{"query_echo":{"q":"","filters":{"geography":["MISO"]},"warnings":[{"code":"facet_value_not_in_vocabulary","message":"Value 'MISO' for facet 'geography' is not in the controlled vocabulary."}]},"total":{"value":9,"relation":"eq"},"page":1,"page_size":20,"self":"https://climateinsightsdirectory.org/api/v1/search?geography=MISO","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":"rmi-000273","url":"https://climateinsightsdirectory.org/document/rmi-000273","title":"The Interconnection Queue Continues to Be a Barrier to US Economic Competitiveness","publisher":{"name":"RMI","organization":"rmi"},"document_type":"policy brief","language":"en","date_published":"2026-03-17","source_url":"https://rmi.org/resources/interconnection-reform-ai-data-centers-generator-queues/","generator":"Climate Insights Directory","generated_fields":["summary","key_insights","climate_tags","geography_discussed","analysis_type"],"summary":{"text":"The US faces a critical bottleneck in connecting new electricity generation and storage to the grid, with over 2.2 terawatts of projects currently in queues. While the US Department of Energy has pushed for streamlined load interconnection for data centers, the author argues that this is insufficient without parallel reforms to generator interconnection. Current processes are characterized by long delays—averaging nearly five years from request to operation in 2024—and high network upgrade costs that often exceed 10% of project capex, leading to high attrition rates. The brief proposes several solutions: adopting advanced AI and automation software for studies, integrating Grid-enhancing technologies (GETs) to reduce costs, improving transparency in network upgrade construction, and implementing 'fast track' pathways such as energy-only interconnection, surplus interconnection service, and generator replacement.","ai_generated":true,"unit":"rmi-000273#summary","date_modified":"2026-10-23"},"key_insights":[{"text":"The US generator interconnection queue is severely congested, with more than 2.2 terawatts of generation and storage projects awaiting connection, which is nearly double the current installed grid capacity.","ai_generated":true,"unit":"rmi-000273#insight-1","date_modified":"2026-10-23"},{"text":"Interconnection timelines have increased significantly; the average time from the initial request to commercial operation rose to nearly five years in 2024, compared to less than two years in 2008.","ai_generated":true,"unit":"rmi-000273#insight-2","date_modified":"2026-10-23"},{"text":"High costs for network upgrades are a primary driver of project attrition, with developers often withdrawing from the queue when these costs exceed approximately 10% of the project's total capital expenditure.","ai_generated":true,"unit":"rmi-000273#insight-3","date_modified":"2026-10-23"},{"text":"Only a small minority of projects that requested interconnection between 2000 and 2019 actually reached commercial operation by the end of 2024, specifically 19%.","ai_generated":true,"unit":"rmi-000273#insight-4","date_modified":"2026-10-23"},{"text":"The use of Grid-enhancing technologies (GETs) in the PJM region could potentially allow 6.6 GW of new generation to connect more quickly, resulting in roughly $1 billion in annual production cost savings for an installation cost of $0.1 billion.","ai_generated":true,"unit":"rmi-000273#insight-5","date_modified":"2026-10-23"},{"text":"FERC Order 2023 introduced initial reforms such as cluster studies and deadlines for studies with financial penalties, but the author contends these are insufficient to meet the needs of significant upcoming load growth.","ai_generated":true,"unit":"rmi-000273#insight-6","date_modified":"2026-10-23"}],"climate_tags":["electric power transmission","wide area synchronous grid","energy storage","data center"],"geography_discussed":["PJM","MISO","California ISO","Southwest Power Pool"],"frame_perspective":[],"analysis_type":["policy brief"]},{"id":"rmi-000143","url":"https://climateinsightsdirectory.org/document/rmi-000143","title":"The State of Utility Planning, 2024 Q4","publisher":{"name":"RMI","organization":"rmi"},"document_type":"report","language":"en","date_published":"2025-01-15","source_url":"https://rmi.org/resources/the-state-of-utility-planning-2024-q4/","generator":"Climate Insights