{"query_echo":{"q":"","filters":{"organization":["Ember"]},"warnings":[]},"total":{"value":539,"relation":"eq"},"page":6,"page_size":20,"self":"https://climateinsightsdirectory.org/api/v1/search?organization=ember&page=6","next":"https://climateinsightsdirectory.org/api/v1/search?organization=ember&page=7","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":"ember-000180","url":"https://climateinsightsdirectory.org/document/ember-000180","title":"From coal boom to methane boom","publisher":{"name":"Ember","organization":"ember"},"document_type":"report","language":"en","date_published":"2025-11-06","source_url":"https://ember-energy.org/chapter/from-coal-boom-to-methane-boom/","generator":"Climate Insights Directory","generated_fields":["summary","key_insights","climate_tags","geography_discussed","analysis_type"],"summary":{"text":"Indonesia's coal industry has seen significant growth, leading to a surge in coal mine methane (CMM) emissions that are largely underreported by the government and industry. Ember estimates 2024 CMM emissions at 722 kt CH4, far exceeding the official figure of 168 kt CH4. This discrepancy is attributed to ineffective monitoring, reporting, and verification (MRV) frameworks and the exclusion of high-emission underground mines from official estimates. The report warns that the development of large underground mines, specifically one in South Kalimantan, will cause total CMM emissions to increase by approximately 25% by 2030, even if national coal production declines by 14%.","ai_generated":true,"unit":"ember-000180#summary","date_modified":"2026-10-23"},"key_insights":[{"text":"There is a significant gap between official government reports and independent estimates of coal mine methane (CMM) emissions in Indonesia. Ember estimated 2024 CMM emissions at 722 kt CH4, which is more than four times the government's reported figure of 168 CH4.","ai_generated":true,"unit":"ember-000180#insight-1","date_modified":"2026-10-23"},{"text":"Underreporting of CMM emissions is driven by structural failures, including limited institutional capacity, low corporate awareness, and the use of inaccurate IPCC low emissions factors for open-cut mines. Furthermore, emissions from underground mines—which have higher emissions per ton—are excluded from official CMM estimations, despite potentially contributing one third of national CMM emissions.","ai_generated":true,"unit":"ember-000180#insight-2","date_modified":"2026-10-23"},{"text":"Corporate reporting is insufficient; five companies representing 17.7% of national coal production reported 90 kt CH4, which is more than half of the total officially reported CMM emissions for the entire sector.","ai_generated":true,"unit":"ember-000180#insight-3","date_modified":"2026-10-23"},{"text":"The growth of underground mining is projected to increase total CMM emissions by approximately 25% by 2030, even if national coal production declines by 14%. A single underground mine in South Kalimantan is projected to see emissions rise from 35 kt CH4 in 2024 to 332 kt CH4 in 2030 as it reaches full capacity.","ai_generated":true,"unit":"ember-000180#insight-4","date_modified":"2026-10-23"},{"text":"Mitigation technologies such as pre-mine drainage and ventilation air methane (VAM) oxidation are commercially viable but not currently applied in Indonesia. Additionally, abandoned mine methane (AMM) from underground mines requires post-closure management through financial guarantees or bonds to ensure gas control.","ai_generated":true,"unit":"ember-000180#insight-5","date_modified":"2026-10-23"}],"climate_tags":["greenhouse gas emissions","measurement, reporting, and verification","Nationally Determined Contributions"],"geography_discussed":["South Kalimantan"],"frame_perspective":[],"analysis_type":["emissions assessment","policy analysis"]},{"id":"ember-000277","url":"https://climateinsightsdirectory.org/document/ember-000277","title":"Chasing volume, losing value: the cost of coal over expansion in Indonesia","publisher":{"name":"Ember","organization":"ember"},"document_type":"report","language":"en","date_published":"2025-11-06","source_url":"https://ember-energy.org/app/uploads/2025/11/EN-Chasing-volume-losing-value-the-cost-of-coal-over-expansion-in-Indonesia-PDF.pdf","generator":"Climate Insights Directory","generated_fields":["summary","key_insights","climate_tags","geography_discussed","analysis_type"],"summary":{"text":"Indonesia's coal sector is facing a downturn as production records in 2024 are met with declining export demand from China and India and rising production costs. This oversupply has eroded company profits and state non-tax revenues. Simultaneously, coal mine methane (CMM) emissions are significantly underreported and are projected to rise by 25% by 2030, driven by the expansion of underground mining in South Kalimantan. The report recommends a moratorium on new mines, improved methane monitoring, and a just transition framework for coal-dependent regions.","ai_generated":true,"unit":"ember-000277#summary","date_modified":"2026-10-23"},"key_insights":[{"text":"Indonesia's coal production reached a record high of 836 million tonnes in 2024, but total demand is projected to fall by approximately 10% to 756 million tonnes in 2025.","ai_generated":true,"unit":"ember-000277#insight-1","date_modified":"2026-10-23"},{"text":"Export markets are contracting as major importers China and India reduce reliance on Indonesian coal due to their own domestic production increases and the growth of solar and wind power.","ai_generated":true,"unit":"ember-000277#insight-2","date_modified":"2026-10-23"},{"text":"The strategy of increasing output to offset falling prices has failed, with average net profits for coal companies dropping by 67% from their 2022 peak due to rising production costs and lower market prices.","ai_generated":true,"unit":"ember-000277#insight-3","date_modified":"2026-10-23"},{"text":"State non-tax revenues from the mineral and coal subsector have declined since 2022, leading to significant reductions in provincial fiscal transfers to East Kalimantan (41%), South Kalimantan (30%), and South Sumatra (23%) between 2023 and 2025.","ai_generated":true,"unit":"ember-000277#insight-4","date_modified":"2026-10-23"},{"text":"Actual coal mine methane (CMM) emissions in 2024 are estimated at 722 kt CH4, which is more than four times the official government reported figure of 168 kt CH4.","ai_generated":true,"unit":"ember-000277#insight-5","date_modified":"2026-10-23"},{"text":"CMM emissions are projected to increase by 25% by 2030, primarily driven by the expansion of underground coal mining in South Kalimantan, where one mine's production is expected to grow from 2.6 million tonnes in 2024 to 20 million tonnes by 2030.","ai_generated":true,"unit":"ember-000277#insight-6","date_modified":"2026-10-23"}],"climate_tags":["greenhouse gas emissions","energy transition","just transition","renewable energy","solar energy","wind power","climate finance","Nationally Determined Contributions"],"geography_discussed":["People's Republic of China","India","South Kalimantan","East Kalimantan","South Sumatra","ASEAN","Malaysia","Vietnam","Bangladesh","Australia"],"frame_perspective":[],"analysis_type":["economic assessment","environmental impact analysis","policy recommendation"]},{"id":"ember-000486","url":"https://climateinsightsdirectory.org/document/ember-000486","title":"How coal oversupply erodes company profits and state revenues","publisher":{"name":"Ember","organization":"ember"},"document_type":"report","language":"en","date_published":"2025-11-06","source_url":"https://ember-energy.org/chapter/how-coal-oversupply-erodes-company-profits-and-state-revenues/","generator":"Climate Insights Directory","generated_fields":["summary","key_insights","climate_tags","geography_discussed","analysis_type"],"summary":{"text":"The report details a downturn in Indonesia's coal sector, where a strategy of increasing production volumes to offset falling global prices is contributing to market oversupply. This trend, combined with rising operational costs from inflation and new biodiesel mandates (B40), has led to a decline in net income for