{"query_echo":{"q":"","filters":{"geography":["PJM Interconnection"]},"warnings":[{"code":"facet_value_not_in_vocabulary","message":"Value 'PJM Interconnection' for facet 'geography' is not in the controlled vocabulary."}]},"total":{"value":3,"relation":"eq"},"page":1,"page_size":20,"self":"https://climateinsightsdirectory.org/api/v1/search?geography=PJM+Interconnection","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-000479","url":"https://climateinsightsdirectory.org/document/rmi-000479","title":"GETting Interconnected in PJM","publisher":{"name":"RMI","organization":"rmi"},"document_type":"report","language":"en","date_published":"2024-02-15","source_url":"https://rmi.org/resources/analyzing-gets-as-a-tool-for-increasing-interconnection-throughput-from-pjms-queue/","generator":"Climate Insights Directory","generated_fields":["summary","key_insights","climate_tags","analysis_type"],"summary":{"text":"The report examines how grid-enhancing technologies (GETs) can address interconnection bottlenecks in the PJM region, potentially enabling 6.6 GW of new solar, wind, and storage projects by 2027 and providing approximately $1 billion in annual production cost savings.","ai_generated":true,"unit":"rmi-000479#summary","date_modified":"2026-10-23"},"key_insights":[{"text":"Grid-enhancing technologies (GETs) have the capacity to allow 6.6 GW of new storage, wind, and solar projects to interconnect by the year 2027.","ai_generated":true,"unit":"rmi-000479#insight-1","date_modified":"2026-10-23"},{"text":"GETs represent a significantly more affordable alternative compared to the standard network upgrades typically required for interconnection customers.","ai_generated":true,"unit":"rmi-000479#insight-2","date_modified":"2026-10-23"},{"text":"The implementation of GETs and the subsequent integration of new generation could result in annual production cost savings of roughly $1 billion throughout the PJM region.","ai_generated":true,"unit":"rmi-000479#insight-3","date_modified":"2026-10-23"}],"climate_tags":["solar energy","wind power","energy storage","electric power transmission","Power system reliability"],"geography_discussed":[],"frame_perspective":[],"analysis_type":["technical analysis","economic assessment"]},{"id":"eninnova-000105","url":"https://climateinsightsdirectory.org/document/eninnova-000105","title":"Impact of Investment Tax Credit on Interconnection Costs","publisher":{"name":"Energy Innovation","organization":"energy-innovation"},"document_type":"report","language":"en","date_published":"2024-02","source_url":"https://energyinnovation.org/wp-content/uploads/Impact-of-Investment-Tax-Credit-on-Interconnection-Costs.pdf","generator":"Climate Insights Directory","generated_fields":["summary","key_insights","climate_tags","geography_discussed","analysis_type"],"summary":{"text":"The report analyzes the impact of a 30% Investment Tax Credit (ITC) on interconnection costs for onshore wind and solar projects in the U.S. It finds that this credit could reduce overall project costs by 3% for solar and 1.7% for wind. More significantly, the analysis suggests the ITC could have bridged the cost gap for 22 GW of withdrawn projects and 15 GW of active projects across five regions, potentially bringing a total of 26-37 GW of capacity to fruition.","ai_generated":true,"unit":"eninnova-000105#summary","date_modified":"2026-10-23"},"key_insights":[{"text":"Applying the Investment Tax Credit (ITC) to interconnection costs could reduce the overall average costs of completed utility-scale projects by 3 percent for solar and 1.7 percent for wind.","ai_generated":true,"unit":"eninnova-000105#insight-1","date_modified":"2026-10-23"},{"text":"A retrospective analysis across five regions covering 30 states indicates that an interconnection ITC could have covered the cost difference between cancellation and success for 22 GW of withdrawn onshore wind and solar projects.","ai_generated":true,"unit":"eninnova-000105#insight-2","date_modified":"2026-10-23"},{"text":"The ITC could have reduced costs for 15 GW of onshore wind and solar projects that remained active as of 2022, bringing them into the cost range of completed projects.","ai_generated":true,"unit":"eninnova-000105#insight-3","date_modified":"2026-10-23"},{"text":"The combined potential impact of the ITC on withdrawn and active projects (26-37 GW) could exceed the 31 GW of utility-scale wind and solar deployed in the U.S. in 2023.","ai_generated":true,"unit":"eninnova-000105#insight-4","date_modified":"2026-10-23"},{"text":"The Midcontinental Independent System Operator (MISO) region showed the highest potential for the ITC to impact project viability, with 11,872 MW of withdrawn solar and 8,364 MW of withdrawn wind projects falling within 30% of the 75th percentile of completed project costs.","ai_generated":true,"unit":"eninnova-000105#insight-5","date_modified":"2026-10-23"},{"text":"Grid interconnection is a primary driver of project failure, with over 60 percent of wind and solar developers citing it as a primary cause for project cancellation.","ai_generated":true,"unit":"eninnova-000105#insight-6","date_modified":"2026-10-23"}],"climate_tags":["wide area synchronous grid","Inflation Reduction Act of 2022","electric power transmission","sustainable energy","energy transition"],"geography_discussed":["Midcontinental Independent System Operator","Southwest Power Pool","PJM Interconnection","Independent System Operator of New England","California","New England"],"frame_perspective":[],"analysis_type":["retrospective analysis","economic impact 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"]}]}