NWPPA Morning Brief

NWPPA Morning Brief - Thursday, June 18, 2026

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NWPPA Morning Brief — Thursday, June 18, 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_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's open meeting takes up large load interconnection and PJM co-location. Senator Lummis introduces legislation to put data center grid access under federal oversight. Oregon's governor declares a statewide wildfire emergency. A Reno Area Fire knocks out power to roughly 70,000 NV Energy customers. Seattle City Light proposes its steepest rate increases in recent memory. A Vista pauses a 500 megawatt data center negotiation after community pushback, and Interior pays Inventergy $765 million to walk away from offshore wind leases. Today's briefing is brought to you by the Northwest Public Power Association. Stronger workforce, greater influence, informed decisions. Serving community-owned electric utilities across the West since 1940.

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The story I'm watching closest today is FERC's Open Meeting. The Large Load Interconnection Rulemaking is the most consequential pending action for public power utilities managing hyperscaler demand. And the DOE jurisdictional assertion underneath it is the part that deserves real scrutiny. If FERC writes the rule broadly, it narrows the space consumer-owned utilities have historically had to structure their own large load tariffs on their own terms. The Lummus bill moves in the same direction from the legislative track, which means this isn't a one-agency story anymore.

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And both tracks are moving simultaneously, which is the operational reality utilities need to plan around now. The 100 megawatt threshold in the Lumis bill is the number your interconnection team should have on the wall.

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Let's start with FERC's open meeting today. The two items on the agenda, large load interconnection and PJM co-location, frame the federal posture on hyperscale demand more clearly than anything FERC has done in the last two years. The interconnection rulemaking sits on top of DOE's assertion that data center and AI growth has outpaced state regulatory regimes, giving FERC the jurisdictional hook. The PJM co-location item, generation paired directly with a single large customer behind the meter, is a separate structural question, but the two together signal that FERC is moving to govern both ends of the hyperscaler equation. For Western public power, the question is how broadly the final rule is written. A narrow rule preserves local flexibility. A broad one sets federal standards that flow into every large load tariff in the West.

SPEAKER_01

The co-location piece is worth flagging separately for resource planners. Behind the meter generation that bypasses the distribution system changes the load math utilities are working from. If FERC's PJM order sets a template, Western utilities will be managing that same dynamic in their own queues before long. Watch what FERC actually orders today, not just the agenda description.

SPEAKER_00

Moving to the Loomis bill, the Power Up Act puts the federal large load picture on a second track. The bill directs FERC to issue standardized interconnection procedures within 18 months for any facility with peak demand of 100 megawatts or more. The state authority carve out for sighting and retail rates is the line that matters for consumer-owned utilities. It's the boundary between federal standardization and local control over how customers pay. Whether that line holds in a final rule is the question worth tracking as this moves through the Senate.

SPEAKER_01

The 18-month clock is also real. If FERC is already in rulemaking and Congress is pushing a parallel deadline, the timeline for utilities to shape their own large load frameworks is shorter than it might look. Public power's voice in the comment process on the FERC rulemaking is the near-term lever.

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Turning to the Avista pause, Avista announced June 12th it has stopped energy service negotiations with a 500 megawatt data center developer in Spokane County after hearing concerns from customers, community members, and local leaders. CEO Heather Rosentrader framed it as a need for broader, coordinated planning. A Vista's stated principles are notable. Existing customers will not pay the costs of serving a new large customer. Engineering studies must be completed before service begins, and any project must deliver net benefits to existing customers. That's a public articulation of cost shift protection that a lot of utilities are still working out internally.

SPEAKER_01

The pause is the important operational signal here. A memorandum of understanding was already in place, and community engagement gaps still stopped the process. For any utility currently in early stage conversations with a hyperscaler, the lesson is that the community engagement timeline needs to start much earlier than the technical study timeline.

SPEAKER_00

Over to the Montana Northwestern Tariff Case. Community, conservation, and indigenous-led organizations have filed for formal party status, the standing to participate in, and contest the proceeding in Northwestern Energy's data center tariff case before the Montana Public Service Commission. The core dispute is transparency. Petitioners argue that confidential contracts shield terms that could allow cost shifts onto residential customers. The tariff protections they're seeking, capacity commitments with penalties, collateral requirements if a data center exits, minimum demand payments, are the same levers every utility facing large load requests will eventually have to write into its own rate structure.

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Montana is now a live laboratory for how these protections actually get codified. Whatever the Commission decides on transparency and cost shift provisions will be cited in proceedings across the West. Watch the Commission's ruling on intervention. That's the first procedural gate.

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Shifting to the wildfire picture, Oregon's governor declared a statewide wildfire emergency on June 16, citing record-low snowpack, persistent drought across nearly half of Oregon's counties, and a hotter, drier summer forecast. The declaration prepositions forestry, the state fire marshal, emergency management, and the National Guard through the end of fire season or December 31st. For Oregon Public Power, this elevates the immediate salience of PSPS decision frameworks, the controlled shutoff of lines when fire conditions spike, vegetation management in transmission corridors, and the insurance and liability exposure that fire season conditions place on utility infrastructure.

SPEAKER_01

The Reno event the same day makes the timing stark. NB Energy de-energized lines across Washoe County as an emergency measure while crews worked a 30-acre fire, and roughly 70,000 customers lost service. That is protective de-energization being applied in the field right now at the start of the 2026 season. Oregon public power utilities should be stress testing their own PSPS protocols against a similar scenario.