producers. Consequently, state non-tax revenues and provincial fiscal transfers to coal-dependent regions like East Kalimantan and South Sumatra have dropped significantly since the 2022 price peak.","ai_generated":true,"unit":"ember-000486#summary","date_modified":"2026-10-23"},"key_insights":[{"text":"Global coal oversupply was driven by production increases in China (147 million tonnes) and India (104 million tonnes) between 2022 and 2023, alongside the removal of Australia's coal export ban.","ai_generated":true,"unit":"ember-000486#insight-1","date_modified":"2026-10-23"},{"text":"Indonesian producers attempted to maintain revenue by expanding exports—by 53 million tonnes in 2023 and 37 million tonnes in 2024—which further increased global inventories by 44 million and 48 million tonnes respectively.","ai_generated":true,"unit":"ember-000486#insight-2","date_modified":"2026-10-23"},{"text":"Nine major coal companies planned a combined production increase of 26.6 million tonnes for 2025, with Bayan Resources and Bukit Asam planning the largest increases of 13.5 million and 6.7 million tonnes respectively, though actual production as of June 2025 reached only 357.6 million tonnes (48% of the annual target).","ai_generated":true,"unit":"ember-000486#insight-3","date_modified":"2026-10-23"},{"text":"Company profits are being squeezed by falling prices and rising costs, including a mandatory biodiesel blending increase to 40% (B40) starting January 2025, which the ICMA estimates could increase annual production costs by 1 trillion IDR.","ai_generated":true,"unit":"ember-000486#insight-4","date_modified":"2026-10-23"},{"text":"State non-tax revenues from the mineral and coal subsector peaked at 183 trillion IDR in 2022 but fell by 4.4% in 2023 and 18.6% in 2024 as average coal prices dropped from 201 USD/ton in 2023 to 121 USD/ton in 2024.","ai_generated":true,"unit":"ember-000486#insight-5","date_modified":"2026-10-23"},{"text":"Provincial fiscal transfers from coal royalties declined between 2023 and 2025 by 41% for East Kalimantan, 30% for South Kalimantan, and 23% for South Sumatra.","ai_generated":true,"unit":"ember-000486#insight-6","date_modified":"2026-10-23"}],"climate_tags":["energy transition"],"geography_discussed":["People's Republic of China","India","Australia","East Kalimantan","South Kalimantan","South Sumatra"],"frame_perspective":[],"analysis_type":["economic analysis","fiscal analysis"]},{"id":"ember-000528","url":"https://climateinsightsdirectory.org/document/ember-000528","title":"Renewable additions in 2025 are once again expected to surge, putting tripling within reach","publisher":{"name":"Ember","organization":"ember"},"document_type":"report","language":"en","date_published":"2025-11-06","source_url":"https://ember-energy.org/app/uploads/2025/11/Report-2025-Renewable-additions-surging-putting-tripling-within-reach.pdf","generator":"Climate Insights Directory","generated_fields":["summary","key_insights","climate_tags","geography_discussed","analysis_type"],"summary":{"text":"Global renewable capacity additions are forecast to reach a record 793 GW in 2025, driven largely by solar and China's deployment. While the actual annual growth rate of additions from 2023 to 2025 (29%) has exceeded the 21% required to triple capacity by 2030, IEA forecasts suggest a potential 15% shortfall in capacity and a 28% shortfall in generation by 2030, primarily due to lags in wind and hydro. National targets remain insufficient, aiming for just over a doubling of capacity (7,793 GW) rather than a tripling, with solar targets particularly lagging behind actual deployment trends.","ai_generated":true,"unit":"ember-000528#summary","date_modified":"2026-10-23"},"key_insights":[{"text":"Global renewable capacity additions are projected to reach a record 793 GW in 2025, representing an 11% increase over the 717 GW added in 2024.","ai_generated":true,"unit":"ember-000528#insight-1","date_modified":"2026-10-23"},{"text":"China is the primary driver of global growth, expected to account for 66% of solar and 69% of wind capacity additions in 2025.","ai_generated":true,"unit":"ember-000528#insight-2","date_modified":"2026-10-23"},{"text":"The world has outperformed the growth rate needed to triple renewables; additions grew by an average of 29% annually from 2023 to 2025, whereas a 21% annual growth rate was required. Consequently, additions only need to rise by 12% per year from 2026 to 2030 to meet the target.","ai_generated":true,"unit":"ember-000528#insight-3","date_modified":"2026-10-23"},{"text":"Despite the growth, the IEA's main case forecast predicts a 15% shortfall in capacity by 2030 (reaching 9,530 GW instead of 11 TW). This results in a larger 28% shortfall in electricity generation because the gaps are concentrated in wind and hydro, which have higher capacity factors than solar.","ai_generated":true,"unit":"ember-000528#insight-4","date_modified":"2026-10-23"},{"text":"National 2030 renewable targets are not aligned with the tripling goal, having increased by only 8% since COP28 to a total of 7,793 GW, which reflects a doubling rather than a tripling of capacity from 2022 levels.","ai_generated":true,"unit":"ember-000528#insight-5","date_modified":"2026-10-23"},{"text":"There is a significant gap between national solar targets and actual deployment; combined national targets are 3,110 GW, which is barely half of the 6,101 GW required for a global tripling.","ai_generated":true,"unit":"ember-000528#insight-6","date_modified":"2026-10-23"},{"text":"Wind capacity targets and forecasts are roughly aligned but both fall short of the 2,742 GW needed for a tripling, with national targets aiming for 2,223 GW.","ai_generated":true,"unit":"ember-000528#insight-7","date_modified":"2026-10-23"}],"climate_tags":["solar energy","wind power","hydropower","2023 United Nations Climate Change Conference","community engagement","2025 United Nations Climate Change Conference","Nationally Determined Contributions","energy storage","electrical grid","climate finance"],"geography_discussed":["People's Republic of China","United States","European Union"],"frame_perspective":[],"analysis_type":["capacity forecast","policy target analysis","progress tracking"]},{"id":"ember-000447","url":"https://climateinsightsdirectory.org/document/ember-000447","title":"How to scale demand flexibility in Europe","publisher":{"name":"Ember","organization":"ember"},"document_type":"briefing","language":"en","date_published":"2025-11-05","source_url":"https://ember-energy.org/latest-insights/how-to-scale-demand-flexibility-in-europe","generator":"Climate Insights Directory","generated_fields":["summary","key_insights","climate_tags","geography_discussed","analysis_type"],"summary":{"text":"The briefing outlines three primary policy areas to scale demand flexibility in Europe: accelerating smart meter rollout, implementing time-of-use tariffs, and removing barriers to automation and aggregation. It highlights the need for updated technical standards by 2026 and national objectives by 2027 to overcome slow implementation of EU rules.","ai_generated":true,"unit":"ember-000447#summary","date_modified":"2026-10-23"},"key_insights":[{"text":"The European Commission is expected to approve new technical standards via the Network Code for Demand Response in early 2026 and provide guidance on flexibility remuneration in retail contracts, with Member states required to set national objectives for demand flexibility and storage by January 2027.","ai_generated":true,"unit":"ember-000447#insight-1","date_modified":"2026-10-23"},{"text":"Smart meter deployment varies significantly across the EU, with coverage exceeding 90% in France and Spain, but remaining as low as 2% in Germany and 36% in Poland.","ai_generated":true,"unit":"ember-000447#insight-2","date_modified":"2026-10-23"},{"text":"To increase flexibility, the document recommends updating static time-of-use tariffs to reflect daytime solar availability rather than nighttime baseload power, and shifting policy levies to general taxation to reduce fixed charges and clarify price signals.","ai_generated":true,"unit":"ember-000447#insight-3","date_modified":"2026-10-23"},{"text":"Scaling