NWPPA Morning Brief
A six-month pilot from NWPPA: a daily, 10- to 12-minute energy and policy intelligence briefing for community-owned electric utilities in the Western United States. New episodes publish every weekday morning, typically by 6:15 AM Pacific.
NWPPA Morning Brief
NWPPA Morning Brief - Friday, July 31, 2026
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NWPPA Morning Brief — Friday, July 31, 2026
In today's brief:
Top Federal Developments
- DOE Plans $100 Billion AI and Gas Complex at Former Kentucky Uranium Site — https://apnews.com/article/a4cf07af1b6776971dc5d609c996ca13
- Utility Consortium Endorses DOE 2026 Transmission Needs Study, Backs North Plains Connector — https://dailyenergyinsider.com/news/53132-utility-consortium-supports-does-2026-transmission-needs-study/
Top Regional / State Developments
- Flathead Electric Cooperative Completes Leadership Transition Amid Tighter Northwest Energy Outlook — https://flatheadbeacon.com/2026/07/28/transition-of-power/
- Maryland Regulators Cut Washington Gas Rate Request by More Than Half — https://psc.maryland.gov/news/2026/maryland-public-service-commission-denies-largest-portion-of-washington-gas-lights-rate-increase-request/
Pilot notice: AI-generated daily briefing. Verify before acting on it.
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 commits $100 billion to an AI data center campus on a former federal uranium site in Kentucky, powered by on-site gas and batteries. A utility consortium including A Vista, Portland General, Puget Sound Energy, and Northwestern Energy backs DOE's 2026 National Transmission Needs Study and the North Plains Connector. Flathead Electric Cooperative completes a leadership change while navigating a maxed-out federal hydropower allocation. Maryland regulators cut a major gas utility rate request by more than half. And Lake Powell sits at 38% of normal storage, keeping Glen Canyon Dam Hydropower under pressure. 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_00The Paducah story is the one I'd clear time for today. DOE isn't just redeveloping a site, it's field testing a model where federal land plus federally sited generation becomes the answer for very large AI loads. That repositions the interconnection conversation Western utilities are having with hyperscalers right now. The question isn't whether this specific Kentucky project affects the West directly. It's whether the federal site playbook spreads to surplus DOE properties out here, and how transmission cost allocation gets handled when it does.
SPEAKER_01And if standby and backup service from the surrounding grid ends up socialized regionally, that's where it lands on public power ratepayers. The shape of this project matters as much as the dollar figure.
SPEAKER_00Let's start with the federal picture. Walk me through Paducah.
SPEAKER_01The DOE Paducah announcement is the data center story that reframes the interconnection question for Western utilities. DOE is converting the former Paducah gaseous diffusion plant in Western Kentucky into a $100 billion AI data center campus with a purpose-built natural gas plant and battery storage supplying power on site. That's a fundamentally different posture than the model most Western public power utilities are working through today, where a hyperscaler knocks on the door and asks for service off the existing system. The federal site model keeps the load off the utility system by design. But it doesn't necessarily keep the transmission upgrade costs off the regional allocation process, the process by which upgrade costs are divided among utilities and ratepayers across the region.
SPEAKER_00The surplus DOE properties question is real in the West. There are former federal energy sites across the region, and if this Kentucky project validates the model, those sites become more attractive to hyperscalers who now have a federal alternative to utility service. That changes the negotiating dynamic. Some large customers may arrive at a public power utilities door with a federal site option already in hand. What DOE does on grid interconnection and cost recovery at Paducah will set precedent worth watching closely.
SPEAKER_01Turning to the transmission front, the North Plains Connector Consortium story puts named Northwest utilities on the record in a meaningful way. A Vista, Northwestern Energy, and Puget Sound Energy have signed non-binding memoranda to own shares of the roughly 420-mile up to 525-kilovolt high-voltage direct current line that would link the eastern and western interconnections across Montana and North Dakota. The full consortium also includes Great River Energy, Mincota Power Cooperative, and others. Their endorsement of DOE's 2026 National Transmission Needs Study strengthens the federal record supporting permitting and cost recovery for interregional projects.
SPEAKER_00For Western public power, the North Plains Connector is one of the very few interregional projects concrete enough to actually shape resource adequacy planning in the 2030s. That DOE endorsement matters because it becomes part of the administrative record cited in future Bonneville Power Administration and WAPA transmission proceedings. Utilities that aren't in the consortium should track how cost allocation gets structured if this line advances. Interregional projects have a way of distributing costs well beyond the signing parties.
