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Oil And Gas Extraction Moves Offshore In 2024
Global Energy Monitor
Oil And Gas Extraction Moves Offshore In 2024The vast majority of new oil and gas extraction projects discovered, approved, and started up in 2024 were located offshore, exacerbating risks to oceans as well as running afoul of the scientific consensus that any new field is incompatible with limiting warming to 1.5°C, according to a new report from Global Energy Monitor. Data in the Global Oil and Gas Extraction Tracker show that, on and offshore globally, at least 9 billion barrels of oil equivalent (bboe) of resources were announced in new discoveries, nearly 4 bboe of reserves were approved for development, and about 6.5 bboe began to be tapped as projects started up. Most of these developments are concentrated in the oceans. Eighty-five percent of new discoveries by volume were located in ten offshore fields. At least twelve projects reached a positive Final Investment Decision in 2024, all of which were offshore. Nineteen offshore projects produced first oil or gas in 2024 — 71% of the total volume of field startups. Discoveries, project approvals, and startups all have marginal increases in offshore volume percentages compared to 2023. Historically, onshore oil and gas projects account for the majority of production. However, exploration and extraction companies are focusing offshore, with increased attention on unlocking new frontier areas via high-risk, higher-cost, further offshore development.  GOGET data show that offshore discoveries have been growing in share of global discoveries per year, accounting for about 60% in the 2010s and around 73% so far in the 2020s.The risks from offshore drilling exist throughout the lifecycle of a project. A United Nations report recently called for, among other things, the halting of new offshore oil and gas projects until a series of safeguards and assessments is made. Scott Zimmerman, Project Manager for the Global Oil and Gas Extraction Tracker at Global Energy Monitor, said, “’Out of sight, out of mind’ does not work in high-risk scenarios like offshore oil and gas extraction. Expansions into uncharted waters are risky bets – financially, for ecosystems, and for the climate.” Contact Scott Zimmerman Project Manager, Global Oil and Gas Extraction Tracker, Global Energy Monitor [email protected]
powerplant
Mar 03, 2025
U.S. Bet On Gas Plants To Meet Uncertain Ai Energy Demand Risks $85 Billion In Stranded Assets
Global Energy Monitor
U.S. Bet On Gas Plants To Meet Uncertain Ai Energy Demand Risks $85 Billion In Stranded AssetsThe United States now has the second-largest pipeline of gas-fired power plants in development globally, driven in part by speculation about future energy demand to fuel a burgeoning AI industry. https://globalenergymonitor.org/wp-content/uploads/2025/02/GEM-briefing-US-gas-plants-AI-Energy-Demand-Feb-2025.pdf But this glut of new projects, many of which currently languish in the earliest phases, could lead to US$85 billion in stranded assets [1] if the gas demand bubble pops, according to a new analysis from Global Energy Monitor. Data in the Global Oil and Gas Plant Tracker show that over the last year, the U.S. more than doubled its oil- and gas-fired capacity in development — projects in the announced, pre-construction, and construction phases — totalling over 85 gigawatts (GW). This increase has propelled the country to second in the world, behind China, for oil- and gas-fired projects in development. If all in-development plants are built, the U.S.’ existing oil and gas fleet would grow by 15%, at an estimated cost of over US$85 billion in capital costs. If future AI power demand does not materialize, any new gas plants built risk becoming stranded assets and either being decommissioned before the end of their economic life or experiencing significant underutilization. Roughly two thirds of in-development plants are located in states serviced by just three grid operators: the Electric Reliability Council of Texas (ERCOT), Midcontinent ISO (MISO) and PJM Interconnection (PJM). ERCOT covers most of Texas, MISO covers parts of 15 states, and PJM covers parts of 13 states and Washington DC. With the gas power plant buildout facing longer construction timelines, supply