Directory","generated_fields":["summary","key_insights","climate_tags","geography_discussed","analysis_type"],"summary":{"text":"In Q4 2024, US utilities updating their IRPs reduced planned wind and solar capacity by 20 GW and increased planned gas capacity by 12 GW, leading to an 8 percent increase in projected emissions despite a small downward adjustment in projected load.","ai_generated":true,"unit":"rmi-000143#summary","date_modified":"2026-10-23"},"key_insights":[{"text":"Utilities that updated their IRPs in Q4 2024 increased projected emissions by 8 percent, driven by a 12 GW increase in planned gas plants and a 20 GW reduction in planned wind and solar capacity by 2035.","ai_generated":true,"unit":"rmi-000143#insight-1","date_modified":"2026-10-23"},{"text":"While Q4 2024 marked the first time since 2021 that utilities observed a decrease in projected load in IRP updates, overall US IRPs still anticipate load to grow 20 percent by 2035 compared to 2021 levels.","ai_generated":true,"unit":"rmi-000143#insight-2","date_modified":"2026-10-23"},{"text":"There is a significant gap between current utility projections and net-zero pathways; while the IEA NZE scenario requires net-zero electricity emissions by 2035, current IRPs project a reduction of only 56 percent by 2035 compared to a 2005 baseline.","ai_generated":true,"unit":"rmi-000143#insight-3","date_modified":"2026-10-23"},{"text":"Utilities cited interconnection difficulties, strict reliability needs for data centers, and changing capacity accreditation rules in the Midcontinent Independent System Operator (MISO) and Southwest Power Pool (SPP) as reasons for scaling back wind and solar plans.","ai_generated":true,"unit":"rmi-000143#insight-4","date_modified":"2026-10-23"},{"text":"Between 2023 and 2035, current planned capacity in US IRPs includes 260 GW of wind and solar additions, 84 GW of gas additions, and 74 GW of coal retirements.","ai_generated":true,"unit":"rmi-000143#insight-5","date_modified":"2026-10-23"}],"climate_tags":["electricity supply company","wind power","solar energy","natural gas","greenhouse gas emissions","data center","Net-zero emissions","Inflation Reduction Act of 2022","energy storage","demand-side management"],"geography_discussed":["MISO","SPP"],"frame_perspective":[],"analysis_type":["quantitative review","trend analysis"]},{"id":"rmi-000235","url":"https://climateinsightsdirectory.org/document/rmi-000235","title":"How Utility Regulators Can Unlock $12.7 Billion in Annual Savings for Customers","publisher":{"name":"RMI","organization":"rmi"},"document_type":"policy brief","language":"en","date_published":"2024-02-14","source_url":"https://rmi.org/resources/how-utility-regulators-can-unlock-12-7-billion-in-annual-savings-for-customers/","generator":"Climate Insights Directory","generated_fields":["summary","key_insights","climate_tags","geography_discussed","analysis_type"],"summary":{"text":"The policy brief advocates for 'clean repowering'—the strategy of siting new renewable energy projects at existing or retiring fossil fuel plant interconnection points—to reduce interconnection times from nearly five years to less than one year. RMI's analysis indicates this approach could enable 250 GW of new renewable energy without transmission upgrades, resulting in average national savings of $12.7 billion annually from 2025 to 2035. The brief highlights the role of the Inflation Reduction Act (IRA) and the Energy Infrastructure Reinvestment (EIR) program in making these projects financially viable and provides specific recommendations for regulators to ensure these savings reach customers through integrated resource planning and oversight.","ai_generated":true,"unit":"rmi-000235#summary","date_modified":"2026-10-23"},"key_insights":[{"text":"Clean repowering allows new renewable energy projects to bypass the standard interconnection process, which can take nearly five years, reducing the time to connect to the grid to less than one year by using existing fossil asset interconnection rights.","ai_generated":true,"unit":"rmi-000235#insight-1","date_modified":"2026-10-23"},{"text":"The clean repowering strategy, supported by Inflation Reduction Act (IRA) incentives, has the potential to add 250 GW of new renewable energy projects without requiring transmission upgrades, leading to average national savings of $12.7 billion per year for 10 years starting in 