{"query_echo":{"q":"","filters":{"geography":["Southwest Power Pool"]},"warnings":[{"code":"facet_value_not_in_vocabulary","message":"Value 'Southwest Power Pool' for facet 'geography' is not in the controlled vocabulary."}]},"total":{"value":8,"relation":"eq"},"page":1,"page_size":20,"self":"https://climateinsightsdirectory.org/api/v1/search?geography=Southwest+Power+Pool","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":"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-000579","url":"https://climateinsightsdirectory.org/document/ucs-000579","title":"The Shaky Economics of Gas-fired Power","publisher":{"name":"Union of Concerned Scientists","organization":"union-of-concerned-scientists"},"document_type":"report","language":"en","date_published":"2022-06","source_url":"https://www.ucs.org/sites/default/files/2022-06/Economics-gas-fired-power-appendix.pdf","generator":"Climate Insights Directory","generated_fields":["summary","key_insights","climate_tags","geography_discussed","analysis_type"],"summary":{"text":"The document describes a methodology for assessing the economic viability of gas-fired power plants in MISO and SPP during 2019. By comparing day-ahead market revenues against fuel and variable operating expenses, the authors calculated hourly cash flows for 436 facilities. The process involved converting EPA gross generation data to net generation, mapping plants to the nearest market pricing nodes, and utilizing S&P Global data for fuel costs and variable operations and maintenance (O&M) expenses.","ai_generated":true,"unit":"ucs-000579#summary","date_modified":"2026-10-23"},"key_insights":[{"text":"The analysis calculated hourly cash flow by subtracting daily spot fuel prices and annual variable O&M costs from day-ahead market revenues based on net generation.","ai_generated":true,"unit":"ucs-000579#insight-1","date_modified":"2026-10-23"},{"text":"To determine market revenues, the researchers converted EPA hourly gross generation data into net generation using scalars derived from S&P Global and EIA Form 923 data, accounting for seasonal efficiency changes in steam and combined-cycle plants.","ai_generated":true,"unit":"ucs-000579#insight-2","date_modified":"2026-10-23"},{"text":"Market pricing was determined by matching plants to the nearest independent system operator pricing node within 10 miles; for nodes further than three miles, an inversely weighted average was used to correct for price outliers.","ai_generated":true,"unit":"ucs-000579#insight-3","date_modified":"2026-10-23"},{"text":"The study excluded additional revenue streams such as uplift payments and revenues from capacity and ancillary service markets.","ai_generated":true,"unit":"ucs-000579#insight-4","date_modified":"2026-10-23"},{"text":"Fuel costs were calculated using daily gas spot prices from S&P Global, though the authors note the analysis is sensitive to fuel price and lacks specific fuel contract terms or hedges.","ai_generated":true,"unit":"ucs-000579#insight-5","date_modified":"2026-10-23"},{"text":"The final analysis included 436 gas facilities across MISO and SPP, after excluding 86 facilities (12 percent of operating capacity) due to data limitations or their role as black-start capacity.","ai_generated":true,"unit":"ucs-000579#insight-6","date_modified":"2026-10-23"}],"climate_tags":["gas-fired power station"],"geography_discussed":["United States"],"frame_perspective":[],"analysis_type":["methodology"]},{"id":"ucs-000580","url":"https://climateinsightsdirectory.org/document/ucs-000580","title":"The Shaky Economics of Gas-fired Power Generation","publisher":{"name":"Union of Concerned Scientists","organization":"union-of-concerned-scientists"},"document_type":"report","language":"en","date_published":"2022-06","source_url":"https://www.ucs.org/sites/default/files/2022-06/Economics-gas-fired-power.pdf","generator":"Climate Insights Directory","generated_fields":["summary","key_insights","climate_tags","geography_discussed","analysis_type"],"summary":{"text":"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.","ai_generated":true,"unit":"ucs-000580#summary","date_modified":"2026-10-23"},"key_insights":[{"text":"In 2019, utilities in the Midcontinent Independent System Operator (MISO) and the Southwest Power Pool (SPP) incurred an estimated $117 million in operating losses from running gas plants when operating expenses exceeded