NWPPA Morning Brief

NWPPA Morning Brief - Thursday, August 20, 2026

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NWPPA Morning Brief — Thursday, August 20, 2026

In today's brief:

Top Federal Developments

Top Regional / State Developments

AI and Large Load Demand Radar

Worth Knowing

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

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

SPEAKER_01

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, Washington's wildfire costs hit $207 million with fire season still running. BPA's latest financial forecast shows net revenues declining since May. The NRC holds its first ever mandatory hearing on an SMR construction permit. PJM files a conditional reliability framework for large new loads that sets a FERC precedent, and the Western Interconnection Regional Advisory Body advances a common large load interconnection template. Plus, California's new wildfire landscaping rules, a 32% rate case in Wyoming, and the Quantum Guard Act targeting grid cybersecurity. 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.

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The BPA Financial Forecast is the story I'd put in front of every wholesale customer today. This is the third official forecast for fiscal year 2026, and net revenues are moving in the wrong direction since May. That's not a rate change yet, but it reframes the cost recovery conversation heading into the next rate period. Utilities on long-term federal power contracts need to understand what's driving that decline before it surfaces in a formal proceeding.

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And the timing matters. Mid-year forecasts that trend down tend to harden spend discipline conversations at BPA faster than any policy directive. Watch what comes next in their financial reporting cycle.

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Let's start with the federal picture. The NRC held its first mandatory hearing on an SMR construction permit last week, specifically the Tennessee Valley Authority's application for the Clinch River BWRX 300 reactor. NRC staff had already recommended approval in a June safety evaluation, so this proceeding is uncontested. No outside parties are challenging it. The hearing record stays open until August 27th. Then commissioners issue a final permit decision. What makes this consequential for Western utilities is the sequence itself. From safety evaluation through mandatory hearing to permit decision, Clinch River is setting the licensing template that every subsequent SMR applicant will follow.

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A clean resolution compresses the perceived licensing risk in advanced nuclear resource planning, and that matters for IRPs that are starting to treat SMRs as a real option rather than a placeholder. A delayed or contested outcome would push that timeline out and inject uncertainty that gets priced into planning assumptions. The August 27th record closed date is the next marker worth watching.

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Turning to the Quantum Guard Act, Senators Kuhnz and Rounds introduced this bill on August 14th, and the structure is worth understanding. It would direct FERC to weigh quantum-related risks when reviewing proposed grid reliability standards and to consider requiring post-quantum cryptography, encryption methods designed to resist attacks from quantum computers, in both information technology and operational technology systems. DOE's Cybersecurity Office would have one year to stand up a testing sandbox and deliver a separate vulnerability study to Congress.

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The practical implication for public power utilities is that post-quantum cryptography moves from a research topic into the FERC jurisdictional reliability standards conversation. If this bill advances, compliance obligations follow. That's a planning horizon question, not an immediate action. But it's one that belongs in the cybersecurity roadmap now, not after a final rule lands.

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Shifting to PJM. The interconnection filing PJM made with FERC on August 13th creates a framework worth tracking closely in the West. For large new electricity users above 50 megawatts connecting after June 2027, PJM would allow them to enter service before sufficient new generation exists. But with a hard condition, uncovered demand can be curtailed unless the customer supplies its own power. Bring your own power or accept curtailment priority. That's the core construct.

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This is a PJM filing, not a Western action, but FERC precedent travels. The Western Interconnection Regional Advisory Body is actively building a large load interconnection template right now. If FERC accepts the curtailment priority construct, expect it to surface in that work and in Western utilities' own large load tariff conversations. The question is whether this becomes the default framework the industry converges on.

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Moving to Washington State, the wildfire cost figure is stark. Twenty active fires have run up $207 million in firefighting costs over roughly a month. That's already more than two-thirds of what the State Department of Natural Resources spent on wildfires over the entire last fiscal year. More than 770,000 acres have burned in 2026, third highest annual total on record, and fire season isn't over. DNR will request emergency federal funds under the Clark McNary Act.

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For Washington Public Power Utilities, this isn't background context. It's the operating environment right now. Mutual aid demands, transmission corridor exposure, and de-energization decisions are all being shaped by the same conditions driving that spending number. And that $207 million figure is still climbing.

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On the California front, the state adopted new wildfire landscaping rules requiring homeowners in fire-prone areas to limit plants within five feet of their homes. That's the home ignition zone concept, targeting the mechanism by which embers turn a wildland fire into a structure fire, moving from best practice into enforceable state law.

