{"query_echo":{"q":"","filters":{"analysis_type":["technoeconomic analysis"]},"warnings":[{"code":"facet_value_not_in_vocabulary","message":"Value 'technoeconomic analysis' for facet 'analysis_type' is not in the controlled vocabulary."}]},"total":{"value":4,"relation":"eq"},"page":1,"page_size":20,"self":"https://climateinsightsdirectory.org/api/v1/search?analysis_type=technoeconomic+analysis","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-000249","url":"https://climateinsightsdirectory.org/document/rmi-000249","title":"The Time Is Now to Reconsider Planned Generation Projects","publisher":{"name":"RMI","organization":"rmi"},"document_type":"briefing","language":"en","date_published":"2026-06-04","source_url":"https://rmi.org/resources/the-time-is-now-to-reconsider-planned-generation-projects/","generator":"Climate Insights Directory","generated_fields":["summary","key_insights","climate_tags","geography_discussed","analysis_type"],"summary":{"text":"RMI advocates for the reassessment of planned coal-fired power plants, particularly in low-and-middle-income countries, given the falling costs of renewables and storage. The briefing provides a framework for identifying candidate plants for reconsideration based on their conception date, sunk costs, and evolving grid needs, suggesting that solar paired with battery energy storage (BESS) often offers a more competitive levelized cost of energy (LCOE) than new ultra-supercritical coal plants.","ai_generated":true,"unit":"rmi-000249#summary","date_modified":"2026-10-23"},"key_insights":[{"text":"There is a significant volume of planned coal capacity globally, with over 640 GW of grid-connected coal plants under development, the vast majority (630 GW) of which are located in low-and-middle-income countries (LMICs).","ai_generated":true,"unit":"rmi-000249#insight-1","date_modified":"2026-10-23"},{"text":"A large portion of planned coal projects are prime candidates for reconsideration: 170 GW were initiated over a decade ago, and 370 GW have not yet begun construction, meaning they have limited sunk costs.","ai_generated":true,"unit":"rmi-000249#insight-2","date_modified":"2026-10-23"},{"text":"Alternatives such as solar generation paired with four-hour or eight-hour battery energy storage (BESS) are projected to provide significant savings compared to a new ultra-supercritical coal plant planned in 2026 in most scenarios.","ai_generated":true,"unit":"rmi-000249#insight-3","date_modified":"2026-10-23"},{"text":"RMI proposes a five-question framework to identify plants for reconsideration, evaluating fuel source, conception date, sunk costs/contractual obligations, original grid role, and how grid needs have evolved.","ai_generated":true,"unit":"rmi-000249#insight-4","date_modified":"2026-10-23"}],"climate_tags":["coal-fired power station","solar energy","battery energy storage system","Levelized cost of energy","energy security","grid flexibility","climate finance"],"geography_discussed":["India","People's Republic of China"],"frame_perspective":[],"analysis_type":["policy recommendation","technoeconomic analysis"]},{"id":"rmi-000054","url":"https://climateinsightsdirectory.org/document/rmi-000054","title":"The Value of Green Hydrogen Trade for Europe","publisher":{"name":"RMI","organization":"rmi"},"document_type":"report","language":"en","date_published":"2023-12-04","source_url":"https://rmi.org/resources/the-value-of-green-hydrogen-trade-for-europe/","generator":"Climate Insights Directory","generated_fields":["summary","key_insights","climate_tags","geography_discussed","analysis_type"],"summary":{"text":"The EU aims to import 10 million tons of renewable hydrogen by 2030 to decarbonize heavy industry and transport, as domestic production is expected to fall short of demand. The report identifies the US Gulf Coast, Australia, and other regions with low renewable energy costs as key potential suppliers. To activate this trade, the EU needs to invest in port infrastructure (ammonia terminals and crackers), clarify certification schemes, and provide €15 billion to €20 billion in public support to offset green premiums over blue hydrogen. While Northwest Europe will rely heavily on imports, Southern Europe (Spain and Portugal) is expected to become more self-sufficient by the mid-2030s.","ai_generated":true,"unit":"rmi-000054#summary","date_modified":"2026-10-23"},"key_insights":[{"text":"The