DOE’s Section 202(c) Emergency Orders Since May 2025: 43 and Counting

Why it mattersCampbell is Michigan’s largest remaining coal plant and a critical baseload resource for the MISO North/Central zone. Consumers Energy had announced plans to close the 1,560-MW, three-unit plant—commissioned between 1962 and 1980—15 years ahead of schedule, and MISO approved the retirement in March 2022, finding no reliability problem with the closure.The DOE’s original , issued May 23, 2025, cited NERC’s , which warned MISO faced “elevated risk of operating reserve shortfalls” during peak demand periods, combined with the retirement of approximately 2,700 MW of Michigan coal generation since 2020. Subsequent extensions leaned on operational data. Over the summer of 2025, MISO issued grid alerts on at least 40 of 69 days between June 11 and August 18, including an Energy Emergency Alert on June 23.The DOE also cited the OMS‑MISO annual survey, which projected MISO would face a capacity deficit of 1.4 GW in 2027, growing to 8.2 GW by 2030, as retirements outpace new firm capacity additions.

As POWER reported in , the DOE used that operational record to justify continued emergency intervention through fall and winter. The plant has now been kept online nearly a full year past its planned closure—the longest-running retirement deferral in this series of orders—with the current  running through May 18, 2026.

Why it mattersEddystone Units 3 and 4 are dual-fuel (natural gas/distillate oil) steam turbines on the Delaware River just south of Philadelphia—380 MW each—and among the last dispatchable peakers in the densely loaded PJM East zone. Constellation submitted its deactivation notice to PJM in December 2023, citing economic pressures, and PJM approved the retirement, finding no reliability concerns. As POWER , the units were more than 50 years old and had seen maintenance deferred in anticipation of shutdown.

The DOE’s original , issued May 30, 2025—the last day before the planned retirement—cited PJM’s own reliability projections showing that under extreme conditions the grid could face supply shortfalls requiring emergency demand response, combined with a tightening supply-demand outlook driven by accelerating retirements across PJM’s footprint. Unlike the Campbell case, PJM publicly supported the order, stating it had “repeatedly documented and voiced its concerns over the growing risk of a supply and demand imbalance driven by the confluence of generator retirements and demand growth.”

Subsequent extensions pointed to PJM’s broader capacity crunch. As POWER reported in , the DOE’s extension orders cited continued tightening reserve margins in PJM East and the absence of near-term replacement firm capacity. The February 2026 extension order also noted that the DOE’s July 2025 Resource Adequacy Report projected mounting national capacity deficits absent intervention.

The units have now been kept online nearly a full year past their planned closure, with the current  running through May 24, 2026.

Why it matters

Centralia Unit 2 is Washington state’s last coal-fired power plant—a 729.9-MW unit commissioned in 1973, with Unit 1 retired in 2020. Its planned 2025 closure was anchored in both a 2011 state law and a memorandum of agreement between TransAlta and the state that locked in the retirement dates ahead of the units’ expected 2035 end-of-life. As As POWER , Washington state officials said the original order would violate state law, and opponents—including Earthjustice—called it a “manufactured” emergency issued “against everyone’s wishes.”

The DOE’s original , issued Dec. 16, 2025, cited which found the WECC Northwest region at “elevated risk during periods of extreme weather, such as prolonged, far-reaching cold snaps,” and an as retirements outpace new capacity development. The DOE also emphasized that, as a coal-fired unit, Centralia would be difficult to restart once retired. Thermal cycling alone could trigger failures requiring 30–60 days to repair, it said. 

The March 2026 extension () acknowledged a new stressor: which Bonneville Power Administration (BPA) modeling projected would significantly cut hydro generation from March through November and raise the risk of regional outages during summer heat waves. On Jan. 13, 2026,  to intervene and a request for rehearing and stay of the original order, marking one of the more direct state challenges to the DOE’s actions. 

The current order runs through June 14, 2026. Notably, it will put the DOE in direct conflict with which bans coal-generated electricity starting in 2026.

Why it mattersCraig Station Unit 1 is a ~446-MW coal unit in Craig, Colo., co-owned by five utilities—Tri-State G&T, Platte River Power Authority, Salt River Project, PacifiCorp, and Xcel Energy—and coordinated through WAPA Rocky Mountain Region and SPP West. Its retirement had been planned since 2016, driven by both economics and state and federal environmental compliance requirements, including Colorado’s 2016 regional haze State Implementation Plan.

