dunch
Старожил
Ну, на самом деле, китайцы ещё есть. Да и американцы вроде не так давно сдавали реакторы в Китае. Так что было бы желание. Ну и да, лет 10 все равно надо
Электроавтомобили - новости, обсуждение, перспективы
nowhow
Старожил
и что там до европы доходит через турцию? крохи...
Pax
Старожил
Вот и RR подтянулся.
Black Semargl
Старожил
Так они ведь оттого что поверхность опускается, заполняя образовавшуюся пустоту.
А у Нидерландов и так над уровнем моря немного
Sergey-nn
циник в розовых очках
40% и 50% - не шибко принципиальная разница, особенно в контексте обсуждения стоимости топлива для авто.
Touring
Старожил
Структуры Росатома сдали в эксплуатацию всего пять реакторов по новому проекту АЭС-2006, с 2017 по 2021-й, и в среднем именно по 10 лет ушло на каждый. Вне экс-СССР пока не сдали по этому проекту как я понимаю ни одного, строят, и сроки по ним видны будут только в будущем. Если бывает резерв для станции нужно создавать и сети изменять, это тоже занимает добавочное время. Ну и мнение военных, в Западную Европу Росатом и так бы из-за него не прошёл, а теперь гарантированно не пройдёт. Как и китайские компании. Ещё, финансирование, кто подпишется на эти новые станции найти десятки миллиардов денег, частный инвестор или как и в 70-80-х будут атомные госпрограммы из налогов, вопрос. Скорее последнее. В общем заявить на уровне текущей администрации можно многое, в Польше тоже подобное заявили недавно, но потом придёт другая, и может всё резко поменяться.
Ariec 71
Ariec 71
Бывает. Вопрос цены, и не всем экономикам она будет по силам.
Touring
Старожил
Вопрос адекватной цены газа в Европе это вопрос времени.
Как только построят достаточно добычи и сжижения в США и Катаре для замещения сибирского трубного газа, ушедшего из Европы, а это лет пять, то цена поставок туда скорее всего станет плюс-минус $10/MMBtu ($370/tcm), по которым японская энергетика покупала LNG в последние годы в среднем. Под японский спрос и спрос в Китае по таким ценам активно вводились новые LNG проекты, типа новых австралийских.
У австралийцев такой прогноз.
Main Exporters
US
The US is forecast to export 75 Mt of LNG in 2022, with the fall in LNG production from Freeport LNG partially offset by new facilities at Calcasieu and Sabine Pass. The two facilities are expected to add 12 Mt to the United States’ nominal liquefaction capacity over the outlook period. This will help lift US LNG production to 92 Mt in 2023.
Meanwhile, two more facilities under construction (Golden Pass and Plaquemine’s LNG phase one) are expected to boost US LNG capacity to 114 Mt per annum (Mtpa) by the end of 2024. However, it will likely take an additional year for the facilities to ramp up to full capacity.
Several proposed US LNG projects could fundamentally alter the global LNG market beyond the outlook period. According to the US Energy Information Agency (EIA), there are now 14 proposed LNG facilities (pre-FID) that have a combined liquefaction capacity of over 172 Mtpa. If successful, these facilities could almost triple the US’s current LNG export capacity of 82 Mtpa.
Qatar
Qatar is projected to expand its LNG export capacity in the coming years. However, this is not expected to meaningfully increase export volumes in the outlook period. The expansion will be facilitated by its North Field South project — which reached FID in late 2021. The LNG project will be the second largest in the world by capacity and is expected to start commercial production in 2025. Qatar’s LNG export capacity is expected to rise to around 107 Mtpa by 2026.
Australia
Around 80-90% of Australian LNG exports are sold under long-term contracts that link the price of LNG to the Japanese Customs Crude (JCC) oil price (with a three to six-month lag, depending on contractual arrangements). Australia’s LNG export volumes are forecast to ease and stabilise at around 81 million tonnes (Mt) through to 2024, after reaching 83 Mt in 2021–22. Woodside made a FID on the $16.5 billion Scarborough and Pluto Train 2 project in late November 2021.