2025.","ai_generated":true,"unit":"rmi-000235#insight-2","date_modified":"2026-10-23"},{"text":"Vertically integrated utilities are projected to achieve $46 billion in net present value (NPV) savings between now and 2054. Specifically, 18 utilities could see NPV savings in the billions, with the highest opportunities located in the Southeast region, PJM, and MISO.","ai_generated":true,"unit":"rmi-000235#insight-3","date_modified":"2026-10-23"},{"text":"In Louisiana, Entergy could achieve $2.8 billion in NPV savings by reducing the operation of its coal and gas fleet and investing in renewables. Specifically, the Nine Mile Points gas plant (2 GW) could support 1,713 MW of solar, and the R S Nelson coal plant (600 MW) could avoid 383,555 tons of CO2 annually by adding 101 MW of solar and 224 MW of wind.","ai_generated":true,"unit":"rmi-000235#insight-4","date_modified":"2026-10-23"},{"text":"The Inflation Reduction Act (IRA) and the Department of Energy's Energy Infrastructure Reinvestment (EIR) program provide the tax credits and low-cost financing necessary to offset the up-front costs of clean energy and the costs associated with more frequent ramping and start-ups.","ai_generated":true,"unit":"rmi-000235#insight-5","date_modified":"2026-10-23"}],"climate_tags":["renewable energy","solar energy","wind power","wide area synchronous grid","Inflation Reduction Act of 2022","Integrated resource planning","carbon dioxide emissions","utility regulation"],"geography_discussed":["Louisiana","MISO","PJM","Southeast region"],"frame_perspective":[],"analysis_type":["economic analysis","policy analysis"]},{"id":"rmi-000656","url":"https://climateinsightsdirectory.org/document/rmi-000656","title":"Clean Repowering: A Near-Term, IRA-Powered Energy Transition Accelerant","publisher":{"name":"RMI","organization":"rmi"},"document_type":"report","language":"en","date_published":"2024-01-16","source_url":"https://rmi.org/resources/clean-repowering-a-near-term-ira-powered-energy-transition-accelerant/","generator":"Climate Insights Directory","generated_fields":["summary","key_insights","climate_tags","geography_discussed","analysis_type"],"summary":{"text":"The report identifies a 250 GW potential for 'clean repowering' in the United States, where new clean energy projects are sited at existing interconnection points to bypass interconnection delays and leverage Inflation Reduction Act (IRA) incentives. It highlights two primary pathways: 'Surplus Interconnection Service' for adding capacity to operating plants and 'Generator Replacement' for replacing retiring plants. These strategies aim to reduce interconnection timelines from years to months while supporting energy communities through tax credits and loan guarantees.","ai_generated":true,"unit":"rmi-000656#summary","date_modified":"2026-10-23"},"key_insights":[{"text":"Analysis indicates there is 250 GW of potential for clean repowering projects across the United States to accelerate the energy transition.","ai_generated":true,"unit":"rmi-000656#insight-1","date_modified":"2026-10-23"},{"text":"Clean repowering projects can utilize specific Inflation Reduction Act (IRA) incentives, including a 10 percent tax credit bonus for projects in energy communities (such as brownfield sites or coal closure communities) and up to $250 billion in loan guarantees via the DOE-administered Energy Infrastructure Reinvestment (EIR) program, which must be committed by 2026.","ai_generated":true,"unit":"rmi-000656#insight-2","date_modified":"2026-10-23"},{"text":"The 'Surplus Interconnection Service' process allows for adding new generation at an existing plant's site using 'spare' interconnection rights; this FERC-regulated process is available in most of the U.S. except for NYISO and ERCOT.","ai_generated":true,"unit":"rmi-000656#insight-3","date_modified":"2026-10-23"},{"text":"The 'Generator Replacement' process enables new generation to replace a retiring plant without exceeding its interconnection rights, though this is only available in specific regions such as SPP, MISO, and certain utility territories because there is no standard FERC order.","ai_generated":true,"unit":"rmi-000656#insight-4","date_modified":"2026-10-23"}],"climate_tags":["energy storage","Inflation Reduction Act of 2022","wide area synchronous grid","energy