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The report finds that gas-fired power plants in MISO and SPP frequently operate at a loss, costing ratepayers an estimated $117 million in 2019. This uneconomic generation is most prevalent in steam turbines and gas turbines, often driven by practices like self-scheduling and self-commitment. The authors argue that these inefficiencies, combined with rising fuel costs and the growth of renewables, make gas-fired power an increasingly risky and expensive investment compared to clean energy portfolios.

The report argues that California can reliably reach an 85 percent clean electricity target by 2030 through a diverse portfolio of resources, including offshore wind and geothermal, while retiring significant natural gas capacity. It emphasizes the need to prioritize the retirement of gas plants in disadvantaged communities (DACs) to improve environmental justice. The authors recommend leveraging demand-side resources as a risk mitigation strategy and expanding regional coordination through a West-wide Regional Transmission Organization (RTO) to enhance grid resilience and reduce costs. The report serves as a policy companion to a technical analysis that stress-tested these portfolios against extreme weather events.

The document analyzes the NEW 4.0 project in northern Germany, which demonstrated that a highly industrialized economy can operate on 100% renewable energy using digital management tools and industrial flexibility. It argues that Canada faces similar non-technical barriers—specifically rigid regulatory and financial frameworks—that hinder the integration of clean energy and innovation.

The document argues that new investment in US gas-fired power plants is becoming uneconomic due to the rise of Clean Energy Portfolios (CEPs)—combinations of wind, solar, energy efficiency, demand response, and battery storage. As of late 2021, 88 GW of gas capacity was proposed, but over 50% of proposed new gas plants have been cancelled prior to construction in the last two years. The analysis finds that CEPs are a cheaper option in more than 80% of sites where gas plants are proposed for service by 2030, and at least 70 GW of proposed gas could be economically avoided, potentially saving $22 billion and 873 MMT of CO2. The report highlights significant stranded cost risks, noting that in a central analysis case, 40% of proposed combined cycle gas plants would cost more to operate than a new CEP costs to build within 10 years.

The report finds that most of the 88+ GW of proposed US gas power plants are economically uncompetitive compared to Clean Energy Portfolios (CEPs), which combine wind, solar, storage, energy efficiency, and demand flexibility. At least 70 GW of proposed gas capacity could be avoided using CEPs, potentially saving $22 billion and reducing CO2 emissions by 873 million metric tons over 20 years. The analysis highlights six key headwinds—including declining renewable costs, rising gas prices, and public health impacts—that increase the risk of project cancellations or stranded assets. Specifically, in a central analysis case, 40% of proposed combined cycle (CC) plants would cost more to operate than a new CEP would cost to build within 10 years, a figure that could rise to 80-90% under certain economic scenarios. The report also notes that CEPs create more jobs and avoid significant health costs, particularly in low-income communities and communities of color.

The document argues that demand-side flexibility (DSF) is essential for integrating intermittent renewables and managing the electrification of transport, buildings, and industry. It highlights that while large industrial users have traditionally provided flexibility, residential and small business consumers have significant untapped potential through assets like electric vehicles (EVs) and heat pumps. Using the UK as a primary example, the brief identifies barriers such as inadequate economic signals and passive consumer behavior, and suggests enablers including smart metering, market reform, and digital aggregation platforms. For China, the authors recommend a 'hybrid approach' combining market-based pricing with administrative scheduling to transition away from a reliance on coal-fired power for system flexibility, while emphasizing the need for pilots to understand consumer preferences.

The document examines the 'digital divide' in the U.S., where rural and tribal areas lack high-speed internet access due to high deployment costs, limited competition, and affordability issues. It highlights how broadband is a prerequisite for smart home devices, precision agriculture, and smart grids, which can reduce energy use by 12–22%. The brief details various deployment initiatives by municipalities, tribal governments, and electric cooperatives, while reviewing federal funding programs and recent legislation aimed at achieving universal broadband access.

The report by ClientEarth, WWF Italy, and ECCO think tank opposes Enel's plan to convert the Federico II plant in Brindisi from coal to gas. It argues that the project is not needed for security of supply, risks creating stranded assets and overcapacity in Southern Italy, and causes adverse climate impacts through CO2 and methane emissions. The authors contend that the project contradicts EU and national decarbonisation goals and should be rejected by the Ministry for Ecological Transition.

ClientEarth argues that the EU is overinvesting in methane gas infrastructure and urges the Commission to implement a methane product standard by 2025 to integrate climate costs into gas prices. The document recommends that public financial support for methane gas or gas-derived hydrogen be precluded or strictly conditioned on carbon capture and storage (CCS) and lifecycle emission caps. It further calls for institutional reform to ensure independent energy system planning, the prioritisation of energy efficiency over new infrastructure, and the cessation of the term 'natural gas' to avoid greenwashing.

The United States faces a deficit in public direct current fast-charging (DCFC) infrastructure, with only 17,000 plugs currently installed. The report highlights that current economics limit growth to a few high-traffic locations, potentially creating an inequitable system where lower-income drivers without home charging pay a significant price premium. In contrast, China has scaled its network to over 309,000 public fast-charging plugs by treating charging as a national priority since 2014. China's strategy included stimulating demand through the electrification of taxis and fleets, reforming utility tariffs to allow industrial rates, capping service fees, and providing installation subsidies. These efforts led to significant economies of scale, reducing the cost of a 50 kW DCFC unit to approximately $3,000, compared to $20,000–$35,000 in the United States. The author suggests the U.S. needs national and local goals, redesigned utility rates, and a focus on equitable access to achieve a similar transition.

