Vedeni Energy’s Deep Dive

As the U.S. power system decarbonizes, the reliability challenge is shifting from annual energy sufficiency to dependable performance during scarcity hours, steep ramps, renewable shortfalls, fuel constraints, and extreme weather. This white paper examines the future role of flexible generation in that environment and argues that dispatchable resources will remain necessary, but in a narrower, more strategic, and lower-emission role than in the past. It assesses the operational value and limitations of gas-fired flexibility, hydrogen-capable turbines, advanced peaking resources, and hybrid configurations, and considers how these resources should be coordinated with storage, demand-side flexibility, transmission, and other clean firm options. 

Read the full whitepaper here

If you manage people in the power business, the old picture is gone. Software no longer sits quietly behind the scenes. Operators still run the control room, planners still build the cases, market teams still place the bids, and IT still keeps the servers alive. But those functions now depend on software that must work together under time pressure. Grid operations, transmission planning, outage scheduling, interconnection studies, market clearing, forecasting, and customer-facing commitments are increasingly tied to the quality of the code and data behind them.

Over the past week, one leadership issue kept surfacing across workplace research, management reporting, and current commentary: layoffs are no longer treated as rare emergencies. In more firms, they are becoming a standard management tool. That shift changes the job for every leader, but it lands hardest on middle managers. They are expected to explain decisions they did not make, steady teams they may no longer fully control, and keep work moving while employees wonder whether another cut is coming.

Wholesale power markets for the seven-day period ending June 12, 2026, were shaped more by early-summer readiness, interconnection reform, large-load integration, and mounting pressure on transmission buildout than by emergency conditions. ERCOT and PJM produced the week’s most consequential near-term developments: ERCOT continued to manage reliability risks associated with rapidly growing large-load interconnections, while PJM secured federal approval for an expedited interconnection track to bring qualified capacity resources online more quickly. CAISO’s activity focused on daily real-time market reporting, interconnection and deliverability process work, and the continued implementation of EDAM and the Western market.

For U.S. power companies, wildfire season is no longer a regional operating problem that a few Western utilities can manage on the margins. It is a leadership test that spans operations, fieldwork, customer care, regulatory affairs, public safety, and finance. Over the past week, Northern California entered its first red-flag warning of the season, PG&E began public safety power shutoffs in parts of nine counties, and reliability groups kept pointing to the same fact: wildfire is now a standing grid risk, not a side case.

The leadership topic gaining the most traction right now is not some shiny new theory. It is an old problem appearing in new forms. Organizations are changing course more often, moving faster, and asking people to absorb more uncertainty. Employees can live with change. What they struggle with is change that arrives without a clear explanation. That is where trust starts to crack. When leaders keep shifting direction and fail to explain what changed, why it changed, and what stays the same, people stop arguing with the plan and start doubting the people behind it.

Wholesale power markets for the seven-day period ending Friday, June 5, 2026, moved decisively out of late-spring shoulder conditions and into an early-summer risk posture. The clearest stress emerged in the East, where PJM issued a Hot Weather Alert for June 5–6 across its Mid-Atlantic and Southern regions ahead of 90-degree temperatures. ISO New England and NYISO, by contrast, remained in summer-readiness mode without a comparable public reliability signal. In the West and central regions, conditions were steadier: CAISO continued routine real-time and EDAM reporting; SPP and MISO maintained active planning and stakeholder calendars; and ERCOT posted largely routine operating notices despite a notable June 1 generation-loss event that did not escalate into a broader emergency.

Much of the utility leadership conversation lately has centered on a simple fact: plants once slated for retirement are still operating because Washington ordered them to remain available. That may sound like a legal story, but inside a utility, it is first and foremost a management story. The Department of Energy has continued to use Section 202(c) emergency authority to keep certain coal and gas units available beyond their planned retirement dates. In 2026 alone, DOE orders have covered plants in Pennsylvania, Michigan, Indiana, Washington, Colorado, Maryland, and Puerto Rico. On May 21, DOE issued one order keeping Eddystone Units 3 and 4 available through August 22 and another keeping Wagner Unit 4 available through August 19. Days earlier, DOE also authorized PJM to use backup generation at data centers and other major sites as a last resort before rolling blackouts.

Many companies still make the same bad trade. They take the person who produces the strongest individual work, give that person direct reports, and call it leadership development. Sometimes it works. Often, it does not. The company loses a strong producer, gains an unsteady manager, and then acts surprised when the team slows down.

The U.S. electric power system has entered a reliability era defined by compound stress. Extreme weather is no longer an occasional external disruption managed through emergency restoration after the fact. Heat waves, winter storms, hurricanes, wildfires, drought, high winds, and flooding now shape core assumptions about resource adequacy, transmission planning, distribution investment, fuel assurance, operating reserves, and emergency procedures. This shift is forcing utilities, ISOs/RTOs, state regulators, FERC, NERC, and reliability coordinators to reconsider long-standing planning practices developed around historical weather patterns, deterministic contingency analysis, and relatively stable load growth. The grid reliability challenge is no longer limited to whether enough nameplate capacity exists on paper.