constraints, and rising costs, renewables combined with battery storage are better positioned to meet an immediate rise in power demand. The levelized cost of electricity for solar and onshore wind is cheaper than any other source, including gas, in the U.S. Jenny Martos, Project Manager for the Global Oil and Gas Plants Tracker at Global Energy Monitor, said, “With all the uncertainty around future AI energy demand, a bet this big on gas power is a risky one. Not only are construction costs and lead times for securing gas turbines increasing, but renewables and battery storage are ready now, fast to deploy and cheaper than building new gas power.” Contact Jenny Martos Project Manager, Global Oil and Gas Plants Tracker, Global Energy Monitor [email protected]
powerplant
Feb 26, 2025
India Can Hit 2030 Energy Milestone If Pace Of Renewables Additions Continues
Global Energy Monitor
India Can Hit 2030 Energy Milestone If Pace Of Renewables Additions ContinuesIndia is on the cusp of hitting its ambitious 2030 energy targets, if the country can continue to add renewables at the same record-setting growth seen in the last year, according to a new report from Global Energy Monitor.  In 2024, renewables accounted for nearly three-quarters of the record 35 gigawatts (GW) of power capacity brought online, with the vast majority of this capacity coming from new solar photovoltaics. Data in the Global Integrated Power Tracker show that if India replicates last year’s annual wind and solar deployment until the end of the decade, the country’s renewables fleet would expand around 80% to 378 gigawatts (GW).  With an additional 24 GW of hydropower capacity slated to come online by 2030, India would be about 100 GW short of its 500 GW target of non-fossil power capacity by 2030. Closing this gap with wind and solar would require annual capacity additions to grow year-on-year at about 15%.  Post-pandemic wind and solar growth rates have tracked slightly above this level, suggesting that renewables expansion in line with the 500 GW target is attainable if the recent pace of growth can be maintained. Such growth would see annual wind and solar additions more than double the record levels in 2024 by 2030. The new GEM report also shows that the combined capacity of wind, utility-scale solar, and hydropower in development — projects that have been announced or are in the pre-construction and construction phases — is on track to overtake operating coal capacity within the next two years. Utility-scale solar projects comprise nearly half of all renewables in development, with more capacity in the construction phase than for coal projects. Still, despite the strong year, renewables only made up around one-fifth of the total increase in power generation in 2024, with fossil power contributing more than two-thirds. A significant uptick in renewables deployment is required to eat into coal’s dominance. This is because renewables tend to generate less readily than fossil sources, particularly wind and solar, which average a utilization rate of 17–22% across the year, compared to coal’s 70%. James Norman, Project Manager for the Global Integrated Power Tracker at Global Energy Monitor, said, “The impressive growth of renewables in the last year, especially solar, shows how serious India is taking its climate targets. The clean energy transition is well underway, but without continued and sustained growth of wind and solar coal will continue to reign supreme.” Contact James Norman Project Manager, Global Integrated Power Tracker, Global Energy Monitor [email protected]
powerplant
Feb 25, 2025
Europe Ramps Up Hydrogen Plans At Gas Sites But Few Projects Take Off
Global Energy Monitor