EU is projected to face a significant supply gap in green hydrogen by 2030, with nearly all Member States unable to meet their projected demand through domestic production alone.","ai_generated":true,"unit":"rmi-000054#insight-1","date_modified":"2026-10-23"},{"text":"The United States is positioned as a highly competitive early supplier for Europe, particularly from the US Gulf Coast, due to the Inflation Reduction Act (IRA) tax credits (Sections 45V and 45Y) which could reduce the levelized cost of green hydrogen by an estimated $2.83/kg for plants reaching FID in 2030.","ai_generated":true,"unit":"rmi-000054#insight-2","date_modified":"2026-10-23"},{"text":"There is a distinct geographic divide in the EU's future hydrogen needs: Northwest Europe (Germany, the Netherlands, and Belgium) will likely remain dependent on imports due to land constraints, whereas Southern Europe (Spain and Portugal) is expected to produce domestic green hydrogen at costs that outcompete subsidized imports by 2040.","ai_generated":true,"unit":"rmi-000054#insight-3","date_modified":"2026-10-23"},{"text":"To achieve the target of 10 million tons of green hydrogen by 2030 at costs competitive with fossil fuels, the EU requires between €15 billion and €20 billion in public support, which is estimated to unlock over €300 billion in private investment.","ai_generated":true,"unit":"rmi-000054#insight-4","date_modified":"2026-10-23"},{"text":"The EU faces a risk of 'locking in' reliance on blue hydrogen if early off-takers choose it over green hydrogen due to lower short-term costs, which could jeopardize decarbonization goals due to difficulties in verifying the emissions intensity of imported blue hydrogen.","ai_generated":true,"unit":"rmi-000054#insight-5","date_modified":"2026-10-23"},{"text":"Current EU port infrastructure is insufficient for the planned scale of imports; the report suggests an investment of approximately €1.8 billion in ammonia offloading terminals, storage, and crackers to bridge the 2030 supply gap.","ai_generated":true,"unit":"rmi-000054#insight-6","date_modified":"2026-10-23"}],"climate_tags":["green hydrogen","blue hydrogen","renewable energy","energy security","decarbonization","Green ammonia","climate finance","Carbon Border Adjustment Mechanism","Inflation Reduction Act of 2022"],"geography_discussed":["United States","Australia","Chile","Saudi Arabia","Algeria","Germany","Netherlands","Belgium","Spain","Portugal","Norway"],"frame_perspective":[],"analysis_type":["technoeconomic analysis","policy assessment"]},{"id":"sei-002736","url":"https://climateinsightsdirectory.org/document/sei-002736","title":"The future of marine multi-use: M4 (marine, multifunctional, mobile, and modular)","publisher":{"name":"Stockholm Environment Institute","organization":"stockholm-environment-institute"},"document_type":"briefing","language":"en","date_published":"2023-12","source_url":"https://www.sei.org/wp-content/uploads/2023/12/sei2023.066-marine-multi-use-wind-hydrogen.pdf","generator":"Climate Insights Directory","generated_fields":["summary","key_insights","climate_tags","geography_discussed","analysis_type"],"summary":{"text":"The document examines the M4 framework for marine multi-use projects, identifying a global trend toward combining offshore wind with other technologies, most notably hydrogen production. A technoeconomic analysis of a potential floating wind farm off Scotland indicates that centralized offshore hydrogen production is the most cost-effective strategy. The report highlights that while technical barriers are low, commercialization is hindered by regulatory gaps and a lack of multi-use integration in Marine Spatial Plans.","ai_generated":true,"unit":"sei-002736#summary","date_modified":"2026-10-23"},"key_insights":[{"text":"A review of 30 global M4 projects shows a growth trend since 2019, with 75% located in Europe. Most projects are in the concept or pilot testing phase, and the most common technology combination is offshore wind energy and hydrogen production, appearing in 11 projects.","ai_generated":true,"unit":"sei-002736#insight-1","date_modified":"2026-10-23"},{"text":"Technoeconomic analysis of a floating offshore wind farm off the coast of Scotland indicates that centralized offshore hydrogen production with pipeline transmission to