NWPPA Morning Brief

NWPPA Morning Brief - Tuesday, August 18, 2026

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NWPPA Morning Brief — Tuesday, August 18, 2026

In today's brief:

Top Federal Developments

Top Regional / State Developments

AI and Large Load Demand Radar

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, FERC sets a cross-regional cost allocation precedent with direct implications for EDAM and Markets Plus. PJM moves to require data centers to ride through grid disturbances after 3,800 megawatts tripped offline in Virginia. Senate Democrats file water utility cybersecurity legislation. DOE streamlines national lab operations, and Q2 earnings flag equipment backlogs with one mid-size gas engine platform coming back to market. 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_00

The FERC cost allocation order is the one I'd anchor today's briefing on. FERC just ruled that one region's needs can justify forcing upgrades and assigning costs inside another region's footprint. That is precisely the question Western utilities will face as interregional transfer projects advance under E Dam and Markets Plus. This order gives FERC's answer, and it is not a narrow one.

SPEAKER_01

And the dollar figures make it concrete. $904 million assigned to a single utility for work that serves a neighboring grid. That is not a rounding error. Western utility executives building EE DAM and Markets Plus cost allocation models should be reading this order closely.

SPEAKER_00

Let's start with that FERC ruling and work through the full picture. The FERC Cross Regional Cost Allocation Order came down August 14th, and it resolves a specific question. Who pays when one grid operator's reliability plan requires physical infrastructure inside a neighboring operator's territory? FERC approved MISO's approach, assigning Commonwealth Edison roughly $904 million in construction obligations, and rejecting competitive bidding for these projects. Two commissioners concurred separately to make the point explicit. The most cost-effective solution for one region's needs sometimes sits inside another region's footprint, and that is a legitimate basis for cross-border cost assignment. The projects come from MISO's high voltage backbone plan, approved in late 2024.

SPEAKER_01

The Western read on this is direct. EDAM and Markets Plus are both heading toward interregional transfer arrangements where the same question will surface: who pays for upgrades that enable transfers? And can costs be pushed across regional lines when benefits are demonstrated? FERC just showed its hand. The standard it applied here is benefits-based, not geography-based, and that framing travels.

SPEAKER_00

The next thing to watch is whether Western utilities and state commissions engage on what a comparable benefits showing would need to look like under EE Dams or Markets Plus cost allocation frameworks before any specific project triggers the question.

SPEAKER_01

Turning to the water cybersecurity bill, Senators Schiff and Klobichar introduced legislation that would give EPA explicit authority to set mandatory cybersecurity standards for drinking water and wastewater utilities. This follows coordinated attacks on at least 30 systems across 12 states. The bill would require large systems to undergo cybersecurity evaluations and compel utilities to remediate identified vulnerabilities. The sponsor has flagged the possibility of attaching it to a larger legislative package before year end.

SPEAKER_00

The political path is narrow. Prior mandatory water sector cyber rules were blocked by Republican state opposition and small utility groups, and the Senate Environment and Public Works Chair is calling for more resources rather than new mandates. So this is not a done deal. But for public power utilities that run combined water and electric operations, or that share operational technology vendors with water systems, the precedent question is real. If EPA style prescriptive cyber authority takes hold in water, the argument for similar authority over electric distribution systems follows naturally.

SPEAKER_01

If it attaches to a year-end package, this could move faster than the underlying politics suggest.

SPEAKER_00

Shifting to the DOE National Lab Directive update. DOE issued revised operating directives for its lab complex, described as removing outdated and duplicative field operation requirements based on more than 30 years of accumulated recommendations. The stated goal is letting the scientific workforce focus on core science and national security work rather than administrative process.

SPEAKER_01

For public power utilities with active cooperative research agreements at labs like the Pacific Northwest National Laboratory, Idaho National Laboratory, or the National Renewable Energy Laboratory, the practical question is whether streamlined field operation requirements change contracting timelines or cost share terms. DOE says the changes are administrative modernization. Whether that translates into faster project cycles or revised cost share structures on existing agreements won't be visible until the directives hit specific programs.

SPEAKER_00

Worth flagging to whoever manages those research partnerships. Not to act now, but to ask the question when their lab counterparts next engage.