ClientEarth argues that EU State aid rules must be transformed into sustainability instruments that prohibit support for fossil fuels and harmful biomass, while prioritizing energy efficiency and renewable energy. The document calls for the strict application of the 'Energy Efficiency First' principle, the exclusion of low-carbon (fossil gas-based) hydrogen from subsidies, and the removal of aid for high-efficiency combined heat and power (CHP) plants. It further recommends increasing support for energy communities, zero-emission vehicles, and energy efficiency in buildings, while introducing a 'greenwashing test' to ensure the environmental integrity of aid beneficiaries.

ClientEarth contends that Belgium's proposed capacity remuneration mechanism (CRM) is legally non-compliant and unnecessary. The organization argues that the national resource adequacy assessment (NRAA) fails to follow ACER's methodology, ignores the absence of price caps, and overstates adequacy concerns. Furthermore, ClientEarth asserts that the CRM's support for new gas capacity contradicts the European Green Deal and Belgium's own climate neutrality goals for 2050, and that the scheme lacks a required phase-out provision.

Following the rejection of the Northeast Supply Enhancement gas pipeline, New York faces a projected gas supply gap in its downstate region. While National Grid proposes a combination of LNG vaporization and gas compression upgrades, the document argues that these infrastructure investments are incompatible with the Climate Leadership and Community Protection Act (CLCPA). It asserts that the state must slash gas demand by approximately 25 percent by 2030 and that investing in electrification, demand response, and energy efficiency is the most cost-effective path to ensure reliability and meet decarbonization goals.

The report uses the WIS:dom-P optimization model to compare four capacity expansion scenarios for the Southeast US: the current SE IRP, an economic IRP without an RTO, an SE RTO, and an SE RTO that retains uneconomic nuclear plants. The findings indicate that the SE RTO scenario is the most economic, offering cumulative savings of $383.7 billion by 2040 and the highest job creation. Retaining nuclear plants further reduces emissions, saving an additional 156.76 million metric tonnes of CO2 by 2040 at a minimal additional cost. The study also highlights the role of variable renewable energy (VRE) and storage in meeting seasonal demand peaks and the importance of transmission expansion in a coordinated regional market.

The policy brief examines how the shift toward variable renewable energy and distributed energy resources (DERs) challenges traditional grid planning paradigms. It argues that the historical reliance on the Planning Reserve Margin (PRM) heuristic is increasingly inadequate for ensuring reliability in a high-renewables system. Furthermore, it warns that fossil fuel incumbents are exploiting these planning uncertainties to protect their market share by framing technical challenges as insurmountable barriers to decarbonization.

The report argues that current utility regulation is incompatible with an all-electric future and proposes ten strategies to decarbonize US buildings. It emphasizes electrification via heat pumps as the primary solution, warning that alternative fuels like biomethane are costly and limited in scale. Key recommendations include reforming electricity rate designs, updating energy efficiency standards to account for total emissions, and proactively managing the retirement of gas infrastructure to avoid stranded asset risks and inequitable cost burdens on low-income customers.

The policy brief outlines a pathway for the U.S. to reach 90 percent zero carbon electricity by 2035, leveraging falling costs of solar, wind, and batteries. It asserts that this transition could support $1.7 trillion in investment and 530,000 annual energy jobs without increasing customer bills. However, it warns that without policy intervention, zero carbon sources would only reach 53 percent by 2035. The authors propose specific regulatory actions for FERC and RTO/ISOs, including simplifying interconnection rules, reforming transmission cost allocation, enhancing energy price signals, and reducing reliance on capacity markets.

This guide outlines six strategies for homeowners to save money and reduce carbon emissions during the COVID-19 crisis: optimizing thermostat settings, switching to LED lighting, scheduling appliance use during low-emissions periods, reviewing utility rate structures, planning for the removal of gas appliances, and improving indoor air quality by opening windows.

The policy brief contends that the proposed $1 billion Northeast Supply Enhancement Project (NESE) gas pipeline is incompatible with New York's Climate Leadership and Community Protection Act (CLCPA). It argues that a 'no infrastructure' approach—combining energy efficiency, electrification (specifically heat pumps), and demand response—is a more cost-effective and reliable path to meeting energy needs while reducing emissions. The author asserts that National Grid's cost analysis underestimates the benefits of customer-focused solutions by ignoring air conditioner cost savings, externality costs of pollution, and the long-term savings beyond a 15-year net present value calculation.

The report argues that flexibility needs in India's electricity system are growing faster than energy demand, particularly under high renewable energy scenarios. It finds that a balanced portfolio of demand-side flexibility, powerplant upgrades, and energy storage can reduce total system costs by 5% to 8% and carbon emissions by 8% to 12% compared to a base case. The analysis highlights regional disparities, noting that states like Karnataka and Tamil Nadu face higher curtailment risks, and emphasizes the need for updated market designs, business models, and infrastructure to unlock these flexibility options.