Europe Ramps Up Hydrogen Plans At Gas Sites But Few Projects Take OffKey points Nearly all the European projects to introduce hydrogen into gas-fired power plants, LNG terminals, and gas transmission pipelines in an effort to decarbonize the energy system have yet to move beyond the announcement phase, finds a new report from Global Energy Monitor.  Offering one of the most comprehensive looks to date at Europe’s hydrogen infrastructure plans, and how they overlay the region’s gas network, the Europe Gas Tracker documents 96 gas-fired power plants with 44.6 gigawatts (GW) of capacity to burn hydrogen — roughly the size of Italy’s gas-fired power fleet — as well as twelve projects to expand or convert LNG terminals to import hydrogen derivatives, and 323 pipelines to transport hydrogen over 50,000 kilometers — a 40% increase in the length of hydrogen pipelines in development last year. Hydrogen produced from renewable energy could be an important decarbonization tool in certain applications, such as industrial processes where fossil-based hydrogen is used today. However, Europe’s hydrogen plans appear, at best, out of touch with the science and economics of the fuel, and at worst, like an attempt by the oil and gas industry to extend the lifetime of Europe’s dependency on gas. The majority of these proposed projects are still in early stages and have not advanced beyond the drafting board. Among hydrogen-burning proposals at power plants, several pilot projects have begun operating with small amounts of hydrogen, but almost three-quarters of all capacity is still in the earliest phases of only having been announced.  More than half of these hydrogen power projects do not have a start year specified, and only a small fraction have secured memoranda of understanding, contracts, or financing for hydrogen supplies. Among hydrogen pipeline projects, plans are split evenly between using new pipelines, retrofitting existing gas pipelines, and using a mix of new and retrofitted pipelines. However, retrofitting pipelines for hydrogen would largely entail replacing them. The European Commission’s most recent Projects of Common Interest list offers funding and streamlined permitting to hydrogen-capable pipeline projects totaling 22,394 km. Some hydrogen pipelines on the list appear nearly identical to older gas pipeline proposals, suggesting that gas companies could be using hydrogen branding to garner support. No hydrogen derivative import projects at LNG facilities have begun construction or taken final investment decisions indicating they will move forward, and just one pipeline to transport hydrogen gas is currently being built. The International Energy Agency has warned that planning is far behind on projects to produce hydrogen from renewable energy sources that would supply this sprawling network.  Meanwhile, the buildout of LNG infrastructure appears to be slowing. Several major projects came online last year, but the pace of new proposals has nearly ground to a halt, with just one new import project mooted in 2024. Five projects totalling 28.7 billion cubic meters per year in new LNG import capacity came online, two-thirds of the capacity that was added in 2023.  As European gas demand begins to fall, these projects are unnecessary and risk wasting public and private investment. Robert Rozansky, Project Manager for the Europe Gas Tracker, said, “A hydrogen network of this scale, with power production as a major end use, is impractical and unrealistic as a decarbonization strategy. Rather than risk locking in gas, EU policy makers should require project developers to make clear how they will source green hydrogen. This will hold regulators to account and allow for better project planning.” Contact Robert Rozansky Project Manager, Global LNG Analyst, Global Energy Monitor [email protected]
powerplant
Jan 29, 2025
Europe Ramps Up Hydrogen Plans At Gas Sites But Few Projects Take Off
Global Energy Monitor
Europe Ramps Up Hydrogen Plans At Gas Sites But Few Projects Take OffKey points Nearly all the European projects to introduce hydrogen into gas-fired power plants, LNG terminals, and gas transmission pipelines in an effort to decarbonize the energy system have yet to move beyond the announcement phase, finds a new report from Global Energy Monitor.  Offering one of the most comprehensive looks to date at Europe’s hydrogen infrastructure plans, and how they overlay the region’s gas network, the Europe Gas Tracker documents 96 gas-fired power plants with 44.6 gigawatts (GW) of capacity to burn hydrogen — roughly the size of Italy’s gas-fired power fleet — as well as twelve projects to expand or convert LNG terminals to import hydrogen derivatives, and 323 pipelines to transport hydrogen over 50,000 kilometers — a 40% increase in the length of hydrogen pipelines in development last year. Hydrogen produced from renewable energy could be an important decarbonization tool in certain applications, such as industrial processes where fossil-based hydrogen is used today. However, Europe’s hydrogen plans appear, at best, out of touch with the science and economics of the fuel, and at worst, like an attempt by the oil and gas industry to extend the lifetime of Europe’s dependency on gas. The majority of these proposed projects are still in early stages and have not advanced beyond the drafting board. Among hydrogen-burning proposals at power plants, several pilot projects have begun operating with small amounts of hydrogen, but almost three-quarters of all capacity is still in the earliest phases of only having been announced.  