infrastructure"],"geography_discussed":["ERCOT","NYISO","MISO","SPP"],"frame_perspective":[],"analysis_type":["policy analysis","capacity assessment"]},{"id":"ucs-001234","url":"https://climateinsightsdirectory.org/document/ucs-001234","title":"Used, But How Useful?","publisher":{"name":"Union of Concerned Scientists","organization":"union-of-concerned-scientists"},"document_type":"report","language":"en","date_published":"2020-05","source_url":"https://www.ucs.org/sites/default/files/2020-05/Used%20but%20How%20Useful%20May%202020.pdf","generator":"Climate Insights Directory","generated_fields":["summary","key_insights","climate_tags","geography_discussed","analysis_type"],"summary":{"text":"The report argues that rate-regulated utilities use 'self-commitment' to bypass market merit order, running coal plants that are objectively uneconomic and passing the resulting losses to captive customers through state fuel-cost-recovery processes. Using PLEXOS modeling for the MISO region in 2018, the authors find that this practice cost customers $350 million and suppressed regional market clearing prices by 2.4%. The report identifies Cleco and DTE Energy as significant contributors to these distortions and recommends that state regulators disallow the recovery of imprudent, above-market costs to incentivize efficient dispatch.","ai_generated":true,"unit":"ucs-001234#summary","date_modified":"2026-10-23"},"key_insights":[{"text":"In 2018, the uneconomic self-commitment of coal plants in the MISO region resulted in costs of $350 million for customers, which equates to an average annual increase of approximately $60 on residential electric bills.","ai_generated":true,"unit":"ucs-001234#insight-1","date_modified":"2026-10-23"},{"text":"The practice of self-committing coal plants artificially lowers market clearing prices across all MISO transmission zones, reducing the regional average by $0.63 per MWh, or 2.4%.","ai_generated":true,"unit":"ucs-001234#insight-2","date_modified":"2026-10-23"},{"text":"While most coal resources in MISO are self-committed, a small group of companies and plants drive the majority of market distortion; Cleco (co-owner of Dolet Hills) and DTE Energy are identified as the worst actors.","ai_generated":true,"unit":"ucs-001234#insight-3","date_modified":"2026-10-23"},{"text":"Eliminating uneconomic self-commitment in MISO would have increased the system's market surplus by 66%, rising from $1.5 billion to $2.5 billion, thereby improving overall market efficiency and profitability for power plants.","ai_generated":true,"unit":"ucs-001234#insight-4","date_modified":"2026-10-23"},{"text":"Rate-regulated utilities can exploit the self-commitment loophole because they can recover market losses through state fuel-cost-recovery processes, a financial cushion not available to independent power providers (IPPs).","ai_generated":true,"unit":"ucs-001234#insight-5","date_modified":"2026-10-23"},{"text":"The traditional view of coal as a 'baseload resource' is outdated; current MISO data shows coal plants often cycle to follow load patterns and frequently operate when the cost to burn coal exceeds the market price.","ai_generated":true,"unit":"ucs-001234#insight-6","date_modified":"2026-10-23"},{"text":"Some utilities, such as Xcel Energy and Cleco, have begun reducing uneconomic dispatch by converting coal plants to seasonal operations, which the report suggests can save customers tens of millions of dollars.","ai_generated":true,"unit":"ucs-001234#insight-7","date_modified":"2026-10-23"},{"text":"The report concludes that market rule reforms alone are unlikely to stop the behavior; instead, state regulators must disallow the recovery of imprudent, above-market costs to create a real incentive for utilities to operate economically.","ai_generated":true,"unit":"ucs-001234#insight-8","date_modified":"2026-10-23"}],"climate_tags":["coal-fired power station","electricity market","energy transition","economic dispatch"],"geography_discussed":["PJM Interconnection","Southwest Power Pool","Electric Reliability Council of Texas","Louisiana","Texas","North Dakota","Michigan","Minnesota","Illinois","Iowa","Arkansas","Missouri","Mississippi","Kentucky","Indiana","Wisconsin"],"frame_perspective":[],"analysis_type":["economic modeling","policy analysis"]},{"id":"eninnova-000032","url":"https://climateinsightsdirectory.org/document/eninnova-000032","title":"THE