NWPPA Morning Brief - Tuesday, May 26, 2026

NWPPA Morning Brief — Tuesday, May 26, 2026

In today's brief:

Top Federal Developments

• FERC Summer Assessment Warns of Colorado River Drought Risk, Reports 75 GW Capacity Additions — https://www.utilitydive.com/news/ferc-summer-market-reliability-assessment/820962/
• FERC Proposes First Major Gas Certificate Rewrite Since 2006 — https://www.ferc.gov/news-events/news/ferc-unleashes-natural-gas-permit-reforms-accelerating-infrastructure-upgrades
• DOE Issues Presidential Permit to Basin Electric for Two New U.S.–Canada Transmission Lines — https://www.energy.gov/oe/articles/does-office-electricity-issues-presidential-permit-expand-us-canada-grid-reliability
• DOE Keeps Wagner Unit 4 Running on Emergency Order for PJM Summer — https://solarquarter.com/2026/05/22/united-states-department-of-energy-approves-emergency-operation-of-wagner-unit-4-to-support-pjm-grid-reliability-during-summer-peak-demand

Top Regional / State Developments

• Wyoming Lawmakers Weigh Looser Electric Regulation as Trona and Data Centers Compete for Power — https://wyofile.com/wyoming-lawmakers-mull-loosening-electric-regulations-to-meet-growing-electrical-demand/
• Utah Nuclear Summit Focuses on Permitting Acceleration — https://www.kpcw.org/wasatch-county/2026-05-25/faster-project-approval-is-focus-at-operation-gigawatt-nuclear-power-summit

Congressional and Federal Agency Scan

• Lawmakers Split on Grid Permitting Legislation — https://news.bloomberglaw.com/environment-and-energy/electric-grid-expansion-in-permitting-push-splits-us-lawmakers

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

Transcript

SPEAKER_00 0:00

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, FERC's Summer Reliability Assessment flags Colorado River drought risk and reports record capacity additions across WEC. FERC also proposes its first major overhaul of the natural gas blanket certificate program in two decades. DOE grants Basin Electric a presidential permit for two new cross-border transmission lines into Canada. A DOE emergency order keeps a Maryland coal plant running for PJM through peak season. Wyoming lawmakers weigh loosening utility regulation as Trona producers and data center developers fight over the same scarce megawatts. And Utah hosts a nuclear permitting summit as state-level SMR momentum builds. 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.

SPEAKER_01 1:16

The FERC Summer Reliability Assessment is the story I'd lead with this morning. The headline is 4,500 megawatts of Colorado River hydropower potentially gone by August. Not a tail risk, a FERC staff warning tied to ongoing drought conditions. The wet capacity addition numbers are real and they improve the regional picture, but they don't offset localized hydroexposure, and Colorado River System utilities face concrete replacement energy cost exposure right now.

SPEAKER_00 1:46

And the timing matters. We're weeks away from peak demand windows. Utilities with Colorado River exposure should already be stress testing their day-ahead procurement assumptions for July and August.

SPEAKER_01 1:56

Let's start with the full reliability picture. The FERC Summer Reliability Assessment covers a lot of ground. Nationally, generating capacity is up roughly 75 gigawatts year over year, solar, wind, and batteries leading, retirements slowing to about 8 gigawatts. The WEC region picked up 13 gigawatts of that, but the drought warning is the operational signal. Colorado River hydropower at risk of curtailment reaching 4,500 megawatts by August puts real pressure on the balancing authorities and load serving entities that depend on that output.

SPEAKER_00 2:29

13 gigawatts added in WEC sounds like a buffer, but capacity on paper and dispatchable capacity when you need it on a hot August afternoon are two different things. Much of that addition is solar and batteries with limited duration. If Colorado River Hydro goes offline in volume, Western utilities are looking at tighter day-ahead markets and elevated replacement energy costs right through the back end of summer.