market revenues.","ai_generated":true,"unit":"ucs-000580#insight-1","date_modified":"2026-10-23"},{"text":"The average gas-fired power plant in MISO and SPP operated without recovering its weekly operating costs for 11.3 and 12.6 weeks of 2019, respectively.","ai_generated":true,"unit":"ucs-000580#insight-2","date_modified":"2026-10-23"},{"text":"Uneconomic operation is strongly correlated with plant type; steam turbines and gas turbines are the most frequent loss-makers, while combined-cycle plants are the most economic.","ai_generated":true,"unit":"ucs-000580#insight-3","date_modified":"2026-10-23"},{"text":"The highest financial losses from uneconomic gas operations in 2019 occurred in Louisiana, non-ERCOT regions of Texas, Nebraska, Oklahoma, Indiana, and northern Midwest states including Minnesota, Wisconsin, and Michigan.","ai_generated":true,"unit":"ucs-000580#insight-4","date_modified":"2026-10-23"},{"text":"Entergy Corporation incurred the highest total weekly operating losses among the analyzed owners, totaling $24.6 million in 2019.","ai_generated":true,"unit":"ucs-000580#insight-5","date_modified":"2026-10-23"},{"text":"Certain operational practices, such as 'self-scheduling' and 'self-committing', allow power providers to operate plants regardless of whether they recover costs, which can displace cheaper, cleaner energy resources.","ai_generated":true,"unit":"ucs-000580#insight-6","date_modified":"2026-10-23"},{"text":"The Gerald Andrus Power Plant in Mississippi operated uneconomically during 22 of the 23 weeks it ran in 2019, resulting in $3.3 million in unrecovered costs passed to ratepayers.","ai_generated":true,"unit":"ucs-000580#insight-7","date_modified":"2026-10-23"},{"text":"Analysis of the Nichols Generating Station in Texas suggests the use of self-commitment to keep units online at minimum operating levels even when fuel and maintenance costs exceed market prices.","ai_generated":true,"unit":"ucs-000580#insight-8","date_modified":"2026-10-23"},{"text":"Basin Electric Power Cooperative's Lonesome Creek and Pioneer Generation Stations in North Dakota both operated at a loss for almost all weeks of 2019, incurring $3.2 million and $2.9 million in losses respectively.","ai_generated":true,"unit":"ucs-000580#insight-9","date_modified":"2026-10-23"}],"climate_tags":["gas-fired power station","electricity market","energy transition","methane emissions","renewable energy","wind power","solar energy","energy efficiency","electric power transmission","energy storage","demand response","air pollution","environmental justice"],"geography_discussed":["United States","Louisiana","Texas","Minnesota","Wisconsin","Michigan","Nebraska","Oklahoma","Indiana","Mississippi","North Dakota"],"frame_perspective":[],"analysis_type":["economic analysis","case study"]},{"id":"ucs-001275","url":"https://climateinsightsdirectory.org/document/ucs-001275","title":"Why Does Wind Energy Get Wasted?","publisher":{"name":"Union of Concerned Scientists","organization":"union-of-concerned-scientists"},"document_type":"fact sheet","language":"en","date_published":"2021-11","source_url":"https://www.ucs.org/sites/default/files/2021-11/Why-Does-Wind-Energy-Get-Wasted.pdf","generator":"Climate Insights Directory","generated_fields":["summary","key_insights","climate_tags","geography_discussed","analysis_type"],"summary":{"text":"The document challenges the notion that wind curtailment results from an oversupply of wind, using analysis of the Southwest Power Pool (SPP) to show that higher-cost coal plants often remain online while wind is curtailed. It identifies three primary drivers of this waste: inadequate transmission capacity, the practice of coal plants 'self-committing' to avoid being turned off, and a lack of battery storage. The author argues that addressing these infrastructure and operational shortcomings would reduce costs for consumers and lower carbon emissions.","ai_generated":true,"unit":"ucs-001275#summary","date_modified":"2026-10-23"},"key_insights":[{"text":"Analysis of the Southwest Power Pool (SPP) demonstrates that wind curtailment is not driven by an oversupply of wind energy, as higher-cost and more-polluting resources remained operational during all curtailment events.","ai_generated":true,"unit":"ucs-001275#insight-1","date_modified":"2026-10-23"},{"text":"The failure to curtail coal instead of wind in the SPP region results