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The document outlines a structured approach to grid modernization, emphasizing integrated distribution planning and the use of outcome-oriented metrics for affordability, resilience, and environmental performance. It suggests tying utility revenue to these performance targets through conditional rates of return or budget caps with shared savings to align utility incentives with public benefits.

The report argues that the rapid growth of electric vehicles (EVs) requires a shift in regulatory paradigms to ensure that new loads benefit rather than impair the electricity grid. It emphasizes the role of state utility regulators in designing smart charging policies, rate structures, and infrastructure ownership models. Through case studies of California and Washington, the document illustrates different approaches to EV deployment and integration, highlighting the need for adaptive regulation, such as scalable pilots and scenario-based distribution planning, to manage the unpredictable nature of EV adoption.

The document examines the failures of California's Risk-Reward Incentive Mechanism (RRIM), where disagreements over counterfactual assumptions for energy savings led to massive swings in utility penalties and bonuses. It argues that measure-by-measure estimation is administratively burdensome and contentious, recommending a shift toward outcome-oriented metrics or the use of approved ex ante values to reduce regulatory conflict.

The paper argues that traditional cost-of-service regulation incentivizes utilities to invest in capital expenditures to meet peak demand. To counter this, it proposes a PIM based on an outcome-oriented metric—specifically the percentage reduction in peak load—rather than a measure-by-measure counterfactual approach, which it claims failed in California's Risk Reward Incentive Mechanism (RRIM). The author recommends setting long-term targets (five to eight years) with annual interim goals and utilizing a sloped, symmetrical incentive structure with upper and lower caps. To manage risk, the proposal suggests a gradual implementation starting with small revenue amounts, eventually scaling the PIM based on independent studies of the net societal benefits of peak reduction.

The paper examines how different DER ownership models can be used to integrate cost-effective technologies into outdated regulatory frameworks. It argues that no single model is universal, but each can work if the value proposition aligns with the public interest and utilizes an adaptive approach prioritizing fair compensation and transparency. Utility-owned models are effective for early adoption and public goals but risk cost overruns and market power issues. Third-party and customer-owned models excel when they have transparent access to the full value of DERs through dynamic rate design or competitive markets.

The report argues that current U.S. distributed solar (DPV) business models are overly customer-centric and fail to capture operational grid benefits, leading to conflict between utilities and solar companies. It proposes three 'bridge' business model building blocks: increasing access via subscription models, optimizing deployment for capacity and grid services, and bundling solar with other distributed energy resources (DERs). The authors emphasize that maximizing DPV value requires collaboration to reduce 'soft costs' and a shift toward standardized valuation methodologies and transparent data sharing between stakeholders.

The report assesses the Risk/Reward Incentive Mechanism (RRIM) implemented by the California Public Utilities Commission (CPUC) in 2007. While the RRIM increased senior management's attention toward energy efficiency and drove the expansion of cost-effective programs like lighting, it struggled to protect ratepayers due to the abandonment of the 'true-up' process. The mechanism's design—characterized by sharp earnings 'cliffs' and retroactive implementation—led to significant regulatory conflict and unpredictable earnings, which limited its value to shareholders. The report concludes that while the RRIM was a valuable experiment, future incentives should be implemented before program design, avoid sharp payment distinctions, and be designed for predictability and repeatability.

The report details a September 2013 briefing on America’s Power Plan (APP), focusing on the transition to a high-renewables future in the U.S. Midwest. It examines the need for new utility business models to handle decarbonization and distributed energy resources (DERs), highlights Minnesota's legislative progress on solar and renewable standards, and discusses Xcel Energy's experience integrating variable wind power. Key recommendations include adopting performance-based regulation, streamlining 'soft costs' for solar PV, and integrating distribution planning into state resource processes.

The Smart Garage report describes a system where electrified vehicles (xEVs) communicate with the grid and buildings to optimize energy use. The document identifies a near-term focus on 'V1G' (smart one-way charging) as a practical first step toward a long-term 'V2G' (bi-directional charging) vision. It analyzes the ecosystem's value chain—including OEMs, utilities, and 'connectors'—and identifies five primary barriers: uncertain consumer demand, high battery costs, infrastructure funding, fragmented utility regulation, and a lack of communication standards. To address these, the report proposes six collaborative projects to quantify demand, analyze battery second-life value, and establish national policy frameworks.

The document asserts that new conventional coal plants are imprudent investments due to the certainty of future U.S. federal CO2 regulations, likely in the form of a cap-and-trade system. It argues that such regulations will significantly raise the cost of coal-fired electricity, making energy efficiency and renewables more competitive. The report urges state regulators to protect ratepayers by either denying the construction of new coal plants or requiring that shareholders, rather than customers, bear the financial risk of future carbon compliance costs.

The report argues that achieving a cost-optimal net-zero building sector in Canada requires a significant shift toward electrification and a reduction in gas use. It warns that current regulatory inertia and the continued expansion of gas networks risk increasing costs for taxpayers and jeopardizing climate goals. The document recommends that provincial governments legislate net-zero targets, move away from gas as the default heating option for new buildings, and provide regulators with the tools to manage a phased contraction of gas infrastructure while ensuring affordability and equity.

The report argues that Canada's cost-optimal path to net zero requires a significant shift from gas to electricity for building heat. It warns that continued expansion of gas networks and a 'business-as-usual' approach to utility regulation create financial risks for ratepayers and threaten climate goals. The authors recommend that provincial governments legislate net zero targets, end the default expansion of gas infrastructure, and provide clear energy roadmaps to guide regulators and utilities.

The text examines the gap between theoretical 'perfect' markets and real-world economic behavior, specifically regarding the under-investment in energy and resource efficiency. It identifies failures in capital allocation, organizational inertia, and perverse regulatory incentives that discourage sustainability. The author proposes solutions such as 'negawatt' markets, decoupled utility earnings, and improved informational feedback loops to align profit motives with the preservation of natural capital.

The briefing examines the relationship between electricity efficiency and utility rates, arguing that 'fixed' costs are not static but decline through depreciation. It posits that as long as the rate of electricity saving does not exceed the combined rate of depreciation and demand growth, both rates and bills can decrease. The author contends that focusing on rates rather than total bills is economically inefficient, as efficiency measures reduce the need for costly new plant construction and allow utilities to retire expensive marginal plants first.

The document argues that traditional regulated utilities are well-positioned to meet the renewable energy needs of large commercial and industrial (C&I) customers through green tariffs. It highlights that successful programs have added over 900 MW of solar and wind capacity since 2013. Key success factors include executive sponsorship, continuous customer consultation, and the provision of fixed-price, cost-based energy. The guide emphasizes the need for flexibility in product design and the importance of avoiding unfair cost-shifting to other customers within the utility's service territory.