Russia
If the current flows are sustained for a year, Europe could lose roughly 78 Mt of LNG-equivalent gas. Crucially, Russia lacks the infrastructure needed to re-divert this gas to countries outside of Europe, and the global LNG trade is only expected to grow by 41 Mt between 2022 and 2024. As a result, global gas markets are expected to be tight for the duration of the outlook period, with large-scale demand destruction inevitable if current conditions endure.
The total LNG trade in 2021 was estimated at 517 bcm. Given enough time, the gas curtailed by Russia could amount to 21% of the annual LNG trade. The unambiguous effect of such a disruption will be to raise the value of uncontracted LNG until new US and Qatari supply comes online beyond the outlook period.
Main Importers
Europe
Roughly 32% (188 bcm) of Europe’s gas is consumed to generate electricity, and 26% (151 bcm) is consumed by the residential sector for space heating. After the power and residential sectors, the third largest consumer is the Industrial sector, with roughly a 20% (118 bcm) share of consumption. In the event of a shortfall, EU regulations clearly state that households and gas-powered generators are to be given priority over other gas consumers. Industrial users are encouraged to reduce their consumption by taking demand-side measures to restore market balance.
The composition of European gas users will make it difficult for the EU to curtail its ex-industrial gas demand because half of Europe’s gas is consumed in sectors where demand is highly price inelastic. As a result, European LNG imports are forecast to rise 43% year-on-year, reaching 111 Mt in 2022. Imports are expected to peak at 126 and 128 Mt in 2023 and 2024, respectively, as infrastructure bottlenecks begin to limit the continent’s ability to absorb additional LNG imports.
Asia
Almost 70% of the LNG traded in Asia is sold via long-term contracts that link the price of the LNG to the price of oil (commonly the Japanese Customs-cleared Crude price), typically with a lag of around three to six months — depending on contractual arrangements.
China
Much depends on whether Chinese LNG buyers become more price sensitive than buyers from other parts of Asia. China only obtains 25% of its gas from LNG imports. Most of China's gas supply is produced domestically (57%), and a sizable quantity is imported via pipelines from Russia and Central Asia (15%). Gas consumption in China is similarly diversified, with the electricity and industrial sectors each accounting for roughly 24% of China's gas demand. The residential sector makes up roughly 20% of gas consumption, with the remaining consumption occurring in the transport and commercial sectors.
The diversity of China’s gas consumers and gas supply sources could increase the price elasticity of Chinese LNG demand at such extreme prices. For example, China's industrial users may become more price sensitive due to their exposure to international competition, while the availability of alternative gas supply could also make industrial users reluctant to purchase uncontracted LNG cargoes. As a result, there is a possibility that Chinese demand for LNG will remain muted even as the nation emerges from lockdowns.
Over the long-term, persistently high LNG prices will erode the competitiveness of LNG relative to other natural gas sources — be it domestically produced or pipeline imports. As a result, Chinese LNG demand is forecast to fall by 19% to 67 Mt in 2022, with imports only modestly recovering to 79 Mt by 2024.
Japan
Unlike China, Japan obtains virtually all of its gas via LNG imports, and its gas consumption is heavily concentrated in the power generation sector, which accounts for roughly 70% of Japanese gas demand. As a result, Japanese LNG imports are much more sensitive to weather-related changes in electricity demand and the competitiveness of gas relative to other types of power generators. LNG imports are expected to fall to about 70 Mt in 2024 as the electricity sector shifts away from gas. According to METI, Japan plans to reduce gas’ share of electricity generation from 38% in 2022 to 27% by 2030, while nuclear’s share rises from 6% to 22% over the same period.
Korea
Korea sources all of its gas from LNG imports, over half (55%) of which is consumed in the power sector to generate electricity. Of the remainder, 16% is used by the industrial sector (typically as a chemical feedstock or as a source of industrial heat), and 26% is used in the commercial and residential sectors. To reduce the call on gas, the South Korean government suspended voluntary emission restrictions on coal-fired power generators. However, LNG demand has remained in line with seasonal trends, due to persistently higher demand for electricity during the summer season. High gas prices and the construction of new nuclear facilities will restrain growth in South Korean LNG imports. As a result, LNG imports are estimated to fall slightly to 41 Mt by 2024.