in higher costs for electricity customers and increased emissions; avoiding this waste could save over $40 million and prevent nearly 1.2 million short tons of carbon emissions annually.","ai_generated":true,"unit":"ucs-001275#insight-2","date_modified":"2026-10-23"},{"text":"Insufficient transmission capacity creates localized congestion that limits the delivery of wind energy to load centers. Examples of successful mitigation include Texas's Competitive Renewable Energy Zones (CREZ) and MISO's Multi-Value Projects portfolio.","ai_generated":true,"unit":"ucs-001275#insight-3","date_modified":"2026-10-23"},{"text":"Wind curtailment is exacerbated by the inflexible operation of coal-fired power plants, which often use 'self-commitment' to stay online at minimum operating levels, forcing grid operators to curtail flexible wind resources instead.","ai_generated":true,"unit":"ucs-001275#insight-4","date_modified":"2026-10-23"},{"text":"The lack of coal flexibility is estimated to cost customers across coal-heavy ISO/RTOs approximately $1 billion per year.","ai_generated":true,"unit":"ucs-001275#insight-5","date_modified":"2026-10-23"},{"text":"Battery storage can mitigate short-duration curtailment events, particularly when wholesale market prices are negative, though its effectiveness currently depends on being co-located at wind farms or upstream of transmission constraints.","ai_generated":true,"unit":"ucs-001275#insight-6","date_modified":"2026-10-23"}],"climate_tags":["wind energy","electric power transmission","coal-fired power station","battery energy storage system","grid flexibility","carbon dioxide emissions","energy transition"],"geography_discussed":["Southwest Power Pool","Texas","North Dakota"],"frame_perspective":[],"analysis_type":["policy analysis","technical analysis"]},{"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":"rmi-000337","url":"https://climateinsightsdirectory.org/document/rmi-000337","title":"Shifting Currents","publisher":{"name":"RMI","organization":"rmi"},"document_type":"briefing","language":"en","date_published":"2017-03-29","source_url":"https://rmi.org/resources/shifting-currents/","generator":"Climate Insights Directory","generated_fields":["summary","key_insights","climate_tags","geography_discussed","analysis_type"],"summary":{"text":"The Southwest Power Pool (SPP) has emerged as a leader in renewable energy, offering significant opportunities for corporate buyers through wind power purchase agreements (PPAs). Market improvements since 2014, including the integration of the Integrated System (IS) transmission system, have increased dispatch efficiency and reduced energy costs. The region possesses some of the highest wind resource quality in the U.S., with nine of the top 10 states for high-capacity-factor wind generation located within the SPP footprint. This high capacity factor allows for lower unit costs and more competitive PPA prices. While there is a strong pipeline of planned wind capacity—including an estimated 19 GW of planned additions and nearly 7 GW expected in 2017—corporate buyers are cautioned to monitor the pace of transmission infrastructure investment to avoid curtailment risks and track regional policy changes, such as potential tax credit eliminations in Oklahoma.","ai_generated":true,"unit":"rmi-000337#summary","date_modified":"2026-10-23"},"key_insights":[{"text":"Market improvements implemented by the Southwest Power Pool (SPP) since 2014, including the expansion to include the Integrated System (IS) transmission system, resulted in $131 million in savings during the first year of operations and reduced curtailments for renewable generators.","ai_generated":true,"unit":"rmi-000337#insight-1","date_modified":"2026-10-23"},{"text":"The SPP region features some of the best wind resources in the United States, with nine of the top 10 states for potential high-capacity-factor wind generation (defined as a capacity factor ≥ 35%) located within its footprint, leading to lower negotiated PPA prices for corporate buyers.","ai_generated":true,"unit":"rmi-000337#insight-2","date_modified":"2026-10-23"},{"text":"There is a significant pipeline of wind energy development in the SPP region, with 73 percent of the generation interconnection queue consisting of wind projects and nearly 7 GW of wind generation expected to be completed in 