{"query_echo":{"q":"","filters":{"analysis_type":["least-cost optimization"]},"warnings":[{"code":"facet_value_not_in_vocabulary","message":"Value 'least-cost optimization' for facet 'analysis_type' is not in the controlled vocabulary."}]},"total":{"value":2,"relation":"eq"},"page":1,"page_size":20,"self":"https://climateinsightsdirectory.org/api/v1/search?analysis_type=least-cost+optimization","stability":"beta","ai_marking":{"digital_source_type":{"uri":"http://cv.iptc.org/newscodes/digitalsourcetype/trainedAlgorithmicMedia","name":"Created using Generative AI"},"notice":"Summary and key insights are generated using artificial intelligence."},"results":[{"id":"ucs-000750","url":"https://climateinsightsdirectory.org/document/ucs-000750","title":"Harnessing the Power of Electric Vehicles","publisher":{"name":"Union of Concerned Scientists","organization":"union-of-concerned-scientists"},"document_type":"report","language":"en","date_published":"2025-06","source_url":"https://www.ucs.org/sites/default/files/2025-06/harnessing-the-power-of-evs-full-report.pdf","generator":"Climate Insights Directory","generated_fields":["summary","key_insights","climate_tags","geography_discussed","analysis_type"],"summary":{"text":"The analysis finds that VGI, particularly bidirectional charging (V2G), can generate annual system savings between $1.8 billion and $11.7 billion by 2045. These savings primarily stem from reduced requirements for electricity delivery infrastructure and utility-scale storage. The report recommends that California mandate bidirectional charging capabilities in new EVs and update battery warranties to cover discharging to encourage widespread adoption.","ai_generated":true,"unit":"ucs-000750#summary","date_modified":"2026-10-23"},"key_insights":[{"text":"Vehicle-grid integration (VGI) is projected to generate annual electricity system savings in California by 2045, ranging from $1.8 billion (1 percent of system costs) in low-enrollment V1G scenarios to $11.7 billion (5 percent of system costs) in high-enrollment V2G scenarios.","ai_generated":true,"unit":"ucs-000750#insight-1","date_modified":"2026-10-23"},{"text":"Bidirectional managed charging (V2G) provides significantly higher incremental benefits than unidirectional managed charging (V1G) alone. In a medium enrollment scenario, shifting from 0 percent V2G to 12.5 percent V2G nearly doubles annual savings from $4.2 billion to $7.7 billion.","ai_generated":true,"unit":"ucs-000750#insight-2","date_modified":"2026-10-23"},{"text":"The primary source of VGI savings is the reduced need for electricity delivery infrastructure, specifically by lowering peak demand on the distribution system. High levels of V2G could reduce net peak demand by up to 33 percent for residential and 10 percent for commercial sectors in 2045.","ai_generated":true,"unit":"ucs-000750#insight-3","date_modified":"2026-10-23"},{"text":"VGI helps match charging demand with variable renewable energy production, which reduces the need for utility-scale thermal generation and energy storage. Savings in storage are primarily driven by a reduced requirement for long-duration storage (minimum 24 hours).","ai_generated":true,"unit":"ucs-000750#insight-4","date_modified":"2026-10-23"},{"text":"The grid benefits of V2G can be achieved with minimal impact on battery wear. In a medium VGI enrollment scenario, the average vehicle in the V2G pool would export power equivalent to driving an additional 700 miles per year, representing less than a 7 percent increase in battery use for a vehicle traveling 10,000 miles annually.","ai_generated":true,"unit":"ucs-000750#insight-5","date_modified":"2026-10-23"},{"text":"On a per-vehicle basis, annual grid savings in a medium enrollment scenario range from $503 for all-V1G to $1,177 for all-V2G. Over a vehicle's average lifetime of 12.5 years, cumulative grid savings per vehicle are estimated between $6,300 and $14,700.","ai_generated":true,"unit":"ucs-000750#insight-6","date_modified":"2026-10-23"}],"climate_tags":["electric vehicle","wide area synchronous grid","energy storage","decarbonization","electromobility"],"geography_discussed":["United States"],"frame_perspective":[],"analysis_type":["least-cost optimization","scenario analysis","demand-side modeling"]},{"id":"cer-001404","url":"https://climateinsightsdirectory.org/document/cer-001404","title":"INTEGRATED RESOURCE PLAN 2018","publisher":{"name":"Centre for Environmental