More than half of these hydrogen power projects do not have a start year specified, and only a small fraction have secured memoranda of understanding, contracts, or financing for hydrogen supplies. Among hydrogen pipeline projects, plans are split evenly between using new pipelines, retrofitting existing gas pipelines, and using a mix of new and retrofitted pipelines. However, retrofitting pipelines for hydrogen would largely entail replacing them. The European Commission’s most recent Projects of Common Interest list offers funding and streamlined permitting to hydrogen-capable pipeline projects totaling 22,394 km. Some hydrogen pipelines on the list appear nearly identical to older gas pipeline proposals, suggesting that gas companies could be using hydrogen branding to garner support. No hydrogen derivative import projects at LNG facilities have begun construction or taken final investment decisions indicating they will move forward, and just one pipeline to transport hydrogen gas is currently being built. The International Energy Agency has warned that planning is far behind on projects to produce hydrogen from renewable energy sources that would supply this sprawling network.  Meanwhile, the buildout of LNG infrastructure appears to be slowing. Several major projects came online last year, but the pace of new proposals has nearly ground to a halt, with just one new import project mooted in 2024. Five projects totalling 28.7 billion cubic meters per year in new LNG import capacity came online, two-thirds of the capacity that was added in 2023.  As European gas demand begins to fall, these projects are unnecessary and risk wasting public and private investment. Robert Rozansky, Project Manager for the Europe Gas Tracker, said, “A hydrogen network of this scale, with power production as a major end use, is impractical and unrealistic as a decarbonization strategy. Rather than risk locking in gas, EU policy makers should require project developers to make clear how they will source green hydrogen. This will hold regulators to account and allow for better project planning.” Contact Robert Rozansky Project Manager, Global LNG Analyst, Global Energy Monitor [email protected]
powerplant
Jan 29, 2025
Indonesia Captive Coal Power On Track To Exceed AustraliaÊŒS Current Total Coal Power Generation Capacity By 2026
Global Energy Monitor
Indonesia Captive Coal Power On Track To Exceed AustraliaÊŒS Current Total Coal Power Generation Capacity By 2026JAKARTA, 8 November, 2024 – This month marks two years into the signing of the Indonesia Just Energy Transition Partnership (JETP), and captive coal power in the country is showing no signs of slowing down. According to a new analysis by the Centre for Research on Energy and Clean Air (CREA) and Global Energy Monitor (GEM), between July 2023 and July 2024, IndonesiaÊŒs coal power capacity saw a 15% increase, totalling 7.2 GW. Of that, 2.6 GW comes from independent power producers (IPPs) and 4.5 GW from captive use, meaning new coal capacity for industry wasn early double that of coal for the national grid. The analysis– an update to CREA and GEMÊŒs 2023 report–finds that sizable growth in captive coal is expected to continue, with an estimated total of 11.04 GW up to 2026, including all units in the construction, pre-permitted, and announced phases. Combined with the 132 units of operational captive coal-fired power plants (CFPPs) totaling 15.2 GW, proposals would put total captive coal capacity at 26.24 GW, which is greater than the total coal plant capacity of all of Australia in 2023and would put captive in the largest share of IndonesiaÊŒs coal generation outside of PLN and IPPs, at nearly 