SPEAKER_01

Over to the Q2 earnings picture. A utility dive review of more than two dozen earnings calls found utilities emphasizing project execution and ratepayer protection alongside data center demand growth. The supply chain headline is that one manufacturer is resuming production of a 10 megawatt medium-speed gas reciprocating engine platform it stopped making in 2022. The three major gas turbine makers are sitting on backlogs ranging from 35 to 116 gigawatts.

SPEAKER_00

The 10 megawatt engine platform coming back is a concrete signal for public power. That unit size fits cooperative and municipal load profiles in ways that utility scale gas turbines simply do not. If Western utilities have been watching the mid-size gas generation market go cold, this changes the procurement landscape, at least for the utilities that can tolerate the lead times those backlog figures imply.

SPEAKER_01

TD Cowan's framing is the other thread worth pulling. The conversation on Wall Street is shifting from growth to affordability and recovery. That pressure will land on public power rate design conversations too, even though the capital structure is different.

SPEAKER_00

NIMAX WTI Front Month Crude Futures were trading at $84.22 per barrel on August 18th, up from $81.72.

SPEAKER_01

For Western spot prices, delivery August 17th, SUMUS Natural Gas was at $2.62 per million BTU, with Mid-Columbia Power at $41.25 per megawatt hour.

SPEAKER_00

On the capital and materials side, the 10-year treasury yield was 4.68% on August 14th, up from 4.63. Comex Copper settled at $6.55 per pound on August 17th, down from $6.60.

SPEAKER_01

Next up, the PJM data center reliability story, and this one has direct Western implications. On July 22nd, approximately 3,800 megawatts of data center load tripped offline in Northern Virginia after a fault on a 230 kilovolt line in Dominion Zone. PJM called it the largest such event in its history. PJM recovered the system within nine minutes, well ahead of the NURC 30 minute standard. But PJM is now developing ride-through requirements. Standards that require large loads to stay connected and keep operating through grid disturbances rather than tripping offline for data centers and crypto mining facilities.

SPEAKER_00

Texas set similar standards earlier this year, and now PJM is heading the same direction. That is two major grid operators moving on this inside of one year. The Western question is whether WEC or KISO moves next, and how existing large load interconnection contracts in the West allocate retrofit costs if new ride-through requirements are imposed after the fact. Utilities that have already signed large load interconnection agreements need to know what their contracts say about compliance with new technical standards.

SPEAKER_01

The Virginia event also illustrates something that does not show up in standard resource adequacy planning. Nearly four gigawatts of load disappearing in seconds is a stability event, not just a demand management moment. If Western grids are absorbing comparable large load concentrations, the operational exposure is worth pressure testing.

SPEAKER_00

For the one to watch, I want to stay on that PJM ride-through development, but wide in the frame. What happened in Northern Virginia on July 22nd is the first large-scale empirical demonstration of what concentrated computational load can do to a transmission system when it trips simultaneously. PJM recovered fast, but the scenario where it does not recover fast enough, or where multiple faults cascade before ride-through standards are in place, is exactly the reliability risk Western utilities need to be modeling now as large load queues grow.

SPEAKER_01

The WEC and KAISO response timeline is the live variable. If either moves to propose comparable ride-through standards, utilities with pending or recently signed large load interconnection agreements face a near-term contract and compliance question. The window between when a standard is proposed and when it takes effect is where the cost and liability exposure gets determined. And that window is often shorter than utilities expect.

SPEAKER_00

The federal picture today runs a consistent thread. Cost allocation, cyber authority, lab contracting, supply chains, large load reliability. Each of those is its own work stream, but the through line is that the rules governing how Western utilities plan, build, and recover costs are in motion across multiple venues simultaneously.

SPEAKER_01

And the market design decisions, EDAM, Markets Plus, interregional transfers, are not waiting for those rules to settle. The FERT cost allocation order is a reminder that precedents being set in MISO and PJM today will constrain the design space in the West tomorrow. That's your NWPPA morning brief for Tuesday, August 18th, 2026. Sources for every story are linked in the show notes. We'll be back tomorrow morning. Keep the lights on.