Rights","organization":"centre-for-environmental-rights"},"document_type":"report","language":"en","date_published":"2018-08","source_url":"https://cer.org.za/wp-content/uploads/2019/10/Thabametsi-Answering-Affidavit-105-304.pdf?x21779","generator":"Climate Insights Directory","generated_fields":["summary","key_insights","climate_tags","geography_discussed","analysis_type"],"summary":{"text":"The Integrated Resource Plan (IRP) 2018 is a strategic update to South Africa's electricity infrastructure development plan, extending the planning horizon to 2050. It evaluates various energy mix scenarios to balance security of supply, cost, and environmental impact, specifically focusing on the transition from coal to renewable energy and gas. The document also includes a Medium-Term System Adequacy Outlook (MTSAO) for 2018-2023 and a specific climate change and water resources assessment for the proposed Thabametsi coal-fired power station.","ai_generated":true,"unit":"cer-001404#summary","date_modified":"2026-08-17"},"key_insights":[{"text":"The IRP 2018 update was necessitated by changes in key assumptions from the IRP 2010-2030, including electricity demand that \"did not increase as envisaged\", Eskom plant performance falling \"way below the 80% availability factor\", and significant declines in technology costs.","ai_generated":true,"unit":"cer-001404#insight-1","date_modified":"2026-08-17"},{"text":"For the period ending 2030, the committed Renewable Energy Independent Power Producers Programme (REIPPP) and Eskom's capacity rollout (ending with Kusile in 2022) are expected to provide sufficient capacity to cover demand and plant decommissioning until approximately 2025.","ai_generated":true,"unit":"cer-001404#insight-2","date_modified":"2026-08-17"},{"text":"Scenario analysis indicates that removing annual build limits on renewable energy (RE) provides the least-cost electricity path for both the 2030 and 2050 horizons.","ai_generated":true,"unit":"cer-001404#insight-3","date_modified":"2026-08-17"},{"text":"Post-2030 projections show a significant decline in coal's contribution to the energy supply, falling to less than 30% by 2040 and less than 20% by 2050, driven by the decommissioning of 35GW of coal plants by 2050 and emission constraints.","ai_generated":true,"unit":"cer-001404#insight-4","date_modified":"2026-08-17"},{"text":"The recommended plan for the period ending 2030 adopts a least-cost approach but retains annual build limits of 1000MW for PV and 1600MW for wind to ensure a \"smooth roll out of RE\" and sustain the industry.","ai_generated":true,"unit":"cer-001404#insight-5","date_modified":"2026-08-17"},{"text":"The recommended plan includes the addition of 1000MW of coal-to-power in 2023-2024 and 2500MW of hydro power by 2030, the latter to facilitate the RSA-DRC treaty on the Inga Hydro Power Project.","ai_generated":true,"unit":"cer-001404#insight-6","date_modified":"2026-08-17"},{"text":"The Medium-Term System Adequacy Outlook (MTSAO) for 2018-2023 concludes that the system is adequate for all demand scenarios if the Energy Availability Factor (EAF) is 75% or above, but inadequate at 71% regardless of demand growth.","ai_generated":true,"unit":"cer-001404#insight-7","date_modified":"2026-08-17"},{"text":"The proposed Thabametsi coal-fired power station (1200MW) is projected to have a high GHG emission intensity of 1.23 tons of CO2e per MWh, which is 17% higher than the average of Eskom's current fleet.","ai_generated":true,"unit":"cer-001404#insight-8","date_modified":"2026-08-17"},{"text":"The Thabametsi project faces high risks regarding water availability in the water-scarce Lephalale region, relying on the Mokolo Crocodile (West) Water Augmentation Project (MCWAP) phases 1 and 2.","ai_generated":true,"unit":"cer-001404#insight-9","date_modified":"2026-08-17"},{"text":"The Thabametsi project utilizes circulating fluidised bed (CFB) technology and dry cooling, which reduces water demand by up to 15 times compared to conventional wet-cooled stations, but results in higher N2O emissions.","ai_generated":true,"unit":"cer-001404#insight-10","date_modified":"2026-08-17"}],"climate_tags":["energy transition","decarbonization","renewable energy","coal decommissioning","ghg emissions","water scarcity","climate resilience"],"geography_discussed":["Limpopo","Democratic Republic of the Congo"],"frame_perspective":[],"analysis_type":["scenario analysis","least-cost optimization","system adequacy study","environmental impact assessment"]}]}