India
Indian LNG imports are forecast to fall from 24 Mt in 2021 to 22 Mt by 2024, as high prices weigh on demand.
Taiwan
Taiwanese LNG imports are expected to stabilise at around 20 Mt per annum over the outlook period.
Как только построят достаточно добычи и сжижения в США и Катаре для замещения сибирского трубного газа, ушедшего из Европы, а это лет пять, то цена поставок туда скорее всего станет плюс-минус $10/MMBtu ($370/tcm), по которым японская энергетика покупала LNG в последние годы в среднем. Под японский спрос и спрос в Китае по таким ценам активно вводились новые LNG проекты, типа новых австралийских.
У австралийцев такой прогноз.
Main Exporters
US
The US is forecast to export 75 Mt of LNG in 2022, with the fall in LNG production from Freeport LNG partially offset by new facilities at Calcasieu and Sabine Pass. The two facilities are expected to add 12 Mt to the United States’ nominal liquefaction capacity over the outlook period. This will help lift US LNG production to 92 Mt in 2023.
Meanwhile, two more facilities under construction (Golden Pass and Plaquemine’s LNG phase one) are expected to boost US LNG capacity to 114 Mt per annum (Mtpa) by the end of 2024. However, it will likely take an additional year for the facilities to ramp up to full capacity.
Several proposed US LNG projects could fundamentally alter the global LNG market beyond the outlook period. According to the US Energy Information Agency (EIA), there are now 14 proposed LNG facilities (pre-FID) that have a combined liquefaction capacity of over 172 Mtpa. If successful, these facilities could almost triple the US’s current LNG export capacity of 82 Mtpa.
Qatar
Qatar is projected to expand its LNG export capacity in the coming years. However, this is not expected to meaningfully increase export volumes in the outlook period. The expansion will be facilitated by its North Field South project — which reached FID in late 2021. The LNG project will be the second largest in the world by capacity and is expected to start commercial production in 2025. Qatar’s LNG export capacity is expected to rise to around 107 Mtpa by 2026.
Australia
Around 80-90% of Australian LNG exports are sold under long-term contracts that link the price of LNG to the Japanese Customs Crude (JCC) oil price (with a three to six-month lag, depending on contractual arrangements). Australia’s LNG export volumes are forecast to ease and stabilise at around 81 million tonnes (Mt) through to 2024, after reaching 83 Mt in 2021–22. Woodside made a FID on the $16.5 billion Scarborough and Pluto Train 2 project in late November 2021.
Russia
If the current flows are sustained for a year, Europe could lose roughly 78 Mt of LNG-equivalent gas. Crucially, Russia lacks the infrastructure needed to re-divert this gas to countries outside of Europe, and the global LNG trade is only expected to grow by 41 Mt between 2022 and 2024. As a result, global gas markets are expected to be tight for the duration of the outlook period, with large-scale demand destruction inevitable if current conditions endure.
The total LNG trade in 2021 was estimated at 517 bcm. Given enough time, the gas curtailed by Russia could amount to 21% of the annual LNG trade. The unambiguous effect of such a disruption will be to raise the value of uncontracted LNG until new US and Qatari supply comes online beyond the outlook period.
Main Importers
Europe
Roughly 32% (188 bcm) of Europe’s gas is consumed to generate electricity, and 26% (151 bcm) is consumed by the residential sector for space heating. After the power and residential sectors, the third largest consumer is the Industrial sector, with roughly a 20% (118 bcm) share of consumption. In the event of a shortfall, EU regulations clearly state that households and gas-powered generators are to be given priority over other gas consumers. Industrial users are encouraged to reduce their consumption by taking demand-side measures to restore market balance.
The composition of European gas users will make it difficult for the EU to curtail its ex-industrial gas demand because half of Europe’s gas is consumed in sectors where demand is highly price inelastic. As a result, European LNG imports are forecast to rise 43% year-on-year, reaching 111 Mt in 2022. Imports are expected to peak at 126 and 128 Mt in 2023 and 2024, respectively, as infrastructure bottlenecks begin to limit the continent’s ability to absorb additional LNG imports.