DEPARTMENT OF ENERGY’S GRID RESILIENCE PRICING PROPOSAL: A COST ANALYSIS","publisher":{"name":"Energy Innovation","organization":"energy-innovation"},"document_type":"research paper","language":"en","date_published":"2017-10","source_url":"https://energyinnovation.org/wp-content/uploads/20171021_Resilience-NOPR-Cost-Research-Note-FINAL.pdf","generator":"Climate Insights Directory","generated_fields":["summary","key_insights","climate_tags","geography_discussed","analysis_type"],"summary":{"text":"The research note analyzes four implementation scenarios for the DOE's Grid Resilience Notice of Proposed Rulemaking (NOPR), which would compensate coal and nuclear plants for costs not recovered in wholesale markets. The analysis finds that annual customer costs could range from $311 million to $10.6 billion, with a high concentration of benefits accruing to a small number of companies, particularly in the PJM region.","ai_generated":true,"unit":"eninnova-000032#summary","date_modified":"2026-10-23"},"key_insights":[{"text":"Depending on the implementation scenario, the DOE's proposal could increase annual costs for electricity customers by between $311 million and $10.6 billion.","ai_generated":true,"unit":"eninnova-000032#insight-1","date_modified":"2026-10-23"},{"text":"The financial benefits of the proposed subsidies are highly concentrated, with over 80% of coal subsidies and nearly 90% of nuclear subsidies going to five or fewer companies.","ai_generated":true,"unit":"eninnova-000032#insight-2","date_modified":"2026-10-23"},{"text":"PJM is identified as the region that would experience the highest cost increases, potentially reaching $7.3 billion per year, which represents more than 17% of its total 2015 billing costs.","ai_generated":true,"unit":"eninnova-000032#insight-3","date_modified":"2026-10-23"},{"text":"Specific companies stand to gain significantly: NRG could see annual revenue increases between $40 million and $1.2 billion for coal units, while Exelon could see increases from $0.1 billion to $3.6 billion for nuclear units.","ai_generated":true,"unit":"eninnova-000032#insight-4","date_modified":"2026-10-23"},{"text":"The analysis considers four 'readings' of the NOPR: Reading 1 (uplift for cash flow negative units), Reading 2 (recovery of capital and fixed O&M after market revenue), Reading 3 (recovery of uncompensated capital and fixed O&M in addition to market revenue), and Reading 4 (Reading 3 plus uneconomic dispatch costs).","ai_generated":true,"unit":"eninnova-000032#insight-5","date_modified":"2026-10-23"}],"climate_tags":["coal power","nuclear power","Resilience (power system)","energy subsidy","energy price"],"geography_discussed":["PJM","ISO-NE","NYISO","MISO"],"frame_perspective":[],"analysis_type":["cost analysis","policy assessment"]},{"id":"ucs-000291","url":"https://climateinsightsdirectory.org/document/ucs-000291","title":"Beyond the Clean Power Plan","publisher":{"name":"Union of Concerned Scientists","organization":"union-of-concerned-scientists"},"document_type":"report","language":"en","date_published":"2016-01-28","source_url":"https://www.ucs.org/sites/default/files/attach/2016/02/beyond-the-clean-power-plan-full-report.pdf","generator":"Climate Insights Directory","generated_fields":["summary","key_insights","climate_tags","geography_discussed","analysis_type"],"summary":{"text":"The report analyzes the Eastern Interconnection Planning Collaborative (EIPC) study to demonstrate that aggressive carbon reductions in the U.S. electric sector are achievable with minimal additional cost. By re-evaluating EIPC data, Synapse Energy Economics found that a 'Carbon Reduction' scenario—featuring massive wind build-out and coal retirements—costs approximately the same as a 'Business as Usual' scenario when carbon revenues are recycled. The analysis shows that this path would allow the MISO and PJM regions to significantly over-comply with the Clean Power Plan's emissions targets while maintaining grid reliability.","ai_generated":true,"unit":"ucs-000291#summary","date_modified":"2026-10-23"},"key_insights":[{"text":"The Carbon Reduction (S1) scenario can achieve an 80 percent reduction in electric sector CO2 emissions by 2030 compared to the Business as Usual (S3) scenario.","ai_generated":true,"unit":"ucs-000291#insight-1","date_modified":"2026-10-23"},{"text":"A re-analysis by Synapse