As POWER , the DOE’s , issued Dec. 30, 2025—one day before the planned shutdown—cited a shortage of electric energy and generation facilities in the WECC Mountain West region under the same resource adequacy framework driving other December orders.

The Craig order stands out for two specific reasons. First, the unit went on Dec. 19, 2025, due to a mechanical valve failure, which means it was not even operational when the order was issued. Tri-State confirmed the unit was not made available to operate until Jan. 20, 2026. Second, and more unusually, two of the order’s own recipients—Tri-State and Platte River Power Authority— arguing the order was unwarranted and that keeping the unit available “will not best meet the DOE’s goal of securing dispatchable electricity resources.” The  and , including Sierra Club, GreenLatinos, Vote Solar, Public Citizen, and EDF, have  to intervene and requests for rehearing and stay on Jan. 28, 2026.

Why it mattersSchahfer Units 17 and 18—commissioned in 1983 and 1986, respectively—at ~847 MW combined, represent the largest single block of capacity frozen by a retirement-deferral order after Campbell. Northern Indiana Public Service Co. (NIPSCO), a regulated natural gas and electric utility, had planned to cease coal combustion at Schahfer by year-end 2025 as part of its long-running “, which included significant investment in renewables and storage. MISO reviewed and approved the retirement plan, finding no reliability concerns with the closures.

The DOE’s , issued Dec. 23, 2025, determined that an “emergency exists in portions of the Midwest region of the U.S. due to a shortage of electric energy, a shortage of facilities for the generation of electricity, and other causes.” The order cited the same MISO capacity deficit projections driving the Campbell extensions—a 1.4 GW shortfall projected for 2027 growing to 8.2 GW by 2030—and the same national resource adequacy framing from the DOE’s July 2025 Resource Adequacy Report. As POWER , the Schahfer and Culley orders were part of a rapid-fire series of December 202(c) actions that collectively froze more than 2 GW of coal capacity in a single week.

NIPSCO said publicly that the order delays its retirement plans and noted in that it “now expects” to keep Units 17 and 18 available through March 23, 2026, consistent with the order’s terms. The order will expire on March 23, 2026.

Why it matters

F.B. Culley Unit 2 is a small, aging coal unit in Warrick County, Indiana—about 103 MW and nearly 60 years old—that CenterPoint Energy had planned to retire by the end of 2025 as part of its long-term coal transition. It is one of the last coal units in CenterPoint’s Indiana portfolio. Culley is also the smallest plant in this series of retirement-deferral orders, underscoring that the DOE is willing to intervene even for relatively modest capacity when it believes regional reserves are tight.

The DOE’s , issued Dec. 23, 2025, paired Culley with NIPSCO’s much larger Schahfer plant in its description of an “emergency” in MISO’s footprint due to a shortage of electric energy, a shortage of facilities for generation, and other causes. The order relied on the same building blocks used in the Campbell and Schahfer orders: NERC’s 2025–2026 Winter Reliability Assessment describing elevated risk in MISO during extreme cold, the OMS‑MISO survey projecting a capacity deficit of 1.4 GW in 2027 growing to 8.2 GW by 2030, and the The DOE’s July 2025 Resource Adequacy Report warning that accelerated retirements and surging load from data centers and industrial growth are outpacing new firm capacity additions.

The Culley order is notable given the DOE’s signal that even relatively small coal units can be deemed “critical” under national emergency framing—potentially affecting dozens of similar aging plants across MISO.

Why it mattersThe PREPA orders were the first in this series and remain the longest-running, continuous since May 16, 2025. The DOE’s initial  followed an island‑wide blackout and warnings that Puerto Rico could face up to 135 days of forced load shedding absent emergency action. Order 202‑25‑1 directs PREPA to dispatch specified fossil generation units “necessary to expand baseload generation for the island and maintain grid reliability, closing the gap in generation shortfall,” while Order 202‑25‑2 requires aggressive vegetation management and asset management on key transmission corridors to keep critical lines in service.

Three successive renewals— (Aug. 15–Nov. 12, 2025),  (Nov. 13, 2025–Feb. 10, 2026), and  (Feb. 10–May 11, 2026) keep those directives in place, expanding them to cover ongoing “asset management” of specified transmission facilities. The orders effectively federalize key aspects of PREPA’s dispatch and line maintenance under an open‑ended emergency rationale, even as Puerto Rico moves through grid privatization and post‑Hurricane Maria reconstruction.