Spark Communities Initiative
Exploring Pathways to Community Energy Independence
A Discussion with the Bolinas Community
January 2026
Rate Increases
101%
PG&E rate increases over the past decade, with six separate increases in 2024 alone
Power Shutoffs
6
Public Safety Power Shutoff (PSPS) events affecting West Marin in 2024
Infrastructure Vulnerability
1
Single radial feeder serving the entire community—one line, one point of failure in the event of storms, fires, or equipment problems
Bolinas faces the same energy challenges as many California communities: rising costs, unreliable service, and limited local control over critical infrastructure.
Reliability: Remote location on a single feeder means extended outages during storms and PSPS events.
Affordability: Average residential bills now exceed $222/month while infrastructure investment in West Marin remains minimal.
Local Control: Decisions about rates, infrastructure, and shutoffs are made by distant entities with different priorities.
The question: What options does Bolinas have to improve energy resilience, affordability, and local control?
Sources: CPUC rate filings, PG&E PSPS reports, Marin County Grand Jury 2022-2023
Continue with current PG&E delivery and MCE generation arrangement
No local control over infrastructure
Subject to continued rate increases
PSPS vulnerability continues
No capital investment required
Acquire PG&E's existing distribution infrastructure through purchase or condemnation
Full local control if successful
High upfront costs (asset acquisition)
Often contested—20-30 year timeline
All-or-nothing commitment
Build new, parallel infrastructure that operates alongside the existing utility
Opt-in household participation—voluntary
Phased investment over time
2-5 year implementation
Maintain grid backup throughout
Each pathway has different implications for cost, timeline, risk, and community control.
What it means: The community acquires PG&E's existing poles, wires, and equipment through negotiated purchase or condemnation, then operates them as a publicly-owned utility.
How It Works
Conduct feasibility study to assess costs and value the assets to be acquired
Attempt to negotiate purchase price with PG&E; if unsuccessful, pursue condemnation
Finance acquisition—general obligation bonds require 2/3 voter approval; revenue bonds do not
Take ownership and transition operations, staff, and customer service
Key Challenges
PG&E consistently argues infrastructure is worth far more than "fair market value." Disputes are decided by CPUC administrative law judges, who have ruled in favor of IOUs for decades.
Legal battles routinely extend the process to 20-30 years. Boulder, CO spent $23 million over 10 years before abandoning their effort. San Francisco has pursued municipalization for decades without success.
The community must commit substantial resources and take on significant risk before seeing any benefits from the transition.
Modern Public Power: Rather than acquiring existing infrastructure, the SCU model enables the building of new, parallel systems that operate alongside the existing utility. Residents opt-in to additional services while maintaining their current utility connection as a reliable backup.
How It Works
Engage stakeholders—community members, local experts, potential funders, and BCPUD—to build consensus
Obtain LAFCO approval for BCPUD to activate its latent electrical authority
Secure funding—federal/state incentives, community capital, foundations, grants, or private contributions rather than GO bonds
Deploy infrastructure in tiers: energy services first, then solar/storage, then microgrids if community chooses
Core Principles
New infrastructure alongside existing—no acquisition battles, no service interruption. Grid connection remains for backup.
Participation is voluntary. Residents join based on demonstrated value—no community-wide mandate required.
Each phase delivers value and generates savings before the next begins. Community can pause or stop at any tier.
BCPUD has legal authority under California's Public Utility District Act (PUC §16461)—tested and upheld in California courts.
| Status Quo | Traditional Muni | SCU Model | |
|---|---|---|---|
| Timeline | N/A | 20-30 years typical | 2-5 years |
| Upfront Cost | None | Very high (asset acquisition at IOU-favorable valuations) | Moderate (phased) |
| Risk Level | Ongoing vulnerability | High (litigation, regulatory) | Low (incremental) |
| Local Control | None | Full (if successful) | Full from day one |
| Participation | Automatic | Mandatory (all ratepayers) | Voluntary opt-in |
| During Transition | N/A | Service continuity risk | Grid backup maintained |
| Required Approvals | None | 2/3 voter approval for GO bonds; none for revenue bonds | Board action + LAFCO |
Each tier delivers value before the next begins. The community can progress at its own pace—pausing, accelerating, or stopping at any tier based on results. Distribution lines are optional and only built in later tiers if the community chooses to pursue deeper integration.
Audits, efficiency upgrades, electrification, on-bill financing
Solar and battery storage owned by BCPUD on customer premises
Optional: local lines connecting neighboring participants
Optional: community-scale resilience with tiered service
Optional: federated microgrids, grid interconnection
The advantage:
Each tier is self-financing through the savings it delivers.
The community can evaluate results at every stage and make informed decisions about continuing.
Projected savings
25-35%
at full implementation
Legal Foundation
Under California's Public Utility District Act (PUC §16461), BCPUD can acquire, construct, own, and operate electrical works without CPUC approval. This legal framework has been tested and upheld in California courts.
Community Fit
"What we can do for ourselves will more likely get done." Bolinas has lived this principle—from the water moratorium to the 1971 oil spill cleanup—all without a mayor or city hall.
Post office campaign raised $50K+ over 2+ years. Community raised $300K for COVID testing.
MCE has funded the Community Center's 23 kWh battery and 5 West Marin critical facility microgrids.
~1,500 residents allows meaningful innovation while limiting risk. Small enough to be agile, large enough to matter.
Active Civic Group, Community Land Trust, West Marin Fund, and history of community-driven solutions.
See supporting document: Regulatory Framework for SCU Services in Bolinas, CA
The SCU model creates opportunities for BCPUD / MCE partnership, not competition. MCE gains a low-risk innovation lab and access to new products; Bolinas gains technical expertise and co-financing.
Near-Term
BCPUD as local implementation partner for MCE's resilience programs
Local engagement for efficiency and electrification incentives
Community capital combined with MCE's institutional funding access
Medium-Term
MCE maintains LSE role; BCPUD operates local distribution infrastructure
BCPUD's billing system and distribution lines enable products not currently possible for CCAs
Test approaches outside CPUC constraints; apply learnings to broader MCE territory
Long-Term
MCE as wholesale energy supplier to BCPUD—retains involvement while enabling local distribution
United voice for streamlined interconnection and resilience recognition
Template for other MCE communities seeking enhanced resilience
MCE has already invested in Bolinas Community Center battery (23 kWh) and 5 West Marin critical facility microgrids
Is there community appetite for exploring energy independence options?
What would BCPUD need to see before considering formal exploration?
What stakeholders should be involved in an initial evaluation?
What concerns would the community want addressed?
Learn more
Supporting materials