A safer utility still shadowed by fire and legislative risks
- PG&E is trying to become a steadier regulated utility after years of wildfire damage and bankruptcy fallout.
- Electric service made up 73.5% of 2025 operating revenue, while natural gas made up 26.5%.
- The new upside is data center demand, with a pipeline of over 12 GW and 1.8 GW expected online by 2030.
- Management says no new equity is needed through 2030 while it works through a $73 billion five-year capital plan.
- The main danger remains wildfire liability, compounded by the need for state legislative reform.
The recovery is real, but fragile
PG&E has a clearer bull case than it did a few years ago. Q2 2026 core EPS came in at $0.40, and the company reaffirmed its full-year guidance. It has also seen zero major fires linked to its equipment over the last four years, which supports the view that wildfire controls are improving.
The newer growth story is power demand from data centers and other large-load customers. Management noted that the data center pipeline now stands at over 12 gigawatts, with 1.8 gigawatts expected to be online by 2030. If those projects turn into real grid spending that regulators approve, PG&E could grow its rate base significantly without selling new stock.
The bear case revolves around legacy liabilities and political pressure. PG&E still faces $3.875 billion in liabilities from the 2019, 2021, and 2022 fires. A major new fire tied to PG&E equipment could reset the whole story.
The key tests are simple to watch. Investors need a favorable outcome on state legislative wildfire liability reform, as management warned that a failure there could force a cut to long-term investment plans. Other catalysts include a CPUC decision on the $1.9 billion Kincade and Dixie recovery request, no major PG&E-caused fire in the 2026 fire season, and an October 2026 decision in the Wildfire and Gas Safety Costs proceeding.
Rates decide the profit
PG&E makes money like a standard regulated utility. It spends money to run and upgrade the electric and gas systems, then asks regulators to let it recover reasonable costs plus an allowed return. The main regulators are the California Public Utilities Commission, called the CPUC, and the Federal Energy Regulatory Commission, called FERC.
A large part of revenue is pass-through money. That means PG&E buys electricity or natural gas for customers, then passes those costs through bills rather than keeping them as profit. The real profit engine is approved investment in the grid and allowed recovery of operating costs.
This model can be stable when regulators agree that spending was needed and reasonable. It can break when costs are delayed, cut, or disallowed. That matters most for wildfire mitigation, insurance, claims, undergrounding, and vegetation management, because those bills are large and politically sensitive.
Power, gas, and new load
Electric service
PG&E generates, transmits, and distributes electricity. This is the largest part of the business and made up 73.5% of 2025 operating revenue.
Natural gas service
PG&E transports and distributes natural gas. It is smaller than electric service, but still a core utility product for homes and businesses.
Wildfire mitigation investment
This is not a customer product, but it drives a large part of future spending. Undergrounding, vegetation work, and grid hardening can raise the rate base if regulators allow recovery.
Large-load and data center service
Data centers need huge amounts of power. Management noted over 12 GW in the demand pipeline, which could become a new source of approved grid growth.
Mostly electric revenue
The mix is from the full year ended December 31, 2025. Both segments serve one main region, Northern and Central California, so PG&E has high geographic and regulatory concentration.
What could break the thesis
Legislative reform stalls
High impact · Medium oddsManagement explicitly warned that if state legislative wildfire liability reform remains unresolved or insufficient, they would need to reevaluate their capital allocation and long-term investment plans. This could threaten the $73 billion five-year capital plan.
A PG&E-caused wildfire
High impact · Medium oddsThis is the biggest risk. A major fire tied to PG&E equipment could create large claims, political pressure, and new limits on cost recovery. It could also damage trust with regulators and customers.
Cost recovery gets cut or delayed
High impact · Medium oddsThe bull case needs regulators to approve wildfire and safety spending in rates. PG&E is waiting on the $1.9 billion Kincade and Dixie AB 1054 recovery request. The Wildfire and Gas Safety Costs proceeding was delayed to October 2026.
Legacy fire liabilities keep rising
High impact · Medium oddsPG&E already lists $3.875 billion of estimated liabilities for the 2019 Kincade, 2021 Dixie, and 2022 Mosquito fires. The filing says these estimates do not include all categories of possible damages and losses.
Data center demand fails to convert
Medium impact · Medium oddsThe 12 GW large-load pipeline sounds important, but interest is not the same as contracted revenue. PG&E must connect customers, upgrade the grid, and win regulatory approval without straining service quality.
In one breath
Is PG&E a normal utility now?
It is closer to a normal regulated utility than it was after the wildfire crisis, but it is not risk-free. The company still carries large legacy fire liabilities and faces a real risk from future equipment-caused fires.
Why do data centers matter for PG&E?
Data centers use a lot of electricity. PG&E has over 12 GW in its pipeline, which could require grid upgrades that grow approved investment if regulators allow recovery.
What is the biggest thing to watch in 2026?
The 2026 fire season and the outcome of state legislative wildfire liability reform are the most important tests. Investors should also watch the CPUC decisions on cost recovery requests.