SPEAKER_01 2:54

The question to watch is which utilities and balancing authorities have direct contract exposure to Colorado River system output versus those with indirect market exposure. The cost hit lands differently depending on your procurement structure.

SPEAKER_00 3:08

Turning to the gas pipeline story, FERC voted unanimously on May 21st to propose the first major rewrite of the blanket certificate program since 2006. The rules that allow interstate natural gas pipelines to build certain projects without filing a separate case at the Commission each time.

SPEAKER_01 3:25

The headline change is roughly doubling the cost thresholds that trigger full case-by-case review. Anything below those thresholds can move under the blanket authorization rather than waiting for a full individual proceeding. The second headline is that LNG facilities are brought into that framework for the first time. For public power utilities with gas-fired generation, the practical question is whether pipeline laterals and compression upgrades needed to support resource adequacy plans can now move on faster timelines.

SPEAKER_00 3:55

If your gas supply infrastructure for a peaker or a combined cycle unit has been waiting on pipeline interconnection approvals, higher thresholds could shorten that path. It's a proposed rule, not final. So the comment period is the next gate. But the direction of travel is toward faster project execution on the gas side, and that affects resource planning assumptions.

SPEAKER_01 4:17

Worth noting that unanimous 5-0 vote. This isn't a contentious outcome at FERC right now. It's a policy direction the full commission is aligned on.

SPEAKER_00 4:27

Next up, the Basin Electric Presidential Permit. DOE's Office of Electricity granted Basin Electric Power Cooperative authorization to build and operate two new 230 kilovolt transmission lines from North Dakota to the Canadian border, adding up to 650 megawatts of U.S. Canada transfer capability.

SPEAKER_01 4:47

A presidential permit is the specific federal authorization required before any cross-border transmission infrastructure can be constructed or operated. You cannot build across the border without one. Basin Electric getting this for two new lines is meaningful on its own as a grid investment signal. But the broader relevance for Western public power is the timing. Canadian hydro imports carry elevated strategic value for summer reliability right now, and this permit reflects continued federal willingness to advance cross-border capacity at exactly that moment.

SPEAKER_00 5:22

Basin Electric is a generation and transmission cooperative, so their grid investments ripple into interregional planning across a wide footprint. 650 megawatts of new transfer capability into Canada is not a rounding error. For utilities in the northern tier exploring Canadian hydro supply options, this is a development worth tracking as it moves toward construction.

SPEAKER_01 5:44

Shifting to the DOE emergency order story, DOE invoked its 202C Emergency Authority, the power to compel a specific plant to keep operating past its planned retirement date when the regional grid operator flags a shortage risk to keep Wagner Unit 4 in Maryland running through PJM's summer peak.

SPEAKER_00 6:04

This is the precedent that Western operators should be watching closely. The 202C tool has been used before, but the pattern of deployment is accelerating as retirements outpace replacement capacity in multiple regions. The cost question is the hard one. When DOE compels a plant to run above its planned retirement date, who bears the above market operating costs? In PJM, that gets resolved through specific mechanisms. But the framework in Western markets for a similar order is less tested.

SPEAKER_01 6:33

If reserve margins in the WEC region continue to tighten and a coal unit retirement gets flagged as a reliability risk, the same tool is available to DOE for Western resources. Utilities that have coal contracts expiring, or units in their resource mix that are approaching retirement dates, should be thinking now about what a 202C order would mean for their cost exposure and operational planning.

SPEAKER_00 6:56

Moving to Wyoming, lawmakers are considering loosening electric utility regulation to address load growth from the state's trona industry, which exports $1.3 billion annually, and told a panel of legislators it cannot access the megawatts it needs to expand, with utilities quoting seven-year interconnection wait times that one industry representative called a de facto no.

SPEAKER_01 7:18

The direct competition here is between the Trona industry and data center developers pursuing the same scarce generation and interconnection capacity. Wyoming's integrated utility framework wasn't built for this volume or this pace of large load requests, and the regulatory structure is now under pressure to adapt. The cost allocation question is the part with the most direct ratepayer implications. Who pays for the generation and transmission additions needed to serve new large loads matters enormously to existing customers.

