

Real-time North hub prices stayed under $30 per MWh during the peak hour, and day-ahead on-peak prices settled at about $75.98 per MWh on July 22 (versus $68 per MWh on July 21), per S&P Global Commodity Insights. The peak load was 91,308 MW.

Why did ERCOT wholesale prices stay so low despite the record demand?

Three factors compressed the peak-hour price: strong ERCOT solar and battery output through the afternoon peak (25-plus GW solar and 15-plus GW batteries), moderate Henry Hub gas near $3.29 per MMBtu, and comfortable operating reserves that never triggered the ORDC scarcity adder.

What is the ERCOT 2027 forward strip trading at right now?

The ERCOT North hub Cal 2027 forward strip printed at about $43.92 per MWh on June 25, 2026 (heat rate near 12.73), per a Vistra/TXU ERCOT Market Snapshot dated June 26, 2026. That is at the low end of ERCOT's visible 2026-2030 forward curve, which clusters in the mid-$50s per MWh.

Should Texas commercial buyers lock in a 2027 fixed rate now?

A passing Peak-Day Price Test on July 22 is a bullish confirmation for the current forward strip, and the 38% short-vs-long premium in TxCP's live catalog suggests REPs are still charging for an option to re-price. Buyers with contracts expiring between now and mid-2027 have a reasonable window to price the Cal 2027 energy component against a low-$40s per MWh forward strip. The 4CP transmission exposure the peak set is a separate line item that requires its own load-shaping response.

Does the July 22 peak lower my 2027 transmission bill?

No. The July 22 outcome moves the energy component of a fixed-rate plan, but the record peak sets 4CP transmission allocations for 2027. Transmission charges are billed separately and require their own load-shaping response. See the sibling article on 2027 commercial transmission charges for the transmission math.