demand flexibility requires removing barriers to automation and aggregation, including avoiding restrictive compensation requirements for suppliers. The UK's mutual compensation model is cited as a more effective approach than the French practice of full compensation, which limits flexibility to incumbent suppliers.","ai_generated":true,"unit":"ember-000447#insight-4","date_modified":"2026-10-23"},{"text":"Full non-discriminatory participation of demand side flexibility in all power markets, including wholesale markets, is currently only possible in two EU countries, with the UK described as more advanced than any EU member state.","ai_generated":true,"unit":"ember-000447#insight-5","date_modified":"2026-10-23"}],"climate_tags":["Demand flexibility","smart grid","Grid balancing","wide area synchronous grid","electric vehicle","heat pump"],"geography_discussed":["Germany","Poland","France","Spain","United Kingdom"],"frame_perspective":[],"analysis_type":["policy analysis"]},{"id":"ember-000385","url":"https://climateinsightsdirectory.org/document/ember-000385","title":"Offshore wind targets underpin acceleration to 2030 and beyond","publisher":{"name":"Ember","organization":"ember"},"document_type":"report","language":"en","date_published":"2025-10-30","source_url":"https://ember-energy.org/app/uploads/2025/10/Report-Global-Offshore-Wind-Targets-1.pdf","generator":"Climate Insights Directory","generated_fields":["summary","key_insights","climate_tags","geography_discussed","analysis_type"],"summary":{"text":"The report finds that 27 countries have set national offshore wind targets, with global capacity projected to almost triple from 83 GW in 2024 to 238 GW by 2030. While targets have driven market growth, many countries are expected to miss their 2030 goals due to cost inflation, supply chain pressures, and permitting delays. The analysis highlights a significant gap between current projections and the 413 GW required by 2030 to align with the UAE consensus for tripling renewable capacity.","ai_generated":true,"unit":"ember-000385#summary","date_modified":"2026-10-23"},"key_insights":[{"text":"A total of 27 countries have established national offshore wind targets, with 22 of these targeting 2030 and 18 setting post-2030 goals. Additionally, there are 27 subnational targets and three regional targets in Europe (North Sea, Baltic Sea, and EU-level).","ai_generated":true,"unit":"ember-000385#insight-1","date_modified":"2026-10-23"},{"text":"Global offshore wind capacity is projected to increase from 83 GW in 2024 to 238 GW by 2030, nearly tripling in six years. However, the Global Wind Energy Council (GWEC) reduced its 2030 global outlook by 25% over the past year.","ai_generated":true,"unit":"ember-000385#insight-2","date_modified":"2026-10-23"},{"text":"Despite rapid growth, the IEA projects that none of the 12 countries expected to have offshore wind capacity by 2030 will fully meet their targets. The United States is forecast to have the greatest shortfall, while Japan and Korea may only reach about one-third of their 2030 targets.","ai_generated":true,"unit":"ember-000385#insight-3","date_modified":"2026-10-23"},{"text":"There is a gap between current national targets and global climate goals; while national 2030 targets (including China's IEA forecast) reach approximately 395 GW, IRENA indicates that 413 GW is needed by 2030 to track the UAE consensus.","ai_generated":true,"unit":"ember-000385#insight-4","date_modified":"2026-10-23"},{"text":"Seven countries have specific targets for floating offshore wind: the UK (5 GW) and Portugal (2 GW) by 2030, and post-2030 targets for France, Norway, Korea, and the United States. Japan aims for 15 GW of floating wind by 2040.","ai_generated":true,"unit":"ember-000385#insight-5","date_modified":"2026-10-23"},{"text":"China does not have a national target but has 11 coastal provinces with 2025 targets totaling 64 GW. The Beijing Declaration 2.0, signed October 20, 2025, specifies that annual installed wind power capacity during the 15th Five-Year Plan (2026-2030) shall include at least 15 GW of offshore wind.","ai_generated":true,"unit":"ember-000385#insight-6","date_modified":"2026-10-23"},{"text":"The World Bank identified 115 countries with offshore wind potential; 88 of these have not yet set targets. Among these, nine are members of the Global Offshore Wind Alliance (GOWA): Australia, Brazil, Canada, Chile, Malta, Panama, Papua New Guinea, Saint Lucia, and Trinidad and Tobago.","ai_generated":true,"unit":"ember-000385#insight-7","date_modified":"2026-10-23"}],"climate_tags":["offshore wind power","energy transition","Nationally Determined Contributions","climate finance","supply chain","energy security"],"geography_discussed":["European Union","United Kingdom","India","United States","People's Republic of China","Brazil","Morocco","New Zealand","Azerbaijan"],"frame_perspective":[],"analysis_type":["policy analysis","capacity forecasting"]},{"id":"ember-000060","url":"https://climateinsightsdirectory.org/document/ember-000060","title":"India’s power generation capacity additions","publisher":{"name":"Ember","organization":"ember"},"document_type":"report","language":"en","date_published":"2025-10-29","source_url":"https://ember-energy.org/chapter/indias-power-generation-capacity-additions/","generator":"Climate Insights Directory","generated_fields":["summary","key_insights","climate_tags","analysis_type"],"summary":{"text":"India is generally on track to meet its NEP 2032 capacity mix, with solar, hydro, and coal well-positioned to reach targets. However, onshore wind additions must accelerate, and nuclear capacity is likely to fall short due to long lead times and a limited near-term pipeline. Battery and pumped hydro storage are expanding rapidly to support renewables integration.","ai_generated":true,"unit":"ember-000060#summary","date_modified":"2026-10-23"},"key_insights":[{"text":"India is seeing record solar expansion, with 23.8 GW added in FY 2024–25 and 22 GW commissioned in the first half of FY 2025–26. To reach the NEP 2032 target of 365 GW, India needs 163 GW more, requiring an average of 32.6 GW annually through 2030.","ai_generated":true,"unit":"ember-000060#insight-1","date_modified":"2026-10-23"},{"text":"Onshore wind capacity is currently lagging and needs to increase from an average of ~3.5 GW added in 2024 to roughly 8.8 GW per year between 2026 and 2030 to close a 44 GW gap and meet the 124 GW NEP 2032 target.","ai_generated":true,"unit":"ember-000060#insight-2","date_modified":"2026-10-23"},{"text":"Coal capacity is well-positioned to meet NEP 2032 goals, with ~35 GW of supercritical and ultra-supercritical plants under construction across 25 projects as of August 2025.","ai_generated":true,"unit":"ember-000060#insight-3","date_modified":"2026-10-23"},{"text":"Nuclear power is expected to miss its 2032 target of 20 GW. While 8.8 GW is installed and 6.6 GW is under construction, the remaining ~5 GW gap is unlikely to be filled because the 7 GW in the pre-project phase will not be ready by 2032.","ai_generated":true,"unit":"ember-000060#insight-4","date_modified":"2026-10-23"},{"text":"Energy storage targets are attainable: the NEP target for pumped hydro storage (26.7 GW) is nearly met with an executable subtotal of 25.91 GW, and the 236 GWh battery storage target is considered achievable despite some tender cancellations.","ai_generated":true,"unit":"ember-000060#insight-5","date_modified":"2026-10-23"}],"climate_tags":["photovoltaics","hydropower","coal power","nuclear power","battery energy storage system","Grid balancing"],"geography_discussed":[],"frame_perspective":[],"analysis_type":["capacity assessment","policy alignment analysis","infrastructure pipeline review"]},{"id":"ember-000064","url":"https://climateinsightsdirectory.org/document/ember-000064","title":"Coal fleet’s changing role in the power system","publisher":{"name":"Ember","organization":"ember"},"document_type":"report","language":"en","date_published":"2025-10-29","source_url":"https://ember-energy.org/chapter/coal-fleets-changing-role-in-the-power-system/","generator":"Climate Insights