Vedeni Energy’s Deep Dive

Wholesale power markets for the seven-day period ending May 29, 2026, reflected typical shoulder-season conditions, with a clear regional split between modest prices in Western and central markets and firmer prices in parts of the East. CAISO and the broader Western Energy Markets footprint continued to publish daily real-time and EDAM materials, with prices shaped by steep net-load ramps, solar output, congestion, and EDAM's early operating phase. ERCOT, SPP, MISO, AESO, IESO, NYISO, and ISO-NE were generally orderly, while PJM stood out for stronger real-time pricing and continued market-design pressure tied to large-load growth, resource adequacy, and investment incentives.

There is a kind of utility work that nobody used to make speeches about: tree trimming, hazard-tree removal, and routine access to a right-of-way. It sits low on the glamour scale and high on the list of things that quietly keep the lights on. That is exactly why it deserves more attention now. In parts of the U.S. electric power industry, especially where lines cross federal land, routine maintenance has become a management problem with real consequences for reliability, wildfire risk, crew scheduling, customer costs, and executive credibility.

This week’s leadership conversation has not focused on perks, personality, or another round of buzzwords. It has focused on uncertainty. Leaders are grappling with shifting economic signals, tariff questions, uneven demand, geopolitical shocks, and pressure from boards to move faster with less room for error. The result is a management problem that shows up in everyday work: teams stall, meetings multiply, forecasts soften, and people start waiting for certainty that never comes.

Wholesale power markets across North America remained broadly orderly during the seven-day period ending May 22, 2026. The week’s clearest stress points were localized transmission constraints, operator notices, and ongoing market-implementation work—not broad emergency conditions. Real-time pricing reflected typical late-spring fundamentals: moderate load across most regions, recurring congestion-driven price separation, and episodic nodal volatility around outages and facility constraints. Public postings highlighted ERCOT manual action for an unsolved contingency in the Taylor County area; PJM post-contingency local load relief warnings on May 20; CAISO daily real-time market and EDAM reports; MISO pricing approvals and report-availability notices; ISO-NE daily market postings; IESO renewed-market engagement activity; and AESO REM readiness work.

When load growth accelerates, the industry’s reflex is familiar: build the next substation, the next line, the next major capital project. In many cases, that is the right response. But not always. One of the most important questions for utility leaders today is simpler and more consequential: are we using the grid we already have as effectively as possible?

Performance management should be one of the simplest parts of a manager’s job. Set expectations. Watch the work. Give useful feedback. Correct problems early. Help good people get better. Instead, many companies have turned it into a ceremony. Managers spend days collecting notes, filling out templates, assigning ratings, and preparing for a single formal conversation that tries to do too much at once. Employees walk in expecting judgment, politics, or surprise. Managers often arrive tired and late, hoping to get through the meeting without a fight.

Wholesale power markets across North America moved through the week ending May 15 in a generally stable shoulder-season pattern, with little evidence of broad regional reliability stress in the reviewed materials. Public daily market publications across the organized markets showed a routine operating cadence, while available real-time price reporting suggested that peak pricing was driven mainly by localized congestion, renewable ramps, and ordinary weather-related load variation rather than systemwide scarcity. In the West, CAISO and the WEIM footprint remained focused on market-integration execution and stakeholder processes, while SPP and Markets+ continued to advance western governance and large-load-related work rather than responding to acute operating events.

If you work in the U.S. electric power industry, you are used to hearing that everything takes longer than expected. Permits take longer. Interconnection studies take longer. New generation takes longer. Transmission siting takes longer. What has changed is that a single piece of equipment can now derail an otherwise sound plan on its own: the transformer. That is why transformer shortages have shifted from a purchasing headache to a leadership problem. When a utility, developer, or grid operator cannot get the transformer it needs, the schedule on the wall no longer means much.

If you manage a plant, field team, service operation, branch, hospital unit, warehouse, or support function that depends on experienced people, you already know the problem. The opening is approved. The budget is in place. The work is ready. The applicants are not. Or they arrive without the needed skills, leave after three months, or are poached as soon as they become useful.

North American wholesale electricity markets remained operationally stable during the week ending May 8, but institutional and infrastructure pressures continued to intensify across nearly every major organized market. Spring shoulder-season conditions generally moderated real-time pricing, with most markets avoiding sustained scarcity despite localized volatility tied to transmission congestion, renewable intermittency, and weather-driven load swings. In the western markets, CAISO and the WEIM footprint continued to emphasize operational readiness, transmission planning, and EDAM implementation. SPP and Markets+ likewise focused on governance and market development as Western integration efforts increasingly evolved into competition among alternative regional market structures.