NWPPA Morning Brief

NWPPA Morning Brief - Wednesday, August 19, 2026

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NWPPA Morning Brief — Wednesday, August 19, 2026

In today's brief:

Top Federal Developments

Top Regional / State Developments

Pilot notice: AI-generated daily briefing. Verify before acting on it.

Feel free to reach out if you have comments or concerns.

SPEAKER_00

Before we begin, a quick note. The NWPPA morning brief is Generative AI, daily intelligence on the federal and Western developments shaping public power. It isn't human-reviewed before publication, so treat it like any AI tool and verify what you'll act on or cite. Sources are in the show notes. You're listening to the NWPPA morning brief. On today's brief, DOE extends its emergency call order for J.H. Campbell through November. DOE disperses $271 million to PGE for Diablo Canyon under the Civil Nuclear Credit Program. ISO New England asks FERC to tighten oversight of aging transmission spending. Oregon regulators open comment on Idaho Powers' proposed $154 million sale of its Oregon territory to a cooperative. A new wildfire risk report puts $1.4 trillion in reconstruction value at risk across Western states. And two new bills in Congress touch data center taxation and utility executive pay. Today's briefing is brought to you by NWPPA's Northwest Innovations in Communications Conference, September 21st to 24th in Walla Walla, Washington. Four days of storytelling, strategy, and connection for the communicators of public power. Register at NWPPA.org.

SPEAKER_01

The DOE Campbell Order is the story I'd lead with. DOE has now used its Section 202C Emergency Authority, the power to compel specific plants to stay available past planned retirement, at both a MISO coal plant and at Transalta Centralia in Washington. That's a pattern, not a one-off. Any Western utility managing a scheduled coal retirement inside a region NERC has flagged for adequacy risk now has a live federal intervention scenario to factor into its planning.

SPEAKER_00

And the timing matters. The new order runs through November 14, which means the question of what comes next hits squarely during peak planning season for the next resource year.

SPEAKER_01

Let's start with the J.H. Campbell Order. DOE issued this on August 17th, directing MISO and Consumers Energy to keep the 1,420 megawatt Campbell coal plant in Michigan available through November 14th. This extends an emergency directive first issued in May 2025, days before Campbell's scheduled shutdown. Energy Secretary Wright cited NERC's January 2026 finding of high energy shortfall risk across MISO over the next five years. These orders are becoming a recurring pattern, and they carry both a reliability rationale and a clear administrative preference for keeping coal capacity online. The open question is whether aging, near-retired units can actually generate reliably at scale when called upon.

SPEAKER_00

That last point is the one worth sitting with. The order compels availability. It doesn't guarantee performance. And for any Western utility watching its own retirement schedule against a backdrop of NERC adequacy flags, the federal intervention option is now clearly on the table, regardless of state policy or local planning timelines.

SPEAKER_01

Moving to the Diablo Canyon payment, DOE dispersed $271 million to PG ⁇ E under the Civil Nuclear Credit Program, a $6 billion federal fund created in 2022 to preserve existing reactors for extended operations at Diablo Canyon Unit 1. Unit 2 becomes eligible after the 2025 award year audit clears. NRC approved 20-year license extensions in April, keeping both units online through 2044 and 2045. Diablo Canyon generates roughly 18,000 gigawatt hours a year, about 9% of California's electricity, so its continued run is a real factor in CAISO resource adequacy and in the price signals that flow to Western trading partners.

SPEAKER_00

The disbursement detail matters here. This program moved from award announcements to actual cash, which is a different kind of signal for any Western utility with an aging nuclear asset weighing federal support against retirement economics. The civil nuclear credit program is now demonstrably liquid.

SPEAKER_01

Turning to the ISONE transmission proposal, ISO New England filed with FERC on August 17th, asking for a new framework to review what are called asset condition projects, the category of transmission work that owners select and build primarily to replace aging infrastructure, often with limited outside scrutiny before costs land in rates. ISONE's stakeholders approved this unanimously. The grid operator's role would be advisory, but its findings could give stakeholders grounds to challenge cost recovery. Senator Blumenthal separately asked FERC to increase oversight and introduced legislation that would deem a transmission rate increase unaffordable, under the just and reasonable standard, the baseline legal test for whether a rate is acceptable, if it would raise retail rates by 5% or more.

SPEAKER_00

The Western relevance is methodology, how FERC rules on the ISO NE proposal sets the analytical framework for how aging infrastructure transmission spending gets scrutinized in FERC jurisdictional proceedings everywhere. Public power utilities across the West that are cost allocated into large transmission replacement programs will want to track this one closely. Over to the Oregon PUC proceeding. The Oregon Public Utility Commission opened public comment on Idaho Power's proposed sale of its Oregon distribution system to Oregon Trail Electric Cooperative with a base price of $154 million. The deal would transfer 20,000 customers in Malhir, Harney, Baker, and Wallawa counties to OTEC. Closing is expected in early 2027. Idaho Power would exit Oregon retail service but retain its Oregon generation and transmission assets, including the Boardman to Hemingway line.

SPEAKER_01

This is structurally significant for the region. An IOU service territory converting to cooperative ownership is not common, and the mechanics of how this closes, including the multi-year wholesale supply agreement back to Idaho Power, will be closely read by anyone thinking about similar rural service area reorganizations. The Oregon PUC comment process is where the terms get tested publicly.