Directory","generated_fields":["summary","key_insights","climate_tags","analysis_type"],"summary":{"text":"India's coal fleet is shifting from baseload to flexible balancing to integrate rising solar and wind energy. By FY 2031–32, coal plants will need to operate closer to their technical minimums, with a projected average plant load factor (PLF) drop from 69% to 55%. This transition will disproportionately impact high-cost, less efficient units, suggesting that the 35 GW of coal capacity currently under construction is sufficient for supply security without further additions.","ai_generated":true,"unit":"ember-000064#summary","date_modified":"2026-10-23"},"key_insights":[{"text":"The role of coal generation is shifting from steady baseload to flexible balancing resources, requiring deeper mid-day turndowns and faster evening ramp-ups to accommodate variable renewable energy.","ai_generated":true,"unit":"ember-000064#insight-1","date_modified":"2026-10-23"},{"text":"The 2023 Grid Code formalises the Minimum Thermal Load (MTL)—the lowest reliable output level—at 55% of rated capacity, with ramping expectations of approximately 1% of rated capacity per minute.","ai_generated":true,"unit":"ember-000064#insight-2","date_modified":"2026-10-23"},{"text":"Modelling for FY 2031–32 indicates a significant daily swing in coal output, peaking at approximately 190 GW during non-solar hours and ramping down to roughly 112 GW at midday solar peaks.","ai_generated":true,"unit":"ember-000064#insight-3","date_modified":"2026-10-23"},{"text":"To avoid solar curtailment and expensive gas-based generation, many plants may need to operate at an effective MTL of around 40%, which is lower than the current 55% standard.","ai_generated":true,"unit":"ember-000064#insight-4","date_modified":"2026-10-23"},{"text":"Flexibility burdens currently fall disproportionately on a few Inter-State Generating Station (ISGS) plants, while intra-state generators remain largely unresponsive to flexibility needs.","ai_generated":true,"unit":"ember-000064#insight-5","date_modified":"2026-10-23"},{"text":"Average plant load factors (PLF) for the coal fleet are projected to decline from approximately 69% in FY 2024–25 to 55% by FY 2031–32.","ai_generated":true,"unit":"ember-000064#insight-6","date_modified":"2026-10-23"},{"text":"The reduction in utilisation will be non-uniform, with plants having variable costs higher than roughly INR 2.8/kWh seeing significant reductions in run hours.","ai_generated":true,"unit":"ember-000064#insight-7","date_modified":"2026-10-23"},{"text":"India does not require new coal capacity beyond the 35 GW currently under construction to maintain supply-side security through FY 2031–32.","ai_generated":true,"unit":"ember-000064#insight-8","date_modified":"2026-10-23"}],"climate_tags":["coal-fired power station","solar energy","wind energy","grid flexibility","energy transition"],"geography_discussed":[],"frame_perspective":[],"analysis_type":["operational modelling","policy assessment","technical analysis"]},{"id":"ember-000109","url":"https://climateinsightsdirectory.org/document/ember-000109","title":"Coal power to get costlier","publisher":{"name":"Ember","organization":"ember"},"document_type":"report","language":"en","date_published":"2025-10-29","source_url":"https://ember-energy.org/chapter/coal-power-to-get-costlier/","generator":"Climate Insights Directory","generated_fields":["summary","key_insights","climate_tags","geography_discussed","analysis_type"],"summary":{"text":"The report analyzes the rising effective costs of coal power in India due to underutilisation, which is expected to increase average tariffs by roughly 25% as PLFs fall. It highlights that fixed costs drive 85% of this increase, making new coal capacity economically inferior to Firm and Dispatchable Renewable Energy (FDRE). The author concludes that India's 2032 power goals can be met with the ~35 GW of coal already in the pipeline, rendering further expansion unnecessary and financially risky for distribution companies (DISCOMs).","ai_generated":true,"unit":"ember-000109#summary","date_modified":"2026-10-23"},"key_insights":[{"text":"The effective cost of coal power in India is projected to rise by nearly 25% as plant load factors (PLFs) decline, with the average coal PLF expected to drop to approximately 55% by FY 2031–32. This cost increase is primarily driven by underutilisation, which accounts for nearly 85% of the effective cost rise because fixed costs are spread over fewer units of generation.","ai_generated":true,"unit":"ember-000109#insight-1","date_modified":"2026-10-23"},{"text":"Declining utilisation increases both fixed and variable costs for coal assets. Fixed costs rise due to the burden of underutilised assets, required retrofits costing between INR 100–400 million (USD 1.15-4.60 million) per unit, and higher O&M expenses from equipment wear. Variable costs increase as lower PLFs raise the station heat rate by 7–9%, increase auxiliary power consumption by 2–4% per kWh, and add INR 10–25 million (USD 0.11-0.29 million) in restart expenses per unit.","ai_generated":true,"unit":"ember-000109#insight-2","date_modified":"2026-10-23"},{"text":"New coal power is becoming prohibitively expensive compared to renewable alternatives. Tariffs for new coal plants have risen sharply, exceeding INR 6/kWh (USD 68/MWh) in Bihar and INR 5.85/kWh (USD 66/MWh) in Madhya Pradesh. In contrast, Firm and Dispatchable Renewable Energy (FDRE) tariffs range from INR 4.3–5.8/kWh (USD 49–67/MWh), and solar and storage tenders range from INR 2.9–3.6/kWh (USD 33–41/MWh).","ai_generated":true,"unit":"ember-000109#insight-3","date_modified":"2026-10-23"},{"text":"India does not require additional coal capacity beyond the ~35 GW currently under construction to meet its 2032 power sector goals. Approving further capacity would risk severe overcapacity and impose financial stress on DISCOMs by locking them into high-cost, underutilised assets.","ai_generated":true,"unit":"ember-000109#insight-4","date_modified":"2026-10-23"}],"climate_tags":["coal power","solar energy","battery energy storage system","energy transition","stranded asset"],"geography_discussed":["Bihar","Madhya Pradesh"],"frame_perspective":[],"analysis_type":["economic analysis","policy assessment"]},{"id":"ember-000158","url":"https://climateinsightsdirectory.org/document/ember-000158","title":"Overbuilding coal capacity is not the solution","publisher":{"name":"Ember","organization":"ember"},"document_type":"report","language":"en","date_published":"2025-10-29","source_url":"https://ember-energy.org/chapter/recommendations-2/","generator":"Climate Insights Directory","generated_fields":["summary","key_insights","climate_tags","analysis_type"],"summary":{"text":"The document outlines strategies for India's power sector transition, emphasizing the need to improve coal plant flexibility, reform power purchase agreements, and scale up energy storage to manage solar integration and grid reliability.","ai_generated":true,"unit":"ember-000158#summary","date_modified":"2026-10-23"},"key_insights":[{"text":"India should improve the technical flexibility of its coal fleet by mandating that plants operate at a minimum technical load (MTL) of 40%, down from the current 55% benchmark, and implementing compensation mechanisms for generators and purchasers.","ai_generated":true,"unit":"ember-000158#insight-1","date_modified":"2026-10-23"},{"text":"To adapt to a changing power sector, Distribution Companies (DISCOMs) should shift from 25-year long-term power purchase agreements to short- or medium-term contracts of approximately 3 to 5 years.","ai_generated":true,"unit":"ember-000158#insight-2","date_modified":"2026-10-23"},{"text":"Integrating state-level thermal generators into the central optimisation pool would increase the thermal capacity available to balance the midday solar surge and allow for more efficient economic dispatch.","ai_generated":true,"unit":"ember-000158#insight-3","date_modified":"2026-10-23"},{"text":"Current storage volumes assumed in the National Electricity Plan (NEP) are insufficient for planned solar growth; without increasing storage and ring-fencing capacity for ancillary services, the system faces estimated