SPEAKER_00 7:48

This pattern is surfacing across the Interior West, not just Wyoming. How state regulators allocate constrained capacity between legacy industrial loads and new hyperscale demand is a live question in multiple jurisdictions. The Wyoming outcome, whatever shape it takes, will inform how other states approach the same tension.

SPEAKER_01 8:08

Over to Utah, the Operation Gigawatt Nuclear Summit in Wasatch County focused on faster project approvals as Utah positions itself as a nuclear development hub. The discussions tracked the broader push under the Advance Act and recent administration directives on reactor deployment.

SPEAKER_00 8:25

For public power utilities evaluating SMRs as a dispatchable carbon-free option, the state level momentum matters as much as the federal policy backdrop. Sighting and approval pathways at the state level are often the longer pole in the tent for early SMR projects. Utah's active engagement means joint action agencies and consortia exploring SMR participation have a jurisdiction that is actively working the problem.

SPEAKER_01 8:52

The summit itself is a signal. State-level political will is forming around nuclear in the Interior West. That changes the calculus for any utility evaluating whether SMR participation is realistic in the next decade.

SPEAKER_00 9:06

On the pricing front, Front Month Henry Hub Natural Gas Futures were trading at $2.94 per million BTU today, up from $2.91. NYMEX WTI Front Month Crude Futures were trading at $92.91 per barrel today, up from $90.81.

SPEAKER_01 9:24

The 10-year Treasury yield was 4.57% on May 21st, flat on the session. Comex Copper settled at $6.38 per pound on May 25th, up from $6.34.

SPEAKER_00 9:38

Turning to the congressional scan, Bloomberg Law is reporting that U.S. lawmakers remain divided on transmission permitting reform and grid modernization legislation. The split covers interregional transfer capacity, NEPA streamlining for transmission, and cost allocation frameworks.

SPEAKER_01 9:54

The practical implication for Western public power is straightforward. Continued congressional stalemate means long-lead transmission projects will continue to depend on FERC's existing authorities and state-level processes rather than any comprehensive federal permitting overhaul. That's the planning environment utilities need to work within for the foreseeable future.

SPEAKER_00 10:16

One to watch today is the cost allocation question embedded in the DOE 202C emergency order story. The Wagner Unit 4 order is a PJM development, but the cost mechanism it sets in motion is the live precedent for Western operators.

SPEAKER_01 10:32

When DOE compels a plant to run past its planned retirement under emergency authority, the above market operating costs have to land somewhere. In PJM, existing capacity market structures and tariff provisions provide a framework, imperfect but defined. In the WEC region, a similar order would enter less settled territory, and the cost exposure for load-serving entities in the affected balancing authority is genuinely unclear.

SPEAKER_00 10:58

Any Western utility with coal units approaching retirement that also serve as reliability anchors in their balancing area should be asking their legal and regulatory teams right now what a 22C order would look like in their footprint. The question is not hypothetical anymore.

SPEAKER_01 11:15

The pattern of emergency orders is accelerating nationally. The Western version of this story is a matter of when, not if. The through line today is resource adequacy pressure hitting from multiple directions simultaneously. Colorado River hydro curtailment risk, emergency orders to retain retiring capacity, large load competition for scarce megawatts in Wyoming. These are not isolated stories. Western public power utilities are navigating a reliability environment where the margin for error is narrowing, even as new capacity additions improve the headline numbers.

SPEAKER_00 11:48

The FERC Summer Assessment puts 4,500 megawatts of potential hydro curtailment in writing, with August as the target date. That's the number to carry into your next operations or procurement conversation. That's your NWPPA morning brief for Tuesday, May 26, 2026. Sources for every story are linked in the show notes. We'll be back tomorrow morning. Keep the lights on.