40%. Captive coal power in Indonesia is mainly dedicated to powering a select range of energy-intensive industries, with metals such as nickel and aluminium holding major shares, followed by pulp and paper, chemicals, cement, and textiles. Major additions of CFPPs in the pipeline are attributed to IndonesiaÊŒs metals processing industry, such as nickel. While nickel is a critical metal for EVs and batteries, captive coal plants are among the most carbon-intensive routes to meet this demand. The health and economic impacts of unchecked CFPP development in Indonesia would be catastrophic. Analysis on nickel industrial complexes located in Central and Southeast Sulawesi and North Maluku reveals that under the current growth pathway and without strengthened emission and environmental standards, exposure to air pollution emitted from coal-based smelting processes and associated captive coal power plants would lead to nearly 5,000 deaths in 2030 and cause IDR 56 trillion (USD 3.42 billion) in economic burden. Meanwhile, exclusion of captive CFPP retirement from a 2040 coal phase-out target would cause an additional 27,000 deaths and IDR 330 trillion (USD 20 billion) of economic burden from cumulative health impacts nationwide. However, showing a proactive stance on global climate partnerships like JETP and blessed with abundant renewables potential, Indonesia holds the capability to pivot from captive coal and become a leader in industrial decarbonisation. WhatÊŒs more, the financial benefits of renewables clearly outweigh those of remaining reliant on coal– by 2025, solar-storage levelized cost of electricity (LCOE) in Indonesia with preferential financing is projected to be USD 0.01 cents per kWh cheaper than coal. In the next decade, pricing will be even better, with the cost difference anticipated to be over USD0.03 cents perk Wh. In anticipation of the JETP SecretariatÊŒs release of IndonesiaÊŒs captive power landscape mapping, national and global stakeholders will be presented with a collective opportunity to catalyse decarbonisation efforts. Inclusion of captive CFPP retirement in IndonesiaÊŒs national plan would not only support the governmentÊŒs energy transition and climate targets, but would also garner interest for clean energy investments. Katherine Hasan, Analyst at CREA: “IndonesiaÊŒs willingness and ability to meet global climate commitments is manifest in the JETP as well as the recent release of the Second Nationally Determined Contribution (SNDC) draft. However, the efficacy of these actions is being threatened by an ever-expanding coal capacity within our nationÊŒs core industries. Setting a clear and ambitious schedule for early CFPP retirement and renewables integration would not only support the governmentÊŒs climate targets, but also help to attract the clean energy investments Indonesia needs to secure a strategic position in the global RE supply chain.” Lucy Hummer, Senior Researcher at Global Energy Monitor: “Addressing the role of coal in IndonesiaÊŒs energy transition cannot be limited to the power sector. It is critical to set out a clear pathway for all captive power facilities. As a leading supplier of critical minerals for the global clean energy supply chain, Indonesia must leverage its national plan and retire captive coal-fired power plants to decarbonise energy intensive industries like nickel, a process that requires both investment and strong governance.” Katherine Hasan, Analyst, CREA; [email protected] Lucy Hummer, Senior Researcher, Global Energy Monitor[email protected] About Centre for Research on Energy and Clean Air (CREA) CREA is an independent research organisation focused on revealing the trends, causes, and health impacts, as well as the solutions to air pollution. We use scientific data, research and evidence to support the efforts of governments, companies and campaigning organisations worldwide in their efforts to move towards clean energy and clean air. www.energyandcleanair.org   About Global Energy Monitor Global Energy Monitor (GEM) develops and shares information in support of the worldwide movement for clean energy. By studying the evolving international energy landscape, and creating databases, reports, and interactive tools that enhance understanding, GEM seeks to build an open guide to the world’s energy system.