2017.","ai_generated":true,"unit":"rmi-000337#insight-3","date_modified":"2026-10-23"},{"text":"Compliance with the EPA's Clean Power Plan may further drive wind development in the region; an April 2015 SPP assessment estimated a need for an additional 5.6 GW of wind capacity to ensure compliance.","ai_generated":true,"unit":"rmi-000337#insight-4","date_modified":"2026-10-23"},{"text":"Corporate buyers face risks related to the pace of transmission infrastructure investment relative to wind development, as well as potential policy shifts, such as the possible elimination of wind generator tax credits in Oklahoma.","ai_generated":true,"unit":"rmi-000337#insight-5","date_modified":"2026-10-23"}],"climate_tags":["wind power","power purchase agreement","electric power transmission","renewable energy","Clean Power Plan","procurement"],"geography_discussed":["United States","Colorado","Wyoming","Texas","Oklahoma"],"frame_perspective":[],"analysis_type":["market assessment"]},{"id":"rmi-001071","url":"https://climateinsightsdirectory.org/document/rmi-001071","title":"SPATIAL AND TEMPORAL INTERACTIONS OF WIND AND SOLAR IN THE NEXT GENERATION UTILITY","publisher":{"name":"RMI","organization":"rmi"},"document_type":"research paper","language":"en","date_published":"2008-06-03","source_url":"https://rmi.org/app/uploads/2017/05/RMI_Document_Repository_Public-Reprts_RMI_Windpower-NGU-paper_fnl.pdf","generator":"Climate Insights Directory","generated_fields":["summary","key_insights","climate_tags","geography_discussed","analysis_type"],"summary":{"text":"The paper argues that the variability of renewable energy can be managed through optimized geographic dispersion and the cross-firming of wind and solar resources. By analyzing data from the MRO, SPP, and ERCOT regions, the study demonstrates that expanding the geographic scope of a renewable portfolio significantly reduces system variability and the frequency of zero-power production. It also finds that combining solar and wind resources further lowers variability compared to wind-only portfolios. The authors conclude that these strategies, combined with demand response, energy storage (such as xEVs), and smart grid communications, can reduce the reliance on conventional baseload power.","ai_generated":true,"unit":"rmi-001071#summary","date_modified":"2026-10-23"},"key_insights":[{"text":"Expanding the geographic area of a renewable portfolio across three reliability regions (MRO, SPP, and ERCOT) reduced system variability by 28% compared to the average individual region.","ai_generated":true,"unit":"rmi-001071#insight-1","date_modified":"2026-10-23"},{"text":"Geographic diversification significantly reduces the amount of time a system produces no power; a portfolio spanning the three analyzed regions produced no power for only 6 hours in a year, compared to 16 hours for the best individual region (ERCOT) and 90 hours for the average individual region.","ai_generated":true,"unit":"rmi-001071#insight-2","date_modified":"2026-10-23"},{"text":"Combining solar and wind resources further reduces variability; an optimized wind/solar portfolio showed 18% lower variability than an optimized wind-only portfolio.","ai_generated":true,"unit":"rmi-001071#insight-3","date_modified":"2026-10-23"},{"text":"In an optimized portfolio for the expanded region's 'bin of greatest return', capacity was distributed with approximately 80% allocated to wind and 20% to solar.","ai_generated":true,"unit":"rmi-001071#insight-4","date_modified":"2026-10-23"},{"text":"The length of the analysis period (one year versus three years) did not significantly impact the results for portfolio power output or variability, provided the single year used was typical.","ai_generated":true,"unit":"rmi-001071#insight-5","date_modified":"2026-10-23"},{"text":"The 'next generation utility' concept proposes reducing reliance on baseload coal and nuclear power by integrating variable renewables with demand response, energy storage via plug-in hybrid and electric vehicles (xEVs), and intelligent grid communications.","ai_generated":true,"unit":"rmi-001071#insight-6","date_modified":"2026-10-23"}],"climate_tags":["wind power","solar energy","grid flexibility","demand response","energy storage","electric vehicle","smart grid","decarbonization","energy efficiency"],"geography_discussed":["United States","California","Nevada"],"frame_perspective":[],"analysis_type":["quantitative","modeling"]}]}