SPEAKER_00

Shifting to the wildfire risk report. Cotality's 2026 wildfire risk assessment finds more than 2.5 million properties across the 10 most exposed western states carry moderate or greater wildfire risk, representing nearly $1.4 trillion in combined reconstruction cost value. California accounts for 1.28 million at-risk properties and $850 billion in reconstruction value, but roughly half the at-risk properties sit outside California. Colorado and Texas together represent nearly $560,000 properties and $252 billion in reconstruction value.

SPEAKER_01

For public power utilities in Oregon, Idaho, and Arizona, these figures quantify the exposure that's already driving insurance market tightness and mitigation investment. The more pointed question is how these totals feed into the wildfire liability debate in California legislation and Ninth Circuit case law. Because the legal and insurance frameworks being shaped in California don't stop at the state line. Next up, the pricing numbers. Front month Henry Hub Natural Gas Futures were trading at $2.84 per million BTU on August 19th, up from $2.72. NYMEX WTI Front Month crude futures were trading at $84.66 per barrel, up from $84.18. On Western spot prices for delivery August 18th, Sumas Natural Gas was at $2.80 per million BTU, and Mid-Columbia Power was at $58 per megawatt hour. On the capital side, the 10-year treasury yield was 4.72% on August 17th, up from 4.68%. COMEX Copper settled at $6.42 per pound on August 18th, down from $6.48.

SPEAKER_00

On to the congressional scan. Representative Salinas introduced the Data Center Community Reinvestment Act on August 13th, which would impose a one cent per kilowatt hour excise tax on electricity used by data centers with more than one megawatt of capacity. Revenue would go toward housing, conservation, energy, and transportation programs. DOE's own numbers suggest U.S. data center electricity use could reach 325 to 580 terawatt hours by 2028. So the tax base being targeted is not small.

SPEAKER_01

The direct operational question for public power is layering. A federal excise tax on top of state-level large load rate design changes the total delivered cost for hyperscale customers and could shift siting decisions. Utilities that are actively designing or renegotiating large load tariffs right now are the ones for whom this bill's trajectory matters most, even if its passage odds are uncertain.

SPEAKER_00

The bipartisan utility executive bonus bill from Senators Blumenthal and Hawley is primarily an IOU story. It would prohibit executive bonuses in years when rates rise faster than inflation. But the congressional temperature it reflects is one public power operates inside. Affordability pressure at the federal level shapes the regulatory environment for the whole sector.

SPEAKER_01

Turning to the Inveris Large Load Readiness Report, Inveris graded U.S. regional grid operators on their preparedness to interconnect large loads following FERC's June 2026 large load order. The Western angle is how CAISO and the Emerging Markets Plus footprint stack up against other operators on Q reform, cost allocation for large load driven upgrades, and interconnection timelines. Developer citing decisions follow those grades.

SPEAKER_00

If Western regions rank lower on those criteria, load growth forecasts already stressed by data center inquiries could tighten further as developers route projects toward higher-rated regions. That's a resource planning signal, not just a market structure one.

SPEAKER_01

On the next era Dominion merger, Massachusetts Energy Secretary Tepper is calling on FERC to heavily scrutinize the merger's impact on ratepayer bills, market power, and reliability. She joins Virginia's governor and the South Carolina PSC in the proceeding. For Western public power, this is a methodology case. How FERC weighs market power concentration and ratepayer effects here becomes the analytical playbook for future utility consolidations that could touch Western service territories.

SPEAKER_00

And the next era Commerce Japan gas deal in Texas and Pennsylvania. 10 gigawatts of new gas generation with a foreign government as a financing partner is unusual structurally. The direct Western effect is limited by geography, but supply of that scale entering eastern markets can influence national gas basis signals that flow west.

SPEAKER_01

One to watch. And this is the story I'd keep on the dashboard. The DOE 202C pattern is accelerating. Two orders in two different regions, both citing NERC adequacy findings, both holding coal capacity past planned retirement dates. NERC has flagged adequacy risk across multiple Western subregions. The question is not whether DOE would use this authority again, the record now says it will. The question is, which utility, in which region, under which NERC finding, is next in line for a federal directive that overrides its retirement schedule.

SPEAKER_00

And that question lands directly on integrated resource planning. A retirement timeline that a utility has built its next 10 years around can be reopened by a federal emergency order. That is a genuine planning variable now, not a theoretical one. The Campbell extension running to November 14 means the next decision point on that plant, extend again or not, lands right at the start of winter planning season.

SPEAKER_01

Today's brief covers a lot of ground, but the through line is federal authority expanding into spaces utilities used to control. Retirement timing, transmission cost scrutiny, nuclear subsidy flows. The J.H. Campbell order is the sharpest example, but Diablo Canyon and the ISO NE transmission proposal are part of the same structural shift. Watch what FERC does with the ISO NE framework and what DOE signals on Campbell before November.

SPEAKER_00

Sources are in the show notes. Verify what you'll act on. That's your NWPPA morning brief for Wednesday, August 19th, 2026. Sources for every story are linked in the show notes. We'll be back tomorrow morning. Keep the lights on.