powerplant
Nov 08, 2024
For The First Time, Fossil Fuels In Brics Countries To Drop Below Half Of Installed Power Capacity
Global Energy Monitor
For The First Time, Fossil Fuels In Brics Countries To Drop Below Half Of Installed Power CapacityKey points Fossil capacity is set to drop below half of the power capacity mix in the BRICS bloc for the first time ever this year, signaling an important milestone in the clean energy transition for countries that still host the vast majority of the world’s coal power, finds a new report from Global Energy Monitor. An analysis of data in the Global Integrated Power Tracker shows 72 gigawatts (GW) of fossil capacity in the BRICS scheduled to come online in 2024. Even in the unlikely case that a further 88 GW under construction without a known target start date also comes online, this total would still not exceed non-fossil additions already built in 2024: 190 GW of non-fossil capacity additions have already come online this year in China, India, and Brazil alone.  This would bring the total non-fossil capacity operating in the BRICS to 2,289 GW versus at most 2,245 GW fossil capacity.  For comparison, the European Union reached 50% non-fossil share at the start of the 2010s, and the G7 hit parity last year. Capacity refers to the maximum amount of electricity that can be produced at any one time, and generation is the amount of electricity that is actually generated over a period of time. In recent years, the share of fossil fuels has been on the decline in most BRICS countries, with China leading the group, as its share of fossil-fueled capacity has fallen twice that of other BRICS countries over the last five years. This sea change is thanks in part to the vast pipeline of wind and utility-scale solar capacity in development — projects that have been announced or are in the pre-construction and construction phases — which now outpaces fossils by two to one. Wind and utility-scale solar projects in development total 1,550 GW across the BRICS group. Adding in-development hydropower to this figure sees the capacity for in-development fossil-fueled projects in the BRICS outnumbered by nearly three to one. The impressive pace of non-fossil additions also means that BRICS countries have enough renewables projects in development to nearly triple such capacity by 2030. The target to triple total global renewables capacity by 2030, agreed at COP28, is considered one of the most important levers for reducing emissions and keeping the 1.5 degree-aligned pathway alive. If the 326 GW of wind and utility-scale solar capacity additions in 2023 continued to 2030, the BRICS group would see total renewable capacity increase by more than two and a half times. Furthermore, the sum of the BRICS’ in-development renewables projects due for completion by 2030 is 2,276 GW, or around 95% of the additional utility-scale renewable capacity estimated as necessary to achieve the global tripling target. Despite fossil-fueled power capacity losing ground in the BRICS’ power mix, virtually all members are building additional coal, oil, or gas plants. GEM data show all BRICS group countries, save Ethiopia, with fossil-fueled power projects in development. If built, fossil fuels projects in development would increase operating coal and oil and gas capacity in the BRICS groups by 36% and 53%, respectively. James Norman, Project Manager for the Global Integrated Power Tracker, said, “The BRICS bloc is at a watershed moment. The clean energy transition really is happening everywhere. Still BRICSs are some of the only countries in the world planning new coal projects, which would undermine the impressive progress to date in cleaning up their energy systems.” Contacts James Norman Project Manager, Global Integrated Power Tracker, Global Energy Monitor [email protected] About the Global Integrated Power Tracker The Global Integrated Power Tracker (GIPT) is a free-to-use Creative Commons database of over 116,000 power units globally, that draws from GEM trackers for coal, gas, oil, hydropower, utility-scale solar, wind, nuclear, bioenergy, and geothermal, as well as energy ownership. Footnoted wiki pages accompany all power facilities included in the GIPT, updated biannually. For more information on the data collection process that underpins GEM’s power sector trackers, please refer to the Global Integrated Power Tracker methodology page.
powerplant
Oct 21, 2024
Us$123 Billion Lng Build-Out Risks Derailing Energy Transition In Latin America
Global Energy Monitor
Us$123 Billion Lng Build-Out Risks Derailing Energy Transition In Latin AmericaKey points A rash of new LNG terminals and gas pipelines threatens to saddle Latin America with costly stranded assets and exposure to energy price swings, in spite of the region’s vast renewables potential, finds a report from Global Energy Monitor. Data in the Global Gas Infrastructure Tracker show planned LNG export and import terminals in the region totalling an estimated US$123.6 billion in new investments, much of which are concentrated in three countries: Mexico, Argentina, and Brazil. New LNG export projects have a high likelihood of becoming stranded assets if countries meet their own climate objectives, and recent geopolitical events, including Russia’s war in Ukraine, have demonstrated the volatility and unreliability of LNG imports.  All of these expansions to the region’s role in the LNG economy are planned despite the International Energy Agency’s warning that the global LNG trade should peak in the middle of this decade for the world to meet its climate goal of limiting global warming to 1.5℃.  