SPEAKER_01Shifting to the regional picture. The Flathead Electric Cooperative Leadership Transition that took effect July 1st is more than a co-op personnel story. Longtime CEO Mark Johnson retired after more than 13 years leading Montana's largest electric cooperative, with COO Jason Williams stepping into the role. What makes this notable is the resource picture Williams is inheriting, a maxed-out federal hydropower allocation from the Bonneville Power Administration, rising equipment costs, and a strategic bet on natural gas as part of the co-op's forward-looking resource plan.
SPEAKER_00Flathead situation is the clearest public illustration we've seen recently of what happens when a Northwest cooperative hits the ceiling of its BPA preference allocation and has to source incremental supply on its own. That's not a flathead-specific problem. It's a resource adequacy question a growing number of preference customers are working through right now. The fact that a co-op of flathead size is going on record about this and choosing natural gas as the answer tells you something about where the options set actually lands when federal hydro runs out.
SPEAKER_01Over to Maryland, this one is out of region, but the scale of the decision is worth flagging. The Maryland Public Service Commission authorized roughly $38.1 million for Washington Gas and Light, less than half of the $82.5 million the utility requested in its natural gas rate case. State commissions under affordability pressure are demonstrating they will take significant reductions to gas utility filings.
SPEAKER_00The question for Western Public Power is whether that posture travels west. State PUCs handling gas distribution rate cases or cost recovery for gas fire generation have been watching each other closely on affordability. If a commission in a moderate demand state cuts a gas rate request by more than half, that's a data point in proceedings where public power utilities are seeking cost recovery for gas transportation service or gas-fired assets. Not a certainty, but a factor worth tracking as Western rate cases move forward. That's a sustained constraint, not a new development. But 38% of normal in late July means the pressure on Colorado River hydropower deliveries carries into fall planning. Worth having that number current as utilities finalize resource positions for Q4.
SPEAKER_01On the pricing front, Sioux Must natural gas spot prices for July 30th delivery were $2.34 per million BTU. Mid-Columbia power for that same delivery date was $56 per megawatt hour. Front month Henry Hub Natural Gas Futures were trading at $2.79 per million BTU on July 31st, up from $2.71. NineMex WTI Front Month Crude Futures were trading at $85.22 per barrel, up from $83.73.
SPEAKER_00On the capital side, the 10-year Treasury yield was 4.67% on July 29th, up from 4.61%. COMEX Copper settled at $6.49 per pound on July 30th, up from $6.44.
SPEAKER_01One to watch. The Western Federal Power Program scan surfaces, something I want to sit with. The North Plains Connector Consortium's endorsement of DOE's transmission study and Flathead Electric's public acknowledgement of a binding BPA allocation ceiling landed in the same briefing cycle. These aren't the same story, but they point at the same structural tension. BPA preference allocations are increasingly a hard constraint on cooperative and public power resource planning. And the answer to that constraint, whether it's a natural gas bet like flatheads or interregional transmission like the North Plains Connector, carries its own cost and risk profile that lands on ratepayers.
SPEAKER_00The timing of those two stories together does clarify something. The interregional transmission path and the on-system gas path are both being pursued simultaneously by utilities facing the same ceiling. The open question is how federal transmission policy, including what DOE does with the North Plains connector endorsement, and how WAPA and BPA handle future allocation decisions, interacts with the self-supply choices cooperatives are making right now. The federal and regional tracks aren't separate. They're on a collision course with the same resource adequacy gap.
SPEAKER_01That's the thread to pull heading into August. DOE is simultaneously proposing a federal site AI load model, endorsing interregional transmission and sitting above the allocation system that's already binding on Northwest cooperatives. How those three things interact in the next round of BPA rate proceedings and Western interconnection planning is the question.
SPEAKER_00And the Paducah precedent is the wild card. If the federal site model for AI loads scales to DOE properties in the West, the transmission and allocation picture shifts again. Big decisions are moving fast in a process that was built for slow.
SPEAKER_01That's your NWPPA morning brief for Friday, July 31st, 2026. Sources for every story are linked in the show notes. Have a great weekend. Keep the lights on.