PG&E's $73 Million Microgrid Play: Who Controls Resilience When the Grid Goes Down

Pacific Gas and Electric announced a major milestone: $73 million in authorized community microgrid investments, including $43 million for nine initial projects announced in 2025 and a new $30 million tranche supporting six additional microgrids serving over 2,200 customers across six counties^[1][2][3]. The projects span rural, coastal, Tribal and high-wildfire-risk areas, combining solar, battery storage, biomass, and in three Lake County cases, an experimental pumped-hydro concept called FLASHES that pairs tens of megawatts of local solar with subsurface water storage^[4]. On its face, this looks like resilience: hospitals, fire stations, police departments, and gas stations staying powered when Public Safety Power Shutoff events or grid outages strike. But the framing matters enormously, and PG&E's framing obscures the central question of ownership and control.

Here is the mechanism: PG&E is not building these microgrids as a gift. The utility is deploying them under its own incentive programs, the Community Microgrid Enablement Program (CMEP) and Microgrid Incentive Program (MIP), which means PG&E holds the narrative, the technical standards, and the interconnection rules^[5]. When a community microgrid works, it works because PG&E allowed it and shaped its design. When it fails, PG&E can claim it tried. More important: the distributed energy resources (solar, batteries, biomass) can be "owned by third parties," but they operate within PG&E's grid, under PG&E's tariffs, subject to PG&E's automatic reconnection to the main grid when conditions permit^[5]. The utility becomes the indispensable intermediary between communities and their own resilience. That is not inherently bad, but it is not the same as community power.

PG&E's strategy reflects a deeper shift in how utilities respond to grid stress and climate risk. Instead of hardening and undergrounding the distribution system at scale, a visible, permanent, rate-regulated capital spend that ratepayers finance directly, PG&E is funding granular, community-scale microgrids that deliver resilience to chosen locations while preserving the utility's monopoly over the broader grid. Communities get backup power for critical facilities; PG&E gets credit for innovation and climate leadership, funded partly through ratepayer money and partly through federal grants under the Infrastructure Investment and Jobs Act^[7]. The distribution of resilience is unequal by design: hospitals and fire stations in microgrid zones stay powered; neighborhoods outside them do not. That is triage, not equity.

California's own Community Energy Reliability and Resilience Investment (CERRI) program, which allocated roughly $106.7 million in federal funds through fiscal year 3, shows the larger pattern^[7]. Public utilities like Anaheim Public Utilities received grants directly to upgrade their own infrastructure; PG&E's approach channels grants into demonstration projects and incentive programs it administers. The incentives are real, $2 million to $6 million per project in the new tranche, but they are conditioned on PG&E's approval, technical specifications, and ongoing interconnection consent. Communities do not own resilience; they lease it, contingent on utility cooperation.

The alternative is neither mysterious nor impossible: communities can own and operate microgrids directly, or through municipal utilities, electric cooperatives, or nonprofit entities with enforceable procurement and operational control. A truly independent microgrid paired with community solar and storage, owned by the city, the co-op, or a community trust, not the incumbent utility, would generate the same resilience without the dependency. That requires capital (grants exist for this; see CERRI above), engineering support (third-party consultants exist), and crucially, the franchise and interconnection terms to permit it. PG&E's program does not block community ownership, but it does not incentivize it either. The utility's role should be as an interconnection partner and grid-stability operator, not as the architect and keeper of local power.