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This doesn't shift utility liability directly, but it changes the factual record in future proceedings about how ignition and spread occurred. And it establishes a regulatory precedent that other Western states with serious fire exposure are going to weigh. The public power angle is the liability picture. More actors with enforceable obligations creates a different landscape in any future dispute about causation.

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Next up, the Black Hills rate case in Wyoming. Black Hills Energy has asked the Wyoming Public Service Commission to approve a $5.1 million annual increase for about 2,600 customers in Northeast Wyoming, the utility's first base rate case there since 2014. A base rate case is a formal proceeding where a utility asks state regulators to reset foundational rates to recover infrastructure and operating costs accumulated since the last reset. If approved, the average residential customer sees roughly $32 more per month, which works out to about 32%.

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The cost drivers Black Hill cited infrastructure upgrades, generation mix changes including wind and gas, rising costs at existing coal plants, workforce compensation, that's a nearly universal list for utilities that haven't reset rates in over a decade. For Wyoming public power utilities, this case is a real-world data point on what state regulators will accept when all of those cost pressures are bundled into a single filing after a long interval.

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Over to the Western market structure story. The Western Interconnection Regional Advisory Body advanced its large load interconnection framework on August 13th, focusing on the second section of a publicly available requirements template for connecting data centers and other major users across the Western grid. Additional work runs through November, with a public webinar on December 3rd. This isn't a mandatory Western standard, it's a template utilities and regulators can adopt to improve consistency.

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The Pennsylvania Data Center Executive Order, signed by Governor Shapiro on August 18th, adds important context here. Facilities over 25 megawatts are excluded from the state's fast track permitting program and must cover associated grid infrastructure costs. That's the second governor-level action in recent months, putting grid costs squarely on the developer side of the ledger. Western utilities doing their own large load-cost allocation work now have a growing set of state-level models to reference.

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On the BPA front, the third official financial forecast for fiscal year 2026 shows end-of-year net revenues declining since the May report. The forecast doesn't change rates, but for wholesale customers on long-term federal power contracts, a mid-year trend moving downward is the kind of signal that reshapes the cost recovery conversation heading into subsequent proceedings. Watch BPA's next financial reporting release for whether the trajectory continues.

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And the MISO Solar Edition, worth noting quickly, Bloomberg NEF data shows MISO added 7.45 gigawatts of solar between April 2024 and March 2025, compared to 3 gigawatts at PJM. MISO is now the largest U.S. grid by electric supply. Regional generation mixes are reordering faster than most planning cycles anticipated, and that has implications for interregional transfers and resource adequacy comparisons across the Western interconnection.

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On pricing, Front Month Henry Hub Natural Gas Futures were trading at $2.77 per million BTU today, down from $2.84. NYMEX WTI Front Month Crude Futures were trading at $0.87.26 per barrel today, up from $84.65.

SPEAKER_01

Western spot prices for delivery August 19. Sumas Natural Gas was $2.98 per million BTU, and Mid-Columbia Power was $67.25 per megawatt hour. The 10-year Treasury yield was 4.71% on August 18. COMEX Copper settled at $6.42 per pound on August 19, down from $6.49.

SPEAKER_00

For the one to watch, keep the Clinch River NRC proceeding at the top of the tracking list. The hearing record closes August 27th and the Commissioner decision follows. This is the first SMR construction permit review to reach this stage under the streamlined mandatory hearing process. A clean outcome validates the licensing template. A contested or delayed one resets the advanced nuclear planning calculus for every utility that has started treating SMRs as a real resource option.

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The sequencing risk cuts both ways. Western utilities that have SMRs in their IRPs are implicitly relying on this process working as designed. If the NRC moves efficiently from the August 27 close to a permit decision, that's a proof point. If it stalls, that's a signal that the streamlined process has limits, and that the timeline assumptions built into resource plans may need adjustment.

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Today's briefing has three threads that connect directly to cost exposure. The BPA forecast, the wildfire spending in Washington, and the large load frameworks moving at both FERC and the Western Interconnection Regional Advisory Body. Each one has a near-term decision point attached. That's a dense set of moving parts for a single week.

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And the Clinch River decision is coming fast. August 27 is one week out. The advanced nuclear picture for Western resource planning could look meaningfully different before September starts. That's your NWPPA morning brief for Thursday, August 20th, 2026. Sources for every story are linked in the show notes. We'll be back tomorrow morning. Keep the lights on.