renewable curtailment of 2.5–3.8%.","ai_generated":true,"unit":"ember-000158#insight-4","date_modified":"2026-10-23"},{"text":"Policy reforms are needed to better compensate energy storage for its superior frequency response and reserve provision, specifically through Secondary Reserve Ancillary Service (SRAS) and the reduction of emergency Tertiary Reserve Ancillary Service (TRAS).","ai_generated":true,"unit":"ember-000158#insight-5","date_modified":"2026-10-23"}],"climate_tags":["coal power","energy storage","solar energy","power purchase agreement","grid flexibility","wide area synchronous grid"],"geography_discussed":[],"frame_perspective":[],"analysis_type":["policy recommendation","technical assessment"]},{"id":"ember-000231","url":"https://climateinsightsdirectory.org/document/ember-000231","title":"Coal’s diminishing role in India’s electricity transition","publisher":{"name":"Ember","organization":"ember"},"document_type":"report","language":"en","date_published":"2025-10-29","source_url":"https://ember-energy.org/app/uploads/2025/10/Coals-diminishing-role-in-Indias-electricity-transition.pdf","generator":"Climate Insights Directory","generated_fields":["summary","key_insights","climate_tags","geography_discussed","analysis_type"],"summary":{"text":"The report argues that as India expands solar and wind capacity, coal's role will shift from baseload provider to a flexible balancing resource, leading to lower plant load factors (PLFs) and higher effective costs. By FY 2031-32, coal-based electricity is projected to be roughly 25% costlier than in FY 2024-25. The analysis suggests that the ~35 GW of coal capacity currently under construction is sufficient for reliability, making further coal expansion uneconomical compared to firm and dispatchable renewable energy (FDRE) and storage options.","ai_generated":true,"unit":"ember-000231#summary","date_modified":"2026-10-23"},"key_insights":[{"text":"India is generally on track to meet its NEP-2032 capacity targets for solar, coal, and hydro, though wind capacity additions must accelerate and nuclear is likely to fall short of its target.","ai_generated":true,"unit":"ember-000231#insight-1","date_modified":"2026-10-23"},{"text":"Coal's operational role is shifting from baseload to flexible balancing, which will significantly reduce its average Plant Load Factor (PLF) from approximately 69% in FY 2024-25 to 55% by FY 2031-32.","ai_generated":true,"unit":"ember-000231#insight-2","date_modified":"2026-10-23"},{"text":"The effective cost of coal-based electricity is projected to rise by roughly 25% by FY 2031-32, driven primarily by underutilisation (spreading fixed costs over fewer units) and increased operational expenses from part-load inefficiencies.","ai_generated":true,"unit":"ember-000231#insight-3","date_modified":"2026-10-23"},{"text":"New coal capacity beyond the ~35 GW already under construction is unnecessary and uneconomical, as approximately 10% of additional units would be entirely unutilised by FY 2031-32.","ai_generated":true,"unit":"ember-000231#insight-4","date_modified":"2026-10-23"},{"text":"Firm and Dispatchable Renewable Energy (FDRE) and solar-plus-storage are now more cost-competitive than new coal plants, with FDRE tariffs between INR 4.3–5.8/kWh and solar-plus-storage at INR 2.9–3.6/kWh, compared to new coal tariffs nearing INR 6/kWh.","ai_generated":true,"unit":"ember-000231#insight-5","date_modified":"2026-10-23"},{"text":"To integrate higher levels of renewables, India should prioritize expanding battery energy storage systems (BESS) and pumped hydro storage (PHS), and consider mandating a statutory minimum technical load (MTL) of 40% for coal plants to increase flexibility.","ai_generated":true,"unit":"ember-000231#insight-6","date_modified":"2026-10-23"}],"climate_tags":["coal-fired power station","solar energy","hydropower","nuclear power","battery energy storage system","energy transition"],"geography_discussed":["Bihar","Madhya Pradesh"],"frame_perspective":[],"analysis_type":["operational modelling","cost analysis","policy assessment"]},{"id":"ember-000219","url":"https://climateinsightsdirectory.org/document/ember-000219","title":"Aligning interests: Central Eastern European TSO perspectives on EU grid development","publisher":{"name":"Ember","organization":"ember"},"document_type":"policy brief","language":"en","date_published":"2025-10-24","source_url":"https://ember-energy.org/app/uploads/2025/10/CEE_TSOs_Policy-paper_new_template.pdf","generator":"Climate Insights Directory","generated_fields":["summary","key_insights","climate_tags","geography_discussed","analysis_type"],"summary":{"text":"The document outlines the views of TSOs from Bulgaria, Estonia, Latvia, Lithuania, Poland, and Slovakia regarding EU grid development. While generally supportive of the European Grids Package, these operators express low confidence in EU-level coordination, citing administrative burdens and a perception of Western European dominance in policy shaping. Key barriers identified include outdated infrastructure, regulatory fragmentation, and complex access to EU funding mechanisms like the Connecting Europe Facility (CEF). The TSOs emphasize the need for more practical, inclusive reforms that respect national sovereignty and address specific security risks for countries on the EU's external borders.","ai_generated":true,"unit":"ember-000219#summary","date_modified":"2026-10-23"},"key_insights":[{"text":"TSOs in Central and Eastern Europe (CEE) exhibit cautious optimism toward the European Grids Package but have low confidence in EU-led coordination, which they perceive as administratively heavy and disconnected from national realities.","ai_generated":true,"unit":"ember-000219#insight-1","date_modified":"2026-10-23"},{"text":"There is a perceived imbalance in EU energy policy influence, with CEE stakeholders feeling that Western European TSOs have a disproportionate impact and that CEE priorities are underrepresented due to resource constraints.","ai_generated":true,"unit":"ember-000219#insight-2","date_modified":"2026-10-23"},{"text":"EU funding is critical but hindered by bureaucracy; while the Connecting Europe Facility (CEF) is preferred, the Recovery and Resilience Facility (RRF) and REPowerEU funds are seen as overly bureaucratic and difficult to access.","ai_generated":true,"unit":"ember-000219#insight-3","date_modified":"2026-10-23"},{"text":"TSOs near the EU's external borders face heightened physical and cyber security risks to critical infrastructure and require dedicated EU financial and strategic support to avoid competitive disadvantages.","ai_generated":true,"unit":"ember-000219#insight-4","date_modified":"2026-10-23"},{"text":"National grid investment is often hampered by a reactive regulatory mindset that prioritizes demonstrated need over anticipatory investments, risking under-investment in the infrastructure required for renewables integration.","ai_generated":true,"unit":"ember-000219#insight-5","date_modified":"2026-10-23"}],"climate_tags":["Grid modernization","wide area synchronous grid","climate finance","energy security","decarbonization"],"geography_discussed":["Bulgaria","Estonia","Latvia","Lithuania","Poland","Slovakia"],"frame_perspective":[],"analysis_type":["stakeholder consultation","policy analysis"]},{"id":"ember-000527","url":"https://climateinsightsdirectory.org/document/ember-000527","title":"From Captive Coal to Green Nickel: Securing Indonesia’s Future Competitiveness","publisher":{"name":"Ember","organization":"ember"},"document_type":"report","language":"en","date_published":"2025-10-22","source_url":"https://ember-energy.org/app/uploads/2025/10/Policy-paper-From-Captive-Coal-to-Green-Nickel_-Securing-Indonesias-Future-Competitiveness-2.pdf","generator":"Climate Insights Directory","generated_fields":["summary","key_insights","climate_tags","geography_discussed","analysis_type"],"summary":{"text":"The report examines the paradox of Indonesia's nickel sector, where a critical mineral for the clean energy transition is processed using carbon-intensive captive coal. It identifies a significant expansion of captive coal capacity, projected to exceed 32 GW by 2031, driven by