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The study finds that while solar PV is the backbone of Nigeria's net-zero electricity system, the lowest-cost and most reliable pathways require a technology-neutral approach that includes nuclear power and natural gas with carbon capture and storage (CCS). Restricting these firm low-carbon technologies increases total installed capacity by approximately 50% and annual investment requirements by about 7%. Under baseline demand, net-zero timelines require average annual investments of US$7–10 billion, but a high-demand scenario aligned with Nigeria Agenda 2050 would increase average annual investment to US$35.8 billion and nearly triple total system costs.

The report argues that next-generation geothermal technologies, specifically Enhanced Geothermal Systems (EGS) and closed-loop systems, can expand U.S. geothermal resource potential from 40 GW to over 5,000 GW by engineering reservoirs in ubiquitous hot rock. It outlines a two-phase pathway: reaching 'liftoff' by 2030 through 2-5 GW of deployment across 5-10 geologic settings, followed by scaling to 90-132 GW by 2050. Key barriers identified include high up-front capital costs, long federal permitting timelines (7-10 years), and the need for power purchase agreements (PPAs) that value clean firm and flexible power. The report highlights that the industry can leverage the existing oil and gas workforce and supply chain to accelerate deployment.

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 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 finds that achieving an 80% non-fossil electricity share by 2035 is technically feasible and would lower wholesale electricity costs compared to current policy trajectories. This transition would be driven by the declining costs of wind, solar, and battery storage, which the authors argue are now more cost-effective than new coal generation. The 'Clean Energy' scenario would significantly reduce CO2 emissions and premature deaths from air pollution, while resulting in a net increase in employment, despite losses in the coal mining sector. Reliability analysis suggests the system can maintain a 10% operating reserve margin even with high variable renewable penetration and the retirement of 250 to 300 GW of coal capacity.