Latin America’s LNG buildout faces significant barriers, however, and is by no means certain to advance. Given the region’s abundant renewable resources and its progress planning new renewable energy projects, countries could avoid sinking investment into the global LNG boom and focus on developing clean energy. Robert Rozansky, Global LNG Analyst at Global Energy Monitor, said “Latin America already has one of the cleanest electricity mixes in the world, so rushing headlong into the LNG economy would be a mistake. The silver lining is that many projects are still in the planning stages, so the region has an opportunity to sidestep the global LNG boom and avoid weighing down economies with risky fossil fuel investments. The smarter bet is to double down on the region’s vast wind and solar potential.” Contacts Robert Rozansky Project Manager, Global LNG Analyst, Global Energy Monitor [email protected] Gregor Clark Project Manager, Latin America Energy Portal, Global Energy Monitor [email protected] About the Global Gas Infrastructure Tracker The Global Gas Infrastructure Tracker (GGIT) is an information resource on natural gas transmission pipeline projects and liquefied natural gas (LNG) import and export terminals. The internal GGIT database and wiki pages are updated continuously throughout the year, and an annual release is published and distributed with data summary tables. The data are released under a creative commons license and can be downloaded here. About the Portal EnergĂ©tico para AmĂ©rica Latina (Latin America Energy Portal) GEM’s Latin America Energy Portal offers a region-wide perspective on energy infrastructure in Latin America and the Caribbean, through interactive maps and thousands of wiki pages. The Portal synthesizes GEM’s research on nearly 5,000 projects throughout the region, including coal- and gas-fired power plants, oil and gas pipelines, oil and gas extraction sites, LNG terminals, solar farms, wind farms, coal terminals, coal mines and steel plants that meet a predetermined size threshold.
powerplant
Oct 16, 2024
Bioenergy Capacity Skyrockets Sevenfold In Japan And South Korea Despite Concerns About Sustainability And Profitability
Global Energy Monitor
Bioenergy Capacity Skyrockets Sevenfold In Japan And South Korea Despite Concerns About Sustainability And ProfitabilityWoody biomass power stations are being used to meet renewable energy goals in Japan and South Korea despite their lack of financial viability and maintenance of the status quo for emissions, according to a new report from Global Energy Monitor.  Data in the Global Bioenergy Power Tracker show that Japan has 3.8 gigawatts (GW) of woody bioenergy capacity projected across 59 units by 2026 and South Korea has 1.46 GW projected across 32 units by the same year — an increase of 658% in the last ten years.  Japan and South Korea also have 16.7 GW of capacity across 55 units that co-fire bioenergy with coal being the primary fuel, according to data in the Global Coal Plant Tracker. This is equivalent to 17.4 per cent of the total operating capacity in those countries. Through its Renewable Energy Certificates (REC) in South Korea and the Feed-in-Tariff (FiT) program in Japan, dedicated woody biomass burning units receive renewable subsidies based on the false premise that they are carbon neutral. But supply chain emissions — including logging, transportation to a processing plant, processing into wood chips or pellets, and additional transportation to the power plant — remain a serious concern.  Those emissions are in addition to the carbon emissions from woody biomass itself, which can be 30% higher than coal burning emissions. Woody biomass must be burned in higher volumes than fossil fuels because of its lower energy density, and the emissions increase as the volume combusted grows.  The continued subsidies also crowd out funding for truly renewable sources of energy like wind and solar and keep coal plants online. With a carbon debt payback period estimated between 44 and 104 years, both Japan and South Korea are continuing to invest in an energy which is not carbon neutral when burning woody biomass. While South Korea has a 2050 coal phaseout date and Japan has yet to commit to a date, utilizing biomass co-firing could serve to lengthen the tail of coal burning in the countries. Sophia Bauer, Project Manager for the Global Bioenergy Power Tracker, said, “The bioenergy buildout is a massive distraction from funding for real solutions to drive a clean energy transition in Japan and South Korea. Not only does burning biomass not bring the intended emissions reductions, it is also a safety hazard for communities and workers, as the threat of fires at power plants is all too well known.” Contact Sophia Bauer, Project Manager, Global Bioenergy Power Tracker, Global Energy Monitor  Email: [email protected] About the Global Bioenergy Power Tracker The Global Bioenergy Power Tracker (GBPT) is a worldwide dataset of utility-scale bioenergy power facilities. It includes bioenergy units with capacities of 30 megawatts (MW) or more. The tracker provides separate data on each of the multiple facilities that typically exist at a particular location. The tracker includes every bioenergy unit at the 30 MW capacity threshold for operating, announced, pre-construction and in-construction power station units. In some cases, units may combust multiple fuel sources in addition to bioenergy.
