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This report examines the critical role of modeling details and assumptions that transmission planners frequently ignore. We first provide an overview of the wide array of choices planners have when designing traditional transmission planning models. We then discuss how planners need to rethink these choices to account for the rapidly evolving energy system and the additional uncertainties climate change brings. Finally, we present a modeling case study to show how important these modeling choices could be for transmission outcomes.

On March 21, 2022, the Securities and Exchange Commission (SEC) proposed a rule that would require SEC registrants (both domestic and foreign) to provide climate-related disclosures in certain SEC filings. Since the release of the SEC Proposal in March 2022, other jurisdictions, including California and the European Union, have adopted climate-related disclosure regimes. Like many federal rules, the SEC Proposal included an assessment of its costs and benefits. This report examines how the California and E.U. disclosure regimes may affect the baseline for that cost-benefit analysis and, consequently, the SEC’s assessment of the incremental costs and benefits of its proposal. Overall, we find that the new disclosure regimes do not undermine the economic case for the SEC Proposal; if anything, they bolster it.

Many states and other jurisdictions are grappling with how to value greenhouse gas emission reductions and trying to understand the rapidly developing climate economics and science involved in this task. Frequently, state governments and other jurisdictions value greenhouse gas emissions in policymaking using a tool known as the social cost of carbon.

While applying the social cost of carbon is conceptually simple, the appropriate value to place on the metric is in flux. In late 2022, the federal government released new, updated values of the social cost of carbon in draft form which, for now, remain unfinalized. So what estimates of the social cost of carbon should states and other entities use during this transition period? This policy brief explores the available options.

Several recent developments in administrative law—namely the Supreme Court’s embrace of the major questions doctrine and decision to hear a case asking it to overrule or clarify Chevron deference—have left federal agencies uncertain about how regulations will fare in litigation. Agencies adapting to this uncertainty may want to pay closer attention to recent case law on administrative severability, which allows a court to sever the invalid portion of a rule while leaving the rest intact.

The devastating 2021 blackout in Texas, among others, has highlighted the need to reform electricity markets to make them resilient to extreme weather events. In this paper, we review related efforts by system planners and operators within electricity market contexts, focusing on Europe and the United States, and we analyze possible reforms to electricity capacity markets. To account for extreme weather events, capacity requirements and markets, along with other regulatory measures throughout the electricity and fuel supply chains, should be modified. First, capacity requirements must be tailored to the specific severe weather failure modes applicable to a given power system to achieve policymakers' reliability and resiliency objectives: reducing the frequency, magnitude and duration of blackouts. Second, all capacity requirements should be cost-effective and integrated with other non-capacity resources and requirements, such as transmission, distribution and other infrastructure systems. Third, for a capacity market to produce the desired efficiency benefits, the product (capacity) must be well-defined and backed by sufficient credit and other policies to ensure providers have sufficient incentives to perform when called.

Congress often relies on agencies to fill in the details of its transfer programs with regulations, such as those setting eligibility criteria for healthcare, housing, and nutritional assistance. This Article uses three recent rulemakings to illustrate how conventional cost-benefit analysis tends to obscure rather than illuminate agencies’ (often distributional) reasons for issuing such transfer regulations—generating unnecessary legal risk for the agencies and unnecessary confusion for the public. The Article then explains why recently proposed revisions to White House guidance on cost-benefit analysis—including the introduction of an analytic technique called income-based distributional weighting—will not fully resolve this problem. Finally, the Article recommends a new analytic framework for transfer regulations that recognizes the particular relevance of distributional concerns to their promulgation and the distinct challenges of assessing their net benefits.

A critical input in cost-benefit analysis is the discount rate, which determines how much impacts in the future are weighted relative to impacts in the present. Federal guidance currently calls on U.S. agencies to apply discount rates of 3% and 7%. But these rates, particularly the 7% rate, substantially devalue impacts that accrue to future generations, thus putting a thumb on the scale against policies that provide long-term benefits such as environmental and public-health regulation. In April, the Office of Management and Budget (OMB) proposed a comprehensive update to that guidance document, known as Circular A-4. Among other revisions, the draft would update the default discount rate used in federal regulatory analysis to 1.7%. In a letter published in Science, leading global experts on discount rates and cost-benefit analysis support the proposed revision.

The Supreme Court’s recent applications of the major questions doctrine have prompted numerous challenges to pending or proposed regulatory actions, including the Federal Energy Regulatory Commission’s (FERC’s) proposed revisions to Order No. 1000’s regional transmission-planning and cost-allocation rules (Transmission Rulemaking) and updated draft policy statements on certification of new interstate natural gas facilities (Draft Policy Statements). This article addresses the impact of West Virginia v. EPA—the most recent Supreme Court case involving the major questions doctrine—on FERC’s regulatory authority.

Integration of Distributed Energy Resources (DERs) in power systems exacerbates the existing information problems between power utilities and regulators. DER policies oblivious to the trilemma of information asymmetry between power utilities, DER aggregators, and regulators result in distorted price signals to DER investors, and socially inefficient DER roll-out. Therefore, in this paper, a game-theoretic approach is proposed for modeling information asymmetry in distribution network information and consumer data between the DER aggregators and the power utilities.