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The document outlines five core elements for BESS zoning ordinances: treating BESS as a distinct land use, creating clear approval pathways, referencing national safety standards, basing setbacks on safety rather than size, and addressing project lifecycle changes. It provides detailed technical recommendations on permitting, environmental mitigation, noise and visual impacts, and the incorporation of NFPA and UL safety standards.

The report assesses California's path to a net-zero carbon economy by 2045, specifically examining the necessity of 'clean firm power'—zero-carbon electricity that is available on demand regardless of weather. Using three different optimization models (RESOLVE, urbs, and GenX), the authors find that relying solely on wind, solar, and batteries would require nearly 500 GW of capacity and increase wholesale electricity rates by approximately 65%. In contrast, integrating 25-40 GW of clean firm power—such as nuclear, geothermal, or gas with carbon capture and storage (CCS)—can maintain costs similar to today's levels (around 9 cents/kWh) while significantly reducing the land and transmission infrastructure needed. The report concludes that a diverse portfolio of clean firm resources is the most cost-effective way to ensure grid reliability during extended periods of low renewable output, known as 'dunkelflaute'.

The document argues that traditional investor-owned utility (IOU) financing for transmission projects risks increasing consumer rates and proposes public financing as a lower-cost alternative. Research focused on California indicates that a "lease-type" public-private partnership could save ratepayers up to $3 billion annually, or $123 billion over 40 years, by utilizing low-cost public debt, reducing taxes, and maintaining private sector operational efficiency. The brief outlines several public financing mechanisms, such as public bonds and loans, and provides policy recommendations for other states to implement similar cost-saving reforms, including the use of credit enhancements and the designation of state-level coordinators for high-priority transmission lines.

A technical analysis indicates California can reach 85 percent carbon-free electricity by 2030 even under extreme stressors, such as the August 2020 heat waves and the retirement of one-third of natural gas capacity. To support this, the brief recommends diversifying clean energy resources (including offshore wind and geothermal), phasing out natural gas plants—particularly in disadvantaged communities—and leveraging demand-side resources like energy efficiency and demand response. It also suggests improving regional coordination across Western states and refining reliability evaluation tools used by the CPUC, CEC, and CAISO.

A fact sheet analyzing 210 U.S. coal plants, finding that 99% are more expensive to operate than replacing them with new wind or solar. It highlights the potential for $589 billion in investment in energy communities and the feasibility of integrating battery storage to maintain grid reliability.

The document finds that reaching an 85% clean electricity target by 2030 is feasible and reliable for California, even under most simultaneous stress conditions. Analysis indicates that while solar and battery storage are primary drivers, a diverse portfolio including offshore wind and geothermal reduces dependence on imports and gas. Battery storage specifically reduces the 'duck curve' ramping requirements by an average of 42%. While the state can retire nearly a third of its in-state gas fleet under certain conditions, some gas remains necessary for reliability unless replaced by comparable firm clean resources. The study emphasizes that sharing power with the rest of the Western United States is more optimal than a 'go it alone' approach.

The report examines the 'death spiral' facing traditional U.S. electric utilities caused by falling costs of renewables, energy efficiency, and declining demand. It proposes a regulatory shift by Public Utilities Commissions (PUCs) toward 'performance-based regulation,' where utilities are rewarded for meeting reliability, affordability, and environmental goals rather than the volume of electricity sold. The author suggests that utilities, given their infrastructure and market reach, are the ideal vehicles for decarbonization if incentivized to prioritize system optimization over electron supply.

The report argues that distributed and demand-side resources—including energy efficiency, demand response, and solar PV—can fill the near-term supply gap created by the shutdown of the San Onofre Nuclear Generating Station (SONGS) while supporting California's long-term greenhouse gas reduction goals. It evaluates various resources based on size, cost, deployment speed, and persistence, recommending the creation of capacity markets and the streamlining of permitting and interconnection processes to accelerate adoption.

The report argues that utilities often undervalue renewable resources by failing to account for their contribution to overall system reliability and the benefits of geographic diversification. It proposes using financial portfolio theory to minimize variability through dispersed siting and suggests that the costs of integrating intermittent renewables are relatively low compared to the risks of fossil fuel price volatility. The authors conclude that failure to apply these valuation techniques leads to unnecessary investment in conventional generation capacity.

The VPP Flipbook outlines how utilities can aggregate distributed energy resources (DERs)—such as batteries, electric vehicles, and smart thermostats—to provide grid services like capacity, energy, and resilience. It details a six-step development process and provides specific examples from utilities including PG&E, National Grid, and Green Mountain Power. The document emphasizes the importance of open-access structures, third-party partnerships, and the integration of VPPs into long-term resource planning to address load growth and decarbonization goals.

The document introduces updates to the OnSSET tool to move beyond the assumption of 100% grid reliability. It proposes two proxies for the cost of non-supplied electricity: a parametric Cost of Non-Served Energy (CNSE) penalty and a diesel back-up system model. Testing in eastern Uganda shows that incorporating these reliability costs shifts the 'least-cost' preference from grid extension toward off-grid solutions, with the diesel back-up approach causing more significant shifts in technology mix and increasing total estimated investment by approximately 20%.

The document argues that the U.S. electricity system can maintain reliability while complying with EPA rules to reduce mercury and toxic air emissions. It highlights the availability of flexible enforcement options, the existence of replacement plant capacity, and the availability of proven compliance technologies such as Flue Gas Desulphurization, Dry Sorbent Injection, and Activated Carbon Injection. The text notes that 17 states had already imposed mercury and toxic emission rules as of 2011 without imperiling reliability.