resource nationalism and the need for stable power in remote regions. The document contrasts 'Green Opportunism' (short-term gains via coal) with 'Green Developmentalism' (long-term competitiveness via decarbonisation) and proposes specific roles for Chinese stakeholders to support a sustainable transition through technical assistance, green finance, and market-shaping rules.","ai_generated":true,"unit":"ember-000527#summary","date_modified":"2026-10-23"},"key_insights":[{"text":"Indonesia's captive coal capacity reached 15.5 GW in 2024, with over 65% serving smelters. Projections from the National Electricity Master Plan (RUKN) suggest this could more than double to over 32 GW by 2031, a scale nearly equivalent to Germany's entire coal fleet.","ai_generated":true,"unit":"ember-000527#insight-1","date_modified":"2026-10-23"},{"text":"The reliance on captive coal is rooted in Indonesia's 'downstreaming' strategy and resource nationalism, which mandated domestic processing. Coal became the preferred energy source due to its reliability, short construction time (2-3 years compared to up to 10 years for hydropower), and the weakness of national grids in remote nickel-rich areas of Sulawesi and Halmahera.","ai_generated":true,"unit":"ember-000527#insight-2","date_modified":"2026-10-23"},{"text":"Chinese companies are the dominant investors in Indonesia's nickel sector; by the end of 2023, they accounted for approximately 75% of smelting capacity and produced over 85% of battery-grade nickel.","ai_generated":true,"unit":"ember-000527#insight-3","date_modified":"2026-10-23"},{"text":"Current policy gaps hinder decarbonisation, specifically exemptions for captive coal plants classified as National Strategic Projects in Presidential Regulation (PR) No. 112/2022 and the Green Finance Taxonomy, which labels coal power for critical minerals as 'transitional' investment.","ai_generated":true,"unit":"ember-000527#insight-4","date_modified":"2026-10-23"},{"text":"The report identifies two strategic paths: 'Green Opportunism,' which prioritises immediate growth while locking in coal dependence, and 'Green Developmentalism,' which uses decarbonisation as a lever for competitiveness to avoid exclusion from premium markets like the EU due to the Carbon Border Adjustment Mechanism and battery passports.","ai_generated":true,"unit":"ember-000527#insight-5","date_modified":"2026-10-23"},{"text":"China can support Indonesia's transition by co-developing park-level transition plans for hubs like Morowali and Weda Bay, championing 'green minerals' tracks in RCEP, and encouraging buyers to sign offtake MOUs indexed to declining emissions intensity.","ai_generated":true,"unit":"ember-000527#insight-6","date_modified":"2026-10-23"}],"climate_tags":["energy transition","electric vehicle","renewable energy","sustainable finance","Carbon Border Adjustment Mechanism","emission intensity","decarbonization"],"geography_discussed":["People's Republic of China","Sulawesi","Halmahera Island","Morowali","Weda Bay Industrial Park","Germany","Vietnam","Australia"],"frame_perspective":[],"analysis_type":["policy analysis","strategic assessment","economic analysis"]},{"id":"ember-000015","url":"https://climateinsightsdirectory.org/document/ember-000015","title":"Achieving the 2035 targets is possible through grid upgrades and diverse solar power plant applications","publisher":{"name":"Ember","organization":"ember"},"document_type":"report","language":"en","date_published":"2025-10-21","source_url":"https://ember-energy.org/chapter/achieving-the-2035-targets-is-possible-through-grid-upgrades-and-diverse-solar-power-plant-applications/","generator":"Climate Insights Directory","generated_fields":["summary","key_insights","climate_tags","analysis_type"],"summary":{"text":"Türkiye aims for 120 GW of wind and solar capacity by 2035, but grid capacity limits and bureaucratic hurdles pose significant obstacles. The report suggests redirecting the $8.7 billion allocated for domestic coal subsidies toward grid modernisation and storage-integrated projects. Key strategies for increasing capacity include deploying rooftop solar (with a 120 GW potential), floating and hybrid solar at dammed hydroelectric plants, and utilizing a 33.1 GW stock of storage-integrated projects to maintain grid balance.","ai_generated":true,"unit":"ember-000015#summary","date_modified":"2026-10-23"},"key_insights":[{"text":"Türkiye's target of 120 GW of total installed wind and solar capacity by 2035 is deemed unfeasible without upgrading the electricity grid and eliminating bureaucratic barriers to solar projects.","ai_generated":true,"unit":"ember-000015#insight-1","date_modified":"2026-10-23"},{"text":"The budget for supporting domestic coal power plants until 2030 is $8.7 billion, which is 53% higher than the ₺362 billion (approximately $5.7 billion) planned by TEİAŞ for grid upgrades between 2024 and 2028.","ai_generated":true,"unit":"ember-000015#insight-2","date_modified":"2026-10-23"},{"text":"To reach the specific solar target of 76.9 GW by 2035, Türkiye must install an average of 5.3 GW annually over the next 10 years, starting from an installed capacity of 24.1 GW as of September 2025.","ai_generated":true,"unit":"ember-000015#insight-3","date_modified":"2026-10-23"},{"text":"Rooftop solar represents a significant potential of 120 GW and can meet 21% of consumption during peak cooling demand hours, which are increasing as every 1°C temperature rise adds an average of 770 MWh to consumption.","ai_generated":true,"unit":"ember-000015#insight-4","date_modified":"2026-10-23"},{"text":"Türkiye possesses a stock of 33.1 GW in storage-integrated solar and wind projects to help maintain grid frequency and voltage balance, though the current maximum price policy hinders new investments.","ai_generated":true,"unit":"ember-000015#insight-5","date_modified":"2026-10-23"}],"climate_tags":["solar energy","wind energy","electrical grid","rooftop photovoltaic system","energy storage","hydroelectricity","energy transition"],"geography_discussed":[],"frame_perspective":[],"analysis_type":["policy assessment","capacity analysis"]},{"id":"ember-000017","url":"https://climateinsightsdirectory.org/document/ember-000017","title":"2030’a kadar yerli kömüre toplam 8,7 milyar dolar alım garantisi sağlanacak","publisher":{"name":"Ember","organization":"ember"},"document_type":"report","language":"tr","date_published":"2025-10-21","source_url":"https://ember-energy.org/tr/chapter/2030a-kadar-yerli-komure-toplam-87-milyar-dolar-alim-garantisi-saglanacak/","generator":"Climate Insights Directory","generated_fields":["summary","key_insights","climate_tags","analysis_type"],"summary":{"text":"The report analyzes a new purchase guarantee for domestic coal power plants in Turkey, which will provide a price of 75 USD/MWh for 60% of their electricity production until 2030. This mechanism is estimated to cost 8.7 billion USD and represents a 12% increase over the average sales price of the last year. The document highlights that these plants will continue to receive support through the existing capacity mechanism regardless of whether they generate electricity, meaning the new guarantee exceeds the total costs determined by TEİAŞ by 27%.","ai_generated":true,"unit":"ember-000017#summary","date_modified":"2026-10-23"},"key_insights":[{"text":"A purchase guarantee of 75 USD/MWh has been announced for 60% of the electricity produced by plants using domestic coal until 2030. If implemented starting in 2026, this four-year period is estimated to cost 8.7 billion USD.","ai_generated":true,"unit":"ember-000017#insight-1","date_modified":"2026-10-23"},{"text":"The 75 USD/MWh guarantee is 12% higher than the average sales price of the last year (67 USD/MWh) and 34% higher than the average Market Clearing Price (PTF) for the 2018–2025 period (56 USD/MWh).","ai_generated":true,"unit":"ember-000017#insight-2","date_modified":"2026-10-23"},{"text":"The inclusion of plants that use a mix of imported and domestic coal could increase the total support cost by 1.2 billion USD, raising the total to 9.8 billion USD, even if these plants only meet 10% of their annual production with domestic