SPEAKER_00

On the wildfire liability front, the Hawaii $4 billion Maui settlement is a benchmark. Roughly 450 lawsuits resolved through a state-led multi-party structure. Utilities, insurers, government, and other defendants all part of the allocation. The Sightline Institute analysis published this week documents that Pacific Northwest utilities are already increasing wildfire mitigation spending substantially, and some are pushing for state-level liability limitation measures in Oregon and Washington. The legislative debate around those caps is one to track through the next session.

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The settlement architecture is what Western utilities should be studying. How liability gets allocated among multiple defendants in a multi-party resolution is the structural question that will shape how future Western wildfire claims get managed. $4 billion in Maui sets a reference point that will show up in every state level negotiation going forward.

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Next up, Seattle City Light. The utility is proposing some of the steepest multi-year rate increases in its recent history, driven by rising capital costs, infrastructure investment, debt service, and wholesale power expenses. As a consumer-owned municipal utility governed by the Seattle City Council, this moves through public rate setting rather than a state commission, putting affordability and the pace of system reinvestment directly in front of elected officials. The case is a bellwether because large public power utilities and PUDs across the Northwest face the same cost pressure stack.

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How the Council responds and how customers react publicly will shape how peer utilities frame their own rate conversations. If Seattle absorbs significant political backlash, it affects the runway other Northwest utilities have when they bring similar proposals forward. Watch the council hearing schedule.

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Moving to the Interior Invenergy offshore wind story. Interior paid $765 million to terminate four offshore wind leases in the New York Bight, off Central California and in the Gulf of Maine. The funds are being redirected to natural gas-fired plants in the Midwest and to geothermal projects in the western United States. The geothermal redirect is the piece with potential regional relevance. Western geothermal projects are in the development pipeline for several public power resource portfolios, and how Interior structures the redirected funding will determine whether public power developers can access it.

SPEAKER_01

The offshore wind cancellations themselves don't move Western resource planning. But if Interior's geothermal redirect includes competitive solicitations, public power developers need to be watching the program design closely. The funding is real. The access terms are what matter.

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Turning to the Centralia Unit 2 order. DOE has directed Transalta's Centralia Unit 2 in Washington State to remain available through September 13th under emergency authority, the power to compel a generator to stay online when grid reliability is at risk. Energy Secretary Wright has also signaled a broader posture of maintaining coal generation in the Northwest for summer reliability, consistent with DOE's use of this authority at other facilities this season. These orders have become a recurring pattern. The reliability need is real, and they also reflect the administration's preference for keeping coal capacity online. The open question that has not gone away is whether these aging, near-retired units can actually generate reliably at scale when called.

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That unit's availability through mid-September factors directly into summer capacity margin planning. The secretary level framing is context. The unit commitment is the number your operations team needs.

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This is a New York document, but the financial tools it evaluates are the same ones Western state agencies and public power entities are weighing for advanced nuclear projects, including successors to the carbon-free power project concept.

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Treat it as a comparative reference, not a development that moves Western projects on its own. But if your IRP includes advanced nuclear pathways, the paper's assessment of barriers to commercial viability is worth the read.

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On the Texas ERCOT story, the Public Utility Commission of Texas is scheduled to vote on ERCOT's proposal to overhaul its large load interconnection approval process. ERCOT's vice president said the existing process was not designed for the volume of hyperscaler requests the grid has been absorbing. Texas is outside NWPPA's geography, but how Texas decides to determine whether a hyperscaler request is firm enough to count in planning is exactly the question Western utilities are now answering in their own queues.

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The PUCT vote is a direct precedent signal. Western state commissions will cite whatever Texas decides. Watch the vote outcome and the firmness of request standard it sets. On pricing, Front Month Henry Hub Natural Gas Futures were trading at $3.16 per million BTU on June 18th, down from $3.22. NYMEX WTI Front Month Crude Futures were trading at $75.15 per barrel, down from $76.75. For Western spot prices on June 17th delivery, Sue Muss Natural Gas was $1.35 per million BTU, and Mid-Columbia Power was $30 per megawatt hour. The 10-year Treasury yield was 4.43% on June 16th, down from 4.47%. Comex Copper settled at $6.41 per pound on June 17th, down from $6.48.

SPEAKER_00

One to watch, the NWRFC Hydrology Signal. NWRFC's current percent of average figures continue to track at observed levels for Bonneville Dam and Lower Granite Dam as the basins move through runoff season. Members with hydropower exposure should keep tracking NWRFC updates.

SPEAKER_01

The hydrology picture is largely set at this point in the season, but given Oregon's drought declaration and the regional fire risk, any deviation in late season runoff has more operational consequence than it would in a normal year.

SPEAKER_00

The through line today is federal jurisdiction moving faster than utilities can respond. FERC's Open Meeting, the Lummus Bill, the DOE Centralia Order, all of them are federal actors asserting authority over decisions that consumer-owned utilities have historically managed locally. The Montana and Avista stories show the community dimension of large load decisions hasn't gotten easier either.

SPEAKER_01

And the wildfire picture is not a background condition this summer. It's an active operational constraint right now. Oregon's declaration, the Reno event, the Hawaii settlement, the sightline analysis. That's a lot of convergent signal for utilities that haven't fully stress tested their fire season protocols. Get that work done now. That's your NWPPA morning brief for Thursday, June 18th, 2026. Sources for every story are linked in the show notes. Tomorrow is the Juneteenth holiday, so we'll be back Monday morning. Have a great weekend. Keep the lights on.