indicates that the total ratepayer costs for the Carbon Reduction scenario are nearly identical to the Business as Usual scenario, being only about 2 percent higher, provided carbon trading revenues are recycled back into the electric sector.","ai_generated":true,"unit":"ucs-000291#insight-2","date_modified":"2026-10-23"},{"text":"The Carbon Reduction scenario requires a substantial transmission build-out, with the majority of new line mileage located in the MISO and SPP regions.","ai_generated":true,"unit":"ucs-000291#insight-3","date_modified":"2026-10-23"},{"text":"In the MISO region, the Carbon Reduction scenario involves building over 100 GW of new wind capacity and retiring approximately 60 GW of coal units by 2030, resulting in emissions that are significantly lower than the Clean Power Plan's mass-based targets.","ai_generated":true,"unit":"ucs-000291#insight-4","date_modified":"2026-10-23"},{"text":"In the PJM region, the Carbon Reduction scenario predicts the retirement of 80 GW of coal capacity by 2030, leading to emissions levels less than half of what is allowed under the Clean Power Plan.","ai_generated":true,"unit":"ucs-000291#insight-5","date_modified":"2026-10-23"},{"text":"The Carbon Reduction scenario provides significant co-benefits in criteria emissions, avoiding over 1 million tons of NOx and 1.7 million tons of SO2 by 2030.","ai_generated":true,"unit":"ucs-000291#insight-6","date_modified":"2026-10-23"},{"text":"Updated data on wind capital costs suggests the Carbon Reduction scenario is even more economical than originally modeled; using DOE Wind Vision costs could reduce the scenario's cost by more than $100 billion.","ai_generated":true,"unit":"ucs-000291#insight-7","date_modified":"2026-10-23"},{"text":"The EIPC modeling suffered from a lack of co-optimization between transmission and generation, meaning the resulting transmission build-out for the Carbon Reduction scenario is likely not economically optimal.","ai_generated":true,"unit":"ucs-000291#insight-8","date_modified":"2026-10-23"}],"climate_tags":["carbon dioxide emissions","electric power transmission","wind power","energy efficiency","demand response","Clean Power Plan","Renewable portfolio standard","climate finance"],"geography_discussed":["MISO","PJM","SPP","United States","Canada"],"frame_perspective":[],"analysis_type":["cost-benefit analysis","scenario modeling","policy assessment"]},{"id":"eninnova-000075","url":"https://climateinsightsdirectory.org/document/eninnova-000075","title":"Data Center Demand Flexibility","publisher":{"name":"Energy Innovation","organization":"energy-innovation"},"document_type":"fact sheet","language":"en","date_published":null,"source_url":"https://energyinnovation.org/wp-content/uploads/Data-Center-Demand-Flexibility.pdf","generator":"Climate Insights Directory","generated_fields":["summary","key_insights","climate_tags","geography_discussed","analysis_type"],"summary":{"text":"The document outlines how data centers can increase electricity demand flexibility by shifting workloads, reducing operations, or using onsite storage. It highlights that without policy changes, data center growth could lead to 25-50 GW of additional fossil generation by 2030. Conversely, curtailing just 0.5 percent of annual electricity use could allow 100 GW of load to be added nationwide without new peak resources. Proposed policy tools include tying tax incentives to demand response participation, enabling faster interconnection for flexible facilities, and implementing utility rates that align costs with system impact.","ai_generated":true,"unit":"eninnova-000075#summary","date_modified":"2026-10-23"},"key_insights":[{"text":"Data center electricity demand growth is projected to be between 74 and 132 gigawatts (GW) by 2028, representing 6.712 percent of U.S. electricity usage.","ai_generated":true,"unit":"eninnova-000075#insight-1","date_modified":"2026-10-23"},{"text":"Failure to implement policy changes and flexible operations for data centers may result in 25-50 GW of additional fossil generation by 2030 and the deferral of several GW of coal retirements.","ai_generated":true,"unit":"eninnova-000075#insight-2","date_modified":"2026-10-23"},{"text":"Adding 100 GW of data center load nationwide would not require new peak resources if these centers curtail 0.5 percent of their annual electricity use