Asia
Almost 70% of the LNG traded in Asia is sold via long-term contracts that link the price of the LNG to the price of oil (commonly the Japanese Customs-cleared Crude price), typically with a lag of around three to six months — depending on contractual arrangements.
China
Much depends on whether Chinese LNG buyers become more price sensitive than buyers from other parts of Asia. China only obtains 25% of its gas from LNG imports. Most of China's gas supply is produced domestically (57%), and a sizable quantity is imported via pipelines from Russia and Central Asia (15%). Gas consumption in China is similarly diversified, with the electricity and industrial sectors each accounting for roughly 24% of China's gas demand. The residential sector makes up roughly 20% of gas consumption, with the remaining consumption occurring in the transport and commercial sectors.
The diversity of China’s gas consumers and gas supply sources could increase the price elasticity of Chinese LNG demand at such extreme prices. For example, China's industrial users may become more price sensitive due to their exposure to international competition, while the availability of alternative gas supply could also make industrial users reluctant to purchase uncontracted LNG cargoes. As a result, there is a possibility that Chinese demand for LNG will remain muted even as the nation emerges from lockdowns.
Over the long-term, persistently high LNG prices will erode the competitiveness of LNG relative to other natural gas sources — be it domestically produced or pipeline imports. As a result, Chinese LNG demand is forecast to fall by 19% to 67 Mt in 2022, with imports only modestly recovering to 79 Mt by 2024.
Japan
Unlike China, Japan obtains virtually all of its gas via LNG imports, and its gas consumption is heavily concentrated in the power generation sector, which accounts for roughly 70% of Japanese gas demand. As a result, Japanese LNG imports are much more sensitive to weather-related changes in electricity demand and the competitiveness of gas relative to other types of power generators. LNG imports are expected to fall to about 70 Mt in 2024 as the electricity sector shifts away from gas. According to METI, Japan plans to reduce gas’ share of electricity generation from 38% in 2022 to 27% by 2030, while nuclear’s share rises from 6% to 22% over the same period.
Korea
Korea sources all of its gas from LNG imports, over half (55%) of which is consumed in the power sector to generate electricity. Of the remainder, 16% is used by the industrial sector (typically as a chemical feedstock or as a source of industrial heat), and 26% is used in the commercial and residential sectors. To reduce the call on gas, the South Korean government suspended voluntary emission restrictions on coal-fired power generators. However, LNG demand has remained in line with seasonal trends, due to persistently higher demand for electricity during the summer season. High gas prices and the construction of new nuclear facilities will restrain growth in South Korean LNG imports. As a result, LNG imports are estimated to fall slightly to 41 Mt by 2024.
India
Indian LNG imports are forecast to fall from 24 Mt in 2021 to 22 Mt by 2024, as high prices weigh on demand.
Taiwan
Taiwanese LNG imports are expected to stabilise at around 20 Mt per annum over the outlook period.
nowhow
Старожил
не вся промышленность доживет до таких щадящих цен.
constructor
Старожил
Постоянно что-то умирает в промышленности, а что-то рождается. Не из-за газа, так по другим причинам.
Sergey-nn
циник в розовых очках
Когда причин "умирания" становится больше чем причин роста "смертность" превышает "рождаемость" и происходит спад экономики.
Можно делать вид что ничего страшного, но это вовсе не так.
Оно не несет ничего хорошего ни для ЕС ни для РФ
По сути сейчас происходит серьёзный развал экономики "обобщенной Европы" (включая Россию, Украину, а так же страны Кавказа и Закавказья) с переносом экономических центров в Азию и США.
Не могу сказать что это радостная перспектива.
brab
Старожил
Давайте вернемся к тому что вы говорили изначально:
>Российский газ емнип более половины газа потребляемого ес. К тому же норвеги заявили о планах свернуть поставки в другие страны. Так что почитай кончился.
Т.е. 40% а не "более половины" - это раз. Про норвегов пруфа как не было так и нет. Итого - про "почитай что кончился" вы ерунду написали
Touring
Старожил
Пока, из того что я слышал, евро-производители удобрений при цене спот-газа сильно выше $1,000/tcm закрылись, сейчас с её приближением к этой границе потихоньку открываются снова. Чистая промка типа авто и их подрядчиков и поставщиков, сидит на газе, она может эти цены компенсировать, заряжают в цену компонент и авто издержки. Так как могут.