powerplant
Sep 24, 2024
Southeast Asian Coal Power Plants Old Enough For Coal To Clean Transition
Global Energy Monitor
Southeast Asian Coal Power Plants Old Enough For Coal To Clean TransitionNew analysis reveals the average age of Southeast Asian coal power plants will be 28 years by 2040, making coal to clean transition feasible The average age of a coal power plant in the Association of Southeast Asian Nations (ASEAN) will be 28 years by 2040, according to a new analysis by Global Energy Monitor (GEM), meaning it can be profitably retired under the right policy conditions before the year in which developing countries should phase out coal.  The analysis challenges previously held assumptions that coal power fleets in ASEAN countries are too young to be retired, with this age near the current global average retirement age of 36. The findings of the report highlight ASEAN members’ ability to transition away from coal power generation by 2040, as recommended by the International Energy Agency as well as Intergovernmental Panel on Climate Change modelling to keep global warming below 1.5°C.  “Those calling for repowering or retrofitting existing coal power plants to co-fire with biomass or ammonia have no justification to do so, as the ‘young Southeast Asian coal fleet’ will soon be a fiction. Despite arguments to the contrary, ASEAN coal plants will be old enough to be retired by 2040,” said Christine Shearer, Project Manager of GEM’s Global Coal Plant Tracker. “Energy transition from coal to clean is a complex process, but our analysis shows that the age of Southeast Asian coal plants as a barrier is simply a misconception.” GEM’s analysis challenges conclusions made by the ASEAN Center for Energy and World Bank implying that southeast Asian coal power plants are too young to retire and therefore must be repurposed by retrofitting carbon capture and storage (CCS) technology or by repowering them to run on biomass or ammonia. “ASEAN countries should stop building new coal power plants and avoid further investment in repowering existing coal power plants. Any further developments either increasing coal capacity or expanding the life of existing coal power plants will only make energy transition more difficult,” added Lucy Hummer, a Researcher at Global Energy Monitor. ASEAN countries have about 15 gigawatts (GW) of new coal power capacity in pre-construction phases and another 15 GW under construction. It is essential for ASEAN countries to cancel new coal power plant projects on an urgent basis in order to stop exasperating an already challenging situation. If ASEAN countries stop expanding coal capacity, less than 20 GW of its coal power capacity will be under 20 years of age by 2040. Under the right policy conditions, these plants could meet the criteria for a profitable transition to renewable energy. Older coal power plants are usually cheaper to retire since they would have recouped investment costs. However, a recent IEEFA analysis authored by Paul Jacobson highlights coal power plants as young as 15 years in age could be profitably retired as early as 2030-2035, under the right policy and financing framework. The report indicates that there could be as many as 800 coal-fired units with the right conditions to make this switch, many of which are in Southeast Asia. “My report provides evidence that coal power plants 15 years in age or older could be profitably retired as early as 2030-2035, under the right policy and financing framework. This requires effort to be put into developing and structuring such a phase out with agreements that replace private coal PPAs with new renewable energy PPAs. Analysis indicates that the costs of such a transition (including coal phaseout, new renewables construction, storage capacity construction, and grid upgrades) would NOT increase wholesale power prices, should policy and other conditions be suitable,” said Paul Jacobson, author of the IEEFA report.   Age of coal plants in the ASEAN region by 2040
powerplant
Aug 28, 2024