coal.","ai_generated":true,"unit":"ember-000017#insight-3","date_modified":"2026-10-23"},{"text":"Domestic coal plants will continue to receive payments under the capacity mechanism for fixed and variable costs regardless of electricity production. The proposed 75 USD/MWh guarantee is approximately 27% higher than the total cost of roughly 59 USD/MWh determined by TEİAŞ in August 2025.","ai_generated":true,"unit":"ember-000017#insight-4","date_modified":"2026-10-23"}],"climate_tags":["coal-fired power station","electricity price","energy subsidy","energy security"],"geography_discussed":[],"frame_perspective":[],"analysis_type":["financial assessment","policy analysis"]},{"id":"ember-000018","url":"https://climateinsightsdirectory.org/document/ember-000018","title":"2035 hedeflerine ulaşmak şebekenin yenilenmesi ve farklı güneş santrali projeleri ile mümkün","publisher":{"name":"Ember","organization":"ember"},"document_type":"report","language":"tr","date_published":"2025-10-21","source_url":"https://ember-energy.org/tr/chapter/2035-hedeflerine-ulasmak-sebekenin-yenilenmesi-ve-farkli-gunes-santrali-projeleri-ile-mumkun/","generator":"Climate Insights Directory","generated_fields":["summary","key_insights","climate_tags","analysis_type"],"summary":{"text":"Turkey aims for 120 GW of wind and solar capacity by 2035, but grid capacity limits and bureaucratic hurdles pose significant risks. The report highlights that the $8.7 billion earmarked for domestic coal support through 2030 exceeds the 362 billion TL (approx. $5.7 billion) needed for a five-year grid renewal plan by 53%. To meet the 76.9 GW solar target, Turkey must install an average of 5.3 GW annually over the next decade, utilizing floating solar on dams, hybrid systems, storage, and rooftop solar to reduce grid pressure and ensure system stability.","ai_generated":true,"unit":"ember-000018#summary","date_modified":"2026-10-23"},"key_insights":[{"text":"Turkey's target of 120 GW of wind and solar capacity by 2035 is unattainable without grid renewal and the removal of bureaucratic obstacles for various solar energy projects.","ai_generated":true,"unit":"ember-000018#insight-1","date_modified":"2026-10-23"},{"text":"The financial resources allocated to support domestic coal plants through 2030 ($8.7 billion) are 53% higher than the estimated cost for a five-year grid renewal plan, which TEİAŞ estimates at 362 billion TL (approximately $5.7 billion).","ai_generated":true,"unit":"ember-000018#insight-2","date_modified":"2026-10-23"},{"text":"Grid capacity for unlicensed plants—which make up 90% of solar capacity—has been exhausted at the transmission level since September 2024 and will be exhausted at the distribution level by July 2025.","ai_generated":true,"unit":"ember-000018#insight-3","date_modified":"2026-10-23"},{"text":"To reach the 2035 solar target of 76.9 GW from the September 2025 level of 24.1 GW, Turkey must achieve an average annual installation of 5.3 GW over the next ten years.","ai_generated":true,"unit":"ember-000018#insight-4","date_modified":"2026-10-23"},{"text":"Diversifying solar projects—including floating solar on dams, hybrid systems, storage, and rooftop solar (which has a 120 GW potential)—is essential to manage grid loads and maintain system stability, though maximum price policies currently hinder storage investments.","ai_generated":true,"unit":"ember-000018#insight-5","date_modified":"2026-10-23"}],"climate_tags":["wind energy","solar energy","electrical grid","Grid modernization","energy storage","rooftop photovoltaic system","energy transition"],"geography_discussed":[],"frame_perspective":[],"analysis_type":["policy analysis","financial assessment"]},{"id":"ember-000026","url":"https://climateinsightsdirectory.org/document/ember-000026","title":"Generating electricity from solar is 21% cheaper than from domestic coal","publisher":{"name":"Ember","organization":"ember"},"document_type":"report","language":"en","date_published":"2025-10-21","source_url":"https://ember-energy.org/chapter/generating-electricity-from-solar-is-21-cheaper-than-from-domestic-coal/","generator":"Climate Insights Directory","generated_fields":["summary","key_insights","climate_tags","analysis_type"],"summary":{"text":"As of 2025, solar energy is the cheapest source of electricity generation in Türkiye, with a Levelised Cost of Electricity (LCOE) of $43 USD/MWh. This is 21% cheaper than the average cost of generating electricity from existing domestic coal plants ($55 USD/MWh) and 52% cheaper than a new domestic coal plant, which is estimated at $90 USD/MWh. Over the last decade, solar installation costs in Türkiye fell by 77%, contributing to a 69% reduction in LCOE. In contrast, the average cost for domestic coal generation varies significantly based on plant efficiency and coal calorific value, ranging from $32 USD/MWh to $86 USD/MWh. Furthermore, purchase prices for wind and solar projects under recent YEKA tenders are less than half of the $75 USD/MWh provided to domestic coal power plants until 2030.","ai_generated":true,"unit":"ember-000026#summary","date_modified":"2026-10-23"},"key_insights":[{"text":"Solar energy is the most cost-effective electricity source in Türkiye as of 2025, with its Levelised Cost of Electricity (LCOE) for new plants reaching $43 USD/MWh, representing a 69% decrease over the last ten years.","ai_generated":true,"unit":"ember-000026#insight-1","date_modified":"2026-10-23"},{"text":"Generating electricity from solar is 21% cheaper than from existing domestic coal plants, which have an average generation cost of $55 USD/MWh (including transport).","ai_generated":true,"unit":"ember-000026#insight-2","date_modified":"2026-10-23"},{"text":"New domestic coal plants are significantly more expensive than solar; a replacement 1.5 GW coal plant would have an LCOE of approximately $90 USD/MWh, more than double the cost of a new solar plant.","ai_generated":true,"unit":"ember-000026#insight-3","date_modified":"2026-10-23"},{"text":"Domestic coal generation costs in Türkiye vary widely based on efficiency and calorific value, with the cheapest plant costing $32 USD/MWh and the most expensive costing $86 USD/MWh.","ai_generated":true,"unit":"ember-000026#insight-4","date_modified":"2026-10-23"},{"text":"Purchase prices for wind and solar projects awarded in early 2025 YEKA tenders are less than half of the $75 USD/MWh incentive provided to domestic coal power plants until 2030.","ai_generated":true,"unit":"ember-000026#insight-5","date_modified":"2026-10-23"}],"climate_tags":["solar energy","coal power","wind power","energy policy"],"geography_discussed":[],"frame_perspective":[],"analysis_type":["economic analysis","comparative cost assessment"]},{"id":"ember-000169","url":"https://climateinsightsdirectory.org/document/ember-000169","title":"$8.7 billion support pledged for domestic coal until 2030","publisher":{"name":"Ember","organization":"ember"},"document_type":"report","language":"en","date_published":"2025-10-21","source_url":"https://ember-energy.org/chapter/8-7-billion-support-pledged-for-domestic-coal-until-2030/","generator":"Climate Insights Directory","generated_fields":["summary","key_insights","climate_tags","analysis_type"],"summary":{"text":"The report analyzes a Turkish government incentive providing a $75 USD/MWh purchase guarantee for 60% of electricity generated by domestic coal plants until 2030, estimated to cost $8.7 billion. It highlights that this guarantee is 12% higher than recent average market prices and 27% higher than the total costs determined by the Turkish Electricity Transmission Corporation (TEİAŞ). Additionally, these plants continue to receive payments under a capacity mechanism that covers fixed and variable costs regardless of generation.","ai_generated":true,"unit":"ember-000169#summary","date_modified":"2026-10-23"},"key_insights":[{"text":"The Turkish government has announced a purchase guarantee of $75 USD/MWh for 60% of the electricity generated by domestic coal power plants until 2030, which is estimated to cost $8.7 billion over a four-year implementation period starting in 2026.","ai_generated":true,"unit":"ember-000169#insight-1","date_modified":"2026-10-23"},{"text":"The $75 USD/MWh guarantee represents a 12% increase over the average electricity sales price of the past year and a 34% increase compared to the average Market Clearing Price (MCP) between 2018 and 2025, which was $56 USD/MWh.","ai_generated":true,"unit":"ember-000169#insight-2","date_modified":"2026-10-23"},{"text":"The purchase guarantee is 27% higher than the total cost of approximately $59 USD/MWh determined for domestic coal power plants by the Turkish Electricity Transmission Corporation (TEİAŞ) in August 2025.","ai_generated":true,"unit":"ember-000169#insight-3","date_modified":"2026-10-23"},{"text":"If power plants using imported coal are eligible for the incentive by sourcing just 10% of their annual generation from domestic coal, the total support cost is projected to increase by $1.2 billion to a total of $9.8 billion.","ai_generated":true,"unit":"ember-000169#insight-4","date_modified":"2026-10-23"},{"text":"Domestic coal plants receive additional payments via a capacity mechanism since 2018 to ensure supply security; over the past year, this mechanism paid 7 billion TL ($188 million) to power plants, covering costs even when they are not generating electricity.","ai_generated":true,"unit":"ember-000169#insight-5","date_modified":"2026-10-23"}],"climate_tags":["electricity price","energy subsidy"],"geography_discussed":[],"frame_perspective":[],"analysis_type":["financial assessment"]},{"id":"ember-000276","url":"https://climateinsightsdirectory.org/document/ember-000276","title":"$8.7 billion coal subsidy contradicts Türkiye's renewable goals","publisher":{"name":"Ember","organization":"ember"},"document_type":"report","language":"en","date_published":"2025-10-21","source_url":"https://ember-energy.org/app/uploads/2025/10/EN-8.7-billion-coal-subsidy-contradicts-Turkiyes-renewable-goals.pdf","generator":"Climate Insights Directory","generated_fields":["summary","key_insights","climate_tags","analysis_type"],"summary":{"text":"Türkiye has pledged a purchase guarantee of $75 USD/MWh for domestic coal power plants through 2030, an incentive estimated to cost at least $8.7 billion over four years. This subsidy is 12% higher than the average sales price of $67 USD/MWh and 36% above the average electricity generation cost of domestic coal ($55 USD/MWh). The report finds that solar energy is now the cheapest source of electricity in Türkiye, with a Levelised Cost of Electricity (LCOE) of $43 USD/MWh, representing a 69% decrease over the last decade. In contrast, a new domestic coal plant would have an LCOE of approximately $90 USD/MWh. The $8.7 billion coal subsidy is 53% higher than the ₺362 billion (approximately $5.7 billion) budget allocated by TEİAŞ for grid upgrades between 2024 and 2028. The report argues that achieving the 2035 target of 120 GW of total installed wind and solar capacity requires upgrading the grid and removing bureaucratic barriers to rooftop, floating, hybrid, and storage-integrated solar projects.","ai_generated":true,"unit":"ember-000276#summary","date_modified":"2026-10-23"},"key_insights":[{"text":"Türkiye has committed to a purchase guarantee of $75 USD/MWh for 60% of the electricity generated by domestic coal power plants until 2030, which is estimated to cost at least $8.7 billion over four years.","ai_generated":true,"unit":"ember-000276#insight-1","date_modified":"2026-10-23"},{"text":"The $75 USD/MWh coal incentive is significantly higher than current market rates and production costs, sitting 12% above the average sales price of $67 USD/MWh and 36% above the average generation cost of $55 USD/MWh.","ai_generated":true,"unit":"ember-000276#insight-2","date_modified":"2026-10-23"},{"text":"Solar energy has become the cheapest electricity source in Türkiye, with installation costs falling by 77% and the Levelised Cost of Electricity (LCOE) dropping 69% over the last decade to $43 USD/MWh.","ai_generated":true,"unit":"ember-000276#insight-3","date_modified":"2026-10-23"},{"text":"New solar power plants are substantially more cost-effective than new coal plants; the LCOE of a new domestic coal plant is approximately $90 USD/MWh, which is more than double the $43 USD/MWh cost of a new solar plant.","ai_generated":true,"unit":"ember-000276#insight-4","date_modified":"2026-10-23"},{"text":"The financial support for coal is disproportionate to grid investment; the $8.7 billion coal subsidy is 53% higher than the $5.7 billion (₺362 billion) budget TEİAŞ has allocated for grid upgrades from 2024 to 2028.","ai_generated":true,"unit":"ember-000276#insight-5","date_modified":"2026-10-23"},{"text":"To reach the 2035 target of 120 GW of wind and solar capacity, Türkiye must address grid capacity limits and remove bureaucratic barriers to diverse solar applications, including rooftop, floating, hybrid, and storage-integrated projects.","ai_generated":true,"unit":"ember-000276#insight-6","date_modified":"2026-10-23"}],"climate_tags":["solar energy","wind power","Grid modernization","rooftop photovoltaic system","energy storage","energy transition"],"geography_discussed":[],"frame_perspective":[],"analysis_type":["economic assessment","policy analysis"]},{"id":"ember-000469","url":"https://climateinsightsdirectory.org/document/ember-000469","title":"Güneşle elektrik üretmek, yerli kömüre göre %21 daha ucuz","publisher":{"name":"Ember","organization":"ember"},"document_type":"report","language":"tr","date_published":"2025-10-21","source_url":"https://ember-energy.org/tr/chapter/gunesle-elektrik-uretmek-yerli-komure-gore-%21-daha-ucuz/","generator":"Climate Insights Directory","generated_fields":["summary","key_insights","climate_tags","analysis_type"],"summary":{"text":"Solar energy has become the cheapest electricity generation method in Turkey, with the Levelized Cost of Electricity (LCOE) for new solar plants falling to 43 USD/MWh. This is 21% lower than the average cost of existing domestic coal plants (55 USD/MWh) and significantly cheaper than the projected 90 USD/MWh for new domestic coal plants. While the Turkish National Energy Plan targets 1.7 GW of new domestic coal by 2030, the document highlights that solar installation costs have dropped by 77% over the last decade, making new solar plants 52% cheaper than new domestic coal plants.","ai_generated":true,"unit":"ember-000469#summary","date_modified":"2026-10-23"},"key_insights":[{"text":"Solar energy is currently the most affordable electricity generation method in Turkey, with new solar plant LCOE dropping 69% over the last ten years to 43 USD/MWh. This cost is 21% lower than the average cost of existing domestic coal plants and 15% lower than existing imported coal plants.","ai_generated":true,"unit":"ember-000469#insight-1","date_modified":"2026-10-23"},{"text":"The average cost of electricity production from domestic coal in Turkey is 55 USD/MWh, including a transport cost estimated at 5% of the sale price. Costs vary significantly by plant efficiency and coal heating value, ranging from a low of 32 USD/MWh for high-efficiency plants (42% efficiency, 2,500 kcal/kg) to 86 USD/MWh for the most expensive plants (28% efficiency, 1,100 kcal/kg).","ai_generated":true,"unit":"ember-000469#insight-2","date_modified":"2026-10-23"},{"text":"New solar installations are substantially cheaper than new domestic coal capacity. A new solar plant's LCOE (43 USD/MWh) is less than half the estimated LCOE of a new 1.5 GW domestic coal plant (approximately 90 USD/MWh). New solar plants are projected to be 52% cheaper than new domestic coal plants.","ai_generated":true,"unit":"ember-000469#insight-3","date_modified":"2026-10-23"},{"text":"Under the YEKA model, recent auctions for wind and solar capacity (conducted in early 2025) resulted in purchase prices significantly lower than the 75 USD/MWh price provided to domestic coal plants until 2030. Winning firms committed a total of 220 million dollars in contribution payments to the state.","ai_generated":true,"unit":"ember-000469#insight-4","date_modified":"2026-10-23"}],"climate_tags":["solar energy","coal power","wind energy","energy policy"],"geography_discussed":[],"frame_perspective":[],"analysis_type":["economic analysis","comparative cost assessment"]}]}