Sekarang Jauhi Selfie Dengan Dua Jari /peace Ternyata Berbahaya Begini Penjelasannya

Regional natural gas infrastructure issues in Southern California could affect electricity reliability this summer, according to separate studies recently released by the Southern California Gas Company (SoCalGas) and the Aliso Canyon Technical Assessment Group. Depending on natural gas infrastructure changes and storage operations this summer, these issues could also have implications for the upcoming winter. The Aliso Canyon Technical Assessment Group, which includes the California Public Utility Commission, the California Energy Commission, the California Independent System Operator, and the Los Angeles Department of Water and Power, concluded that base case total system deliverability capacity—a combination of the natural gas pipeline system and the deliverability capacity of non-Aliso storage working gas—is slightly lower than 3.6 billion cubic feet per day (Bcf/d) this summer, or 0.2 Bcf/d lower than last summer when pipeline outages curtailed deliverability. If daily natural gas demand exceeds 3.6 Bcf/d—which is relatively common in winter months but has occurred only once in the past five summers—some natural gas deliveries to electric generators may need to be curtailed. Since October 2017, SoCalGas has experienced a series of planned and unplanned natural gas pipeline outages that have reduced the ability to bring natural gas into Southern California. According to the May 7, 2018 SoCalGas maintenance schedule, pipeline repairs are not expected to be completed until the end of summer, with key pipelines—Lines 4000, 235-2, and 2000—showing no scheduled completion date. Pipeline capacity for summer 2018 is about 0.53 Bcf/d lower than at this time last summer, but storage deliverability is about 0.4 Bcf/d higher. Natural gas inventories in Southern California are typically refilled over the summer months. However, electricity demand is higher in the summer months, and natural gas is a key fuel source for electric power generation in Southern California. According to SoCalGas, the current outages will create challenges this summer for meeting customer demand while also refilling storage inventories. The timing and extent of refilling natural gas at SoCalGas’ storage fields have changed since a leak at the Aliso Canyon storage complex was discovered in October 2015. Aliso Canyon, previously the second-largest natural gas storage facility in the United States, had its capacity reduced from 86 billion cubic feet (Bcf) to about 25 Bcf as a result of the leak. The total capacity of the four storage facilities in the SoCalGas service territory declined from 136 Bcf to 74 Bcf. Working gas inventories as of June 6, 2018, totaled 58.2 Bcf, which is low by historical standards, but 11 Bcf higher than at this time in 2017 and 4.1 Bcf lower than at this time in 2016. The Assessment Group’s report issued a series of recommendations to help Southern California address reliability challenges, including: Importing liquefied natural gas (LNG) through the Otay Mesa receipt point at the San Diego-Mexico border Coordinating with natural gas customers to ensure they are prepared to respond to high and low operational flow orders to maintain system balance Expediting any pending electricity transmission upgrades Taking advantage of demand response pilot projects Exploring an increase in the maximum target inventory—or storage capacity—at Aliso Canyon EIA provides a daily summary of key energy conditions in Southern California on the Southern California Daily Energy Report. In addition to the daily summary, EIA provides occasional commentary and analysis on notable market conditions in Southern California.

Since October 2017, SoCalGas has experienced a series of planned and unplanned natural gas pipeline outages that have reduced the ability to bring natural gas into Southern California. According to the May 7, 2018 SoCalGas maintenance schedule, pipeline repairs are not expected to be completed until the end of summer, with key pipelines—Lines 4000, 235-2, and 2000—showing no scheduled completion date. Pipeline capacity for summer 2018 is about 0.53 Bcf/d lower than at this time last summer, but storage deliverability is about 0.4 