SB 1221: CPUC Adopts Gas Decommissioning Pilot Framework; Consent Rules Loosened, Cost-Shift Questions Remain

On July 2, the CPUC adopted a final decision establishing the application process for Senate Bill 1221 neighborhood decarbonization pilots. The decision creates the first formal pathway for gas corporations to propose voluntary projects that replace gas service with zero-emission alternatives and enable decommissioning of the underlying gas distribution system.

The item carried 4-0. (Commissioner Christine Harada was not present today).

PILOT CAP & SLOT ALLOCATION

The program is capped at 30 pilots statewide, excluding projects with 100% property-owner consent. The first round is limited to 16 projects. PG&E and SoCalGas/SDG&E receive seven slots each in the first round and seven each in the second. The decision reserves one slot for Southwest Gas and one for smaller CPUC-regulated gas corporations, each usable in either of the first two rounds. Any remaining slots move to a third round without utility-specific caps.

FILING SCHEDULE

First-round applications are due April 1, 2027. Second-round applications are due January 15, 2028. A third round, if slots remain, is due June 1, 2028. Commissioner Karen Douglas said Energy Division will issue another staff proposal before the first deadline to further refine application and program requirements. The initial decarbonization zones are also scheduled to be updated by December 31, 2026.

REVIEW PROCESS & APPLICANT STRUCTURE

The first round must proceed by application rather than advice letter. The decision leaves open whether the CPUC will authorize an advice-letter process for the second and third rounds. Gas corporations remain the applicants but may partner with or co-administer projects alongside electric utilities, local governments, community-based organizations or other entities.

COST-EFFECTIVNESS TEST

Each pilot must demonstrate that avoided gas infrastructure costs exceed the cost of the zero-emission alternative, calculated by net present value using the utility's weighted average cost of capital as the discount rate. The governing cost-effectiveness test excludes costs funded by non-ratepayer sources and excludes administrative and outreach costs. Applications must also account for electric infrastructure upgrade costs, gas infrastructure impacts, bill impacts, greenhouse gas emissions, labor considerations, customer outreach, affordability and substitute-service adequacy.

CONSENT & COMMUNITY SUPPORT

The decision relaxes the proposed decision's front-end consent requirement. Applications no longer need non-binding expressions of interest from at least 67% of property owners before filing; instead, the utility must demonstrate a reasonable expectation of obtaining the required consent. After CPUC approval, the utility must obtain binding consent from owners of at least 67% of properties in the pilot boundary before investing capital.

CUSTOMER PROTECTIONS

Customer offerings must include a no-cost option for all appliances, upgrades and remediation needed to implement the zero-emission alternative, with optional upgrades available at customer expense. Applications must identify affected customers, property owners, tenants, master-metered properties, small commercial customers and medical baseline customers, and must provide bill-impact estimates while protecting individual customer data.

COST RECOVERY & RATEMAKING TREATMENT

Behind-the-meter costs must be treated as expenses rather than capital costs earning the utility's authorized rate of return. Utilities may propose amortization over no more than ten years and may recover financing costs at either the applicable account interest rate or the utility's authorized cost of debt. The decision also authorizes gas corporations to establish subaccounts for administrative and application-outreach costs, including prudently incurred costs for projects explored but not ultimately proposed.

DEFERRED ISSUES

Shareholder incentives, data collection, reporting and evaluation remain deferred to Track 4.

COMMISSIONER COMMENTS

The four commissioners used the voting meeting to mark different implementation risks.

• Commissioner Douglas said first-round applications are needed for transparency and because additional work remains before the Commission can rely on a lighter process. She also identified the SB 1221 obligation-to-serve determination (relieving a gas corporation of its service obligation once all affected customers convert) as an issue the forthcoming staff proposal must address.
• Commissioner Darcie Houck discussed low-income community needs, tenant protections and CBO-led outreach, while endorsing a possible advice-letter process for rounds two and three if round-one applications are clear enough to support faster review.
• Commissioner Matthew Baker focused on ratepayer protections: cross-subsidy magnitude, who pays versus who benefits, scalability and bill-impact transparency so participating owners can exercise a free choice. He backed the behind-the-meter expense treatment and the 10% administrative-cost cap, and warned that gas-to-electric conversion imposes upfront electric-system costs borne by electric customers (a problem outside this decision's scope but relevant to whether the model can scale).
• President John Reynolds endorsed the first-round application requirement and the April 1, 2027 schedule.

INSTANT ANALYSIS: The final decision converts SB 1221 into a working pilot pipeline while reducing the pre-filing burden the proposed decision would have imposed.

Dropping the requirement for 67% non-binding property-owner interest before filing removes a major front-end screen. Utilities can now bring forward projects based on a reasonable expectation of consent, rather than completing extensive property-owner outreach before knowing whether the CPUC will entertain the proposal. Binding consent still applies before capital spending, so weak community support can still stop a pilot after approval.

Later rounds may move faster. Commissioners Douglas and Houck both displayed openness to an advice-letter process after the first round, with Houck tying that path to the 2029 statutory deadline and the quality of first-round applications. That would shift the program toward speed and away from application-level litigation after the CPUC sees the first batch of proposals, while preserving full review for the inaugural projects.

The cost-effectiveness test still limits where pilots are likely to work. A project must show that avoided gas repair, replacement or continued operation pays for the zero-emission alternative, using the utility's weighted average cost of capital and excluding non-ratepayer funding and administrative/outreach costs from the governing calculation. The strongest candidates are areas with expensive near-term gas work, manageable electric upgrades and customer conversions that do not create large bill or remediation exposure.

Commissioner Baker's scalability concern extends past the pilots. Even when a project avoids gas-system spending, electrification pushes upfront costs onto electric customers while reducing near-term gas-system costs. The decision does not resolve that gas-electric cost-shift, but applications will have to make the tradeoffs legible through bill-impact analysis, electric-upgrade review and ratepayer-benefit showings.

Two major issues remain for Track 4 and the forthcoming staff proposal: how the CPUC will evaluate pilot performance and structure shareholder incentives, and how it will handle the obligation-to-serve determination that makes gas decommissioning legally operative after customers convert.