shore is the most beneficial strategy. For a 2 GW wind farm, the levelized cost of hydrogen (LCOH) is estimated at 5.8 EUR/kg.","ai_generated":true,"unit":"sei-002736#insight-2","date_modified":"2026-10-23"},{"text":"The LCOH for offshore hydrogen production is most sensitive to the assumed levelized cost of electricity (LCOE), as electricity is the primary cost driver over a 30-year project lifetime.","ai_generated":true,"unit":"sei-002736#insight-3","date_modified":"2026-10-23"},{"text":"Industry stakeholders report that technical and economic barriers are not the primary obstacles; instead, the lack of an enabling regulatory environment and gaps in Marine Spatial Plans (MSPs) are major barriers to commercialization.","ai_generated":true,"unit":"sei-002736#insight-4","date_modified":"2026-10-23"},{"text":"To accelerate the adoption of M4 projects, the report recommends simplifying permitting procedures, providing economic incentives, and including marine multi-use as a non-price criterion when ranking bids for offshore wind projects.","ai_generated":true,"unit":"sei-002736#insight-5","date_modified":"2026-10-23"}],"climate_tags":["offshore wind power","aquaculture"],"geography_discussed":["Europe","Scotland","Belgium","Portugal","Spain","People's Republic of China","Denmark","Netherlands","Taiwan"],"frame_perspective":[],"analysis_type":["technoeconomic analysis","systematic review","stakeholder interviews"]},{"id":"greenca-000124","url":"https://climateinsightsdirectory.org/document/greenca-000124","title":"Technical factsheet for thermal beneficiation and treatment of wastewater sludge","publisher":{"name":"GreenCape","organization":"greencape"},"document_type":"fact sheet","language":"en","date_published":null,"source_url":"https://greencape.co.za/wp-content/uploads/2023/08/Factsheet-9_Thermal-Beneficiation-and-treatment-of-Wastewater-Sludge.pdf","generator":"Climate Insights Directory","generated_fields":["summary","key_insights","climate_tags","analysis_type"],"summary":{"text":"The document advocates for the use of thermal hydrolysis as a pre-treatment for anaerobic digestion in wastewater treatment works (WWTWs) to increase biogas production and reduce sludge mass. It highlights that South African municipalities spend over R300 million annually on sludge disposal and suggests that thermal hydrolysis can improve digester efficiency, reduce carbon footprints, and provide a payback period of 2-5 years. The factsheet also outlines various financing mechanisms, such as municipal budgets, grants, and energy performance contracts, to support the adoption of these energy efficiency and renewable energy technologies.","ai_generated":true,"unit":"greenca-000124#summary","date_modified":"2026-10-23"},"key_insights":[{"text":"Wastewater treatment works (WWTWs) are significant energy consumers, with water supply and wastewater treatment accounting for approximately 17% of the total energy used by South African municipalities.","ai_generated":true,"unit":"greenca-000124#insight-1","date_modified":"2026-10-23"},{"text":"The disposal of WWTW sludge in South Africa is a major financial burden, with annual costs estimated to exceed R300 million.","ai_generated":true,"unit":"greenca-000124#insight-2","date_modified":"2026-10-23"},{"text":"Thermal hydrolysis serves as a pre-treatment for anaerobic digestion, utilizing heat and pressure to increase biogas production by 15-60% and improve sludge dewatering by 7-8% on a dry basis.","ai_generated":true,"unit":"greenca-000124#insight-3","date_modified":"2026-10-23"},{"text":"The business case for adding thermal hydrolysis to an existing anaerobic digester includes a unit capital cost of R1,900-R2,400 per tonne of dry solids treated, a unit operating cost of R6-R8 per kg of dry solids treated, and an internal rate of return between 31% and 53%.","ai_generated":true,"unit":"greenca-000124#insight-4","date_modified":"2026-10-23"},{"text":"The investment payback period for thermal hydrolysis installations is estimated to be between 2 and 5 years.","ai_generated":true,"unit":"greenca-000124#insight-5","date_modified":"2026-10-23"}],"climate_tags":["biogas","wastewater treatment","energy efficiency","renewable energy","greenhouse gas emissions","climate finance"],"geography_discussed":[],"frame_perspective":[],"analysis_type":["technoeconomic analysis","policy briefing"]}]}