to avoid peak demand periods.","ai_generated":true,"unit":"eninnova-000075#insight-3","date_modified":"2026-10-23"},{"text":"Data centers that reduce power usage by 25-50 percent during peak demand periods can significantly lower emissions and costs while reducing the need for new firm generation capacity, such as gas plants.","ai_generated":true,"unit":"eninnova-000075#insight-4","date_modified":"2026-10-23"},{"text":"The regions with the greatest potential for integrating flexible data centers are Southern Company, SPP, ERCOT, MISO, and PJM.","ai_generated":true,"unit":"eninnova-000075#insight-5","date_modified":"2026-10-23"}],"climate_tags":["data center","demand response","Demand flexibility","wide area synchronous grid","clean energy"],"geography_discussed":["PJM","MISO","ERCOT","SPP"],"frame_perspective":[],"analysis_type":["policy analysis","impact assessment"]},{"id":"rmi-000724","url":"https://climateinsightsdirectory.org/document/rmi-000724","title":"Catalyzing the Market for Automated Emissions Reduction Post-Charette Report","publisher":{"name":"RMI","organization":"rmi"},"document_type":"report","language":"en","date_published":null,"source_url":"https://rmi.org/app/uploads/2017/05/AER-Post-Charette-Report_RMI_May-2017.pdf","generator":"Climate Insights Directory","generated_fields":["summary","key_insights","climate_tags","geography_discussed","analysis_type"],"summary":{"text":"The report explores automated emissions reduction (AER), a software-based technology that modulates the electricity use of internet-connected devices based on real-time grid emissions data. Based on a pilot in Chicago and a stakeholder workshop, the report finds that AER can reduce pollution by 5–40% for specific loads and lower customer acquisition costs for utility demand response programs. It proposes five priority near-term initiatives: institutional and residential pilots, device certification, integration into GHG accounting protocols, and the creation of open-source infrastructure.","ai_generated":true,"unit":"rmi-000724#summary","date_modified":"2026-10-23"},"key_insights":[{"text":"Automated emissions reduction (AER) can reduce pollution by 5–40% per year for specific loads using current generation data, with electric vehicles and water heaters offering higher savings potential than air conditioning.","ai_generated":true,"unit":"rmi-000724#insight-1","date_modified":"2026-10-23"},{"text":"AER can significantly lower the cost of recruiting customers for utility demand response (DR) programs, with survey data indicating a 30–60% reduction in the required incentive for customers to participate when an AER feature is offered.","ai_generated":true,"unit":"rmi-000724#insight-2","date_modified":"2026-10-23"},{"text":"The project identified a specific near-term goal to achieve a reduction of 2 tons of mercury across the Great Lakes region, with a longer-term potential to reach 41 tons by 2020.","ai_generated":true,"unit":"rmi-000724#insight-3","date_modified":"2026-10-23"},{"text":"The effectiveness of AER is highly dependent on the quality of marginal emissions data; while first-generation data allowed for a 3% CO2 reduction for water heaters in MISO, future direct data from system operators could enable reductions exceeding 40%.","ai_generated":true,"unit":"rmi-000724#insight-4","date_modified":"2026-10-23"},{"text":"AER is complementary to both CO2 and mercury reduction goals, as optimizing for either typically reduces energy production from coal plants and utilizes nearly identical control signals.","ai_generated":true,"unit":"rmi-000724#insight-5","date_modified":"2026-10-23"},{"text":"The report proposes five priority initiatives for near-term action: launching institutional and residential customer pilots, creating a recognized device certification brand, integrating AER into greenhouse gas accounting protocols, and developing open-source tools and infrastructure.","ai_generated":true,"unit":"rmi-000724#insight-6","date_modified":"2026-10-23"}],"climate_tags":["demand response","carbon accounting","environmental impact of mercury","carbon dioxide emissions","wide area synchronous grid","demand-side management"],"geography_discussed":["United States","CAISO","ERCOT","ISO-NE","MISO","NYISO","PJM"],"frame_perspective":[],"analysis_type":["market analysis","pilot project evaluation","stakeholder workshop"]}]}