Теплогенерация которая могла, перешла на уголь местный и привозной по максимуму, это дешевле. Электрогенерация которая могла перешла также на уголь. Когенерация в Скандинавии и Балтии, где есть отходы деревообработки, снова-таки сидит на них, это тоже дешевле газа сейчас. Когенерация газовая в Балтии, которая ещё не переползла на щепу и мусор, перескакивает даже на мазут, это тоже дешевле газа сейчас. Короче удар по популярности газа от таких цен очень сильный.
Бизнес и граждане, те у кого поставлены газовые котлы, потребляют на отопление и горячее водоснабжение дорогой газ, у них выбора мало. Они тоже задумались об альтернативе, у частников в одноквартирном это тепловой насос, а у бизнеса и нет особой.
Что по ценам, в Японии газ в виде LNG сейчас примерно в два раза дороже обычного, в среднем на уровне $70/МВт-ч, спотовый небольшими партиями до $100/МВт-ч, вместо $20-35/МВт-ч в 2015-2020, однако в 2011-2014 у них были похожие цены, вокруг $50/МВт-ч, и если учесть инфляцию доллара за 10 лет, то и не сильный рост, с начала 10-х. Поэтому они особо и не стонут, ни Тойота ни Хонда, ни прочие. В остальной Азии ценовая ситуация похожая, в том числе в Китае.
В Европе газ сейчас стоит порядка $70-100/МВт-ч, поставщики туда ориентируются на цены LNG в Азии, так как Европа конкурирует за него, и это раза в 2-3 дороже чем в 2011-2013, когда в Европе было порядка $30-35/МВт-ч, и раз в 4-5 дороже чем в 2015-2020, когда там было $15-25/МВт-ч. Поэтому для европейцев это изменение конечно чувствуется. Но ничего, японское производство и экспорт рентабельны при таких ценах, научатся и европейцы.
В Штатах газ сейчас порядка $20-25/МВт-ч, дешевле чем в 2008-2009, когда там было порядка $30/МВт-ч, но при этом он раза в два дороже чем в 2015-2020, с их $8-10/МВт-ч. Опять же, если брать инфляцию доллара за 10 лет, $30/МВт-ч в конце 00-х, то нынешние $20/МВт-ч это дёшево. Американские компании и тогда работали в мире конкурентно при тех ценах энергии, тем более сейчас. Американская экономика сильная, с большой долей интеллектуальной продукции, тем же Гугл-Эппл-Майкрософт-Боинг переварить почти любые цены газа, да запросто.
Японцы из JOGMEC приводят такие цифры.
Japan
2019
Japan's average LNG import price of USD 10.13 in August 2019 was higher than USD 8.5 - 9.3 in other LNG markets in Northeast Asia and 2.2 times as high as the assessed spot LNG price in the region (JKM) for delivery in August (assessed between mid-June and mid-July) at USD 4.55. It was the largest gap ever between the two. Japan's average LNG import price in September 2019 was USD 9.62 and in October was USD 9.42. While the METI spot LNG price was USD 4.9 in September 2019 and was USD 5.4 in October 2019.
Assessed spot LNG prices (JKM) in Northeast Asia have been at the lowest level during the past ten years (effectively the lowest ever) at this time of the year since 23 October 2019. Notably on 30 October, the front-month JKM went down to below USD 6 per million Btu for the first time as that for December delivery in the JKM history. JKM for December 2019 delivery, which was on the first day as the new front-month on 16 October several dime higher than that for November delivery, stayed above USD 7 only from 17 to 21 October before its rapid decline. JKM for January 2020 delivery on the first day as the new front-month on 18 November 2019 was also assessed below USD 6. While Japan and China do not expect additional spot cargo demand as they have largely completed procurement for their winter gas demand, the market is expected to have ample LNG supply capacity in the coming winter.
Japan’s average LNG import price, which accounts for 70%-80% of long-term contracts linked to crude oil import price (JCC: Japan Crude Cocktail), is expected to continue to be affected by current crude oil prices.
2022
Based on the preliminary figures from Japan's customs statistics of the Ministry of Finance, the country's average LNG import price in August 2022 was USD 19.88 per million Btu. Elsewhere in Asia, average import prices in August were USD 17.00 in China, USD 23.04 in Korea, and USD 24.60 in Chinese Taipei. Japan’s average landed crude oil import price (JCC: Japan Crude Cocktail) was USD 112.41 per barrel in August 2022.
Based on the preliminary figures from Japan's customs statistics of the Ministry of Finance, the country's average LNG import price was USD 22.73 per million Btu in September 2022. Elsewhere in Asia, average import prices in September were USD 17.81 in China, USD 28.26 in Korea, and USD 21.67 in Chinese Taipei. Japan’s average landed crude oil import price (JCC: Japan crude cocktail) was USD 110.79 per barrel in September 2022.
The assessed spot LNG price for near-month delivery to Northeast Asia, JKM declined to USD 36 per million Btu on 3 October amid stagnant activity in the Northeast Asian market, but on 6 October, JKM rose to USD 33 from USD 29 the previous day after Malaysia LNG declared a force majeure due to a pipeline leak, raising supply concerns. The following week, activity in the Northeast Asian market remained stagnant, hovering around the late USD 20s to USD 30 range. The week of 17 October showed similar price movements, although the price reached USD 33 on 21 October due to a temporary increase in buying interest. JKM generally hovered at USD 30 for the week of 24 October. JKM then remained flat at USD 30/MBtu until 28 October.
Japan, China, and Korea appear to have generally completed stocking up on LNG inventories for the winter season. Sporadic commercial activity was seen in the market, but buying interest was generally low.
Europe
2019
Meanwhile the NBP price in the United Kingdom during October 2019 went up only slightly to USD 5.53 equivalent at the end of the month, still around half of the price one year earlier, reflecting continuous inflow of LNG and unseasonably high inventory in natural gas storage.
2022
The Dutch TTF Gas Futures price was in the upper USD 40s to 50s range for the week of 3 October, but gradually began to decline the following week from USD 45.2 on 10 October to USD 41.6 on 14 October as European natural gas underground storage exceeded 90% and LNG supply became in excess. The following week, the situation remained the same, with TTF falling further in value, from USD 36.5 on 17 October to USD 32.4 on 21 October. During the week, the European Commission presented a proposal for emergency measures, including joint gas procurement and a price cap on the TTF. TTF showed a further downward trend during the week of 24 October, hovering in the late USD 20s to USD 30 range. TTF began to show a downward trend, as European natural gas underground storage has started to exceed 90%, and also due to the oversupply of LNG.
During the week of 24 October 2022 the discount of the UK gas price NBP to the TTF is USD 7s to 8s, down from the recent trend, falling further in value to USD 22.
US
2019
While the Henry Hub price in the United States went up by USD 0.3 in October 2019 to USD 2.63 at the end of the month, it was still almost 20% lower than that of the same time one year earlier responding to the sustaining growth of natural gas production in the country.
2022
The Henry Hub Natural Gas Futures price rose after reaching USD 6.5 on 3 October and reached USD 7.0 on 6 October. The following week, HH remained at the USD 6s level, but in the following two weeks, it turned down on the back of weaker demand due to a warmer climate outlook and a bullish production outlook, falling from USD 6.0 on 17 October to USD 5.0 on 21 October. The price remained at the USD 5s level for the week of 24 October.
Последнее редактирование:
Sergey-nn
циник в розовых очках
Сильно!
Это вы про электрогенерацию на базе парового котла с КПД около 30% под которым еще угольная топка сохранилась?
Небось вся Европа только так "лепестричество" и получала
Газовая электростанция представляет собой две "ступени" генерации
первая - газовая турбина имеющая КПД около 35%.
Вторая - паровая турбина, работающая за счет остатков тепла газовой турбины, и дающая еще 30% КПД. Вот там да, есть "паровой котел". Только уголь под ним жечь невозможно.
Touring
Старожил
В Германии угольные имеют КПД от 30 до 47%. Те которые 30-32% это очень старые, они или стоят в резерве, или выведены. Работающие станции с КПД порядка 36% и обычными параметрами, ввод до 90-х, модернизация в 90-х с повышением КПД, тогда же обновление систем фильтрации. Часть парка новые, с КПД в вилке 41-47% и суперкритическими параметрами, это ввод конец 90-х и позднее, список ниже. Доминирующая часть работает на местном буром угле, это выгодно, стоят непосредственно в регионах с такой добычей.
1. Современное, местный бурый уголь:
1995
Saxony-Anhalt
Schkopau 2x480=960 MWh(e) = 40%
1998
Brandenburg
Schwarze Pumpe 2x800=1600 MWh(e) = 41%
2000
Saxony-Anhalt
Boxberg-IV 907 MWh(e) = 42%
2000
Saxony-Anhalt
Lippendorf 2x933=1866 MWh(e) = 43%
2002
North Rhine-Westphalia
Niederaussem-K 1000 MWh(e) = 43%
2012
North Rhine-Westphalia
Neurath-F/G 2x1100=2200 MWh(e) = 43%
2012
Saxony-Anhalt
Boxberg-R 675 MWh(e) = 44%
2. Современное, привозной энергетический уголь:
2014
Baden-Wurttemberg
Rheinhafen-8 912 MWh(e) = 47%
2020
North Rhine-Westphalia
Datteln-4 1052 MWh(e) = 45%
1. Современное, местный бурый уголь:
1995
Saxony-Anhalt
Schkopau 2x480=960 MWh(e) = 40%
1998
Brandenburg
Schwarze Pumpe 2x800=1600 MWh(e) = 41%
2000
Saxony-Anhalt
Boxberg-IV 907 MWh(e) = 42%
2000
Saxony-Anhalt
Lippendorf 2x933=1866 MWh(e) = 43%
2002
North Rhine-Westphalia
Niederaussem-K 1000 MWh(e) = 43%
2012
North Rhine-Westphalia
Neurath-F/G 2x1100=2200 MWh(e) = 43%
2012
Saxony-Anhalt
Boxberg-R 675 MWh(e) = 44%
2. Современное, привозной энергетический уголь:
2014
Baden-Wurttemberg
Rheinhafen-8 912 MWh(e) = 47%
2020
North Rhine-Westphalia
Datteln-4 1052 MWh(e) = 45%
Последнее редактирование:
Touring
Старожил
Модернизация старых газовых станций в части эффективности и фильтрации в 90-х годах.
Эффект от внедрения фильтрации.
Развитие технологий, рост КПД.
Эффект от внедрения фильтрации.
Развитие технологий, рост КПД.
Последнее редактирование:
Touring
Старожил
Немецкая электрогенерация в 2021-м:
113 TWh локальный ветер,
99 TWh локальный бурый уголь,
86 TWh привозной газ,
65 TWh атом на привозном топливе,
46 TWh привозной энергетический уголь,
48 TWh локальное солнце,
43 TWh локальная биомасса,
19 TWh локальная вода.
--------------
519 TWh всего, из них 322 локальные, или 62%, цель у них довести локальные до 100%.
Актуальный немецкий микс электрогенерации. Количество установленной там газовой и угольной генерации таково что позволяет переключаться в зависимости от цен этих двух энергоресурсов. Доля газовой как видно мала, но она в нынешнем миксе есть, несмотря на цены газа, поскольку такая генерация в простом цикле наиболее удобна по скорости "подъёма".
113 TWh локальный ветер,
99 TWh локальный бурый уголь,
86 TWh привозной газ,
65 TWh атом на привозном топливе,
46 TWh привозной энергетический уголь,
48 TWh локальное солнце,
43 TWh локальная биомасса,
19 TWh локальная вода.
--------------
519 TWh всего, из них 322 локальные, или 62%, цель у них довести локальные до 100%.
Актуальный немецкий микс электрогенерации. Количество установленной там газовой и угольной генерации таково что позволяет переключаться в зависимости от цен этих двух энергоресурсов. Доля газовой как видно мала, но она в нынешнем миксе есть, несмотря на цены газа, поскольку такая генерация в простом цикле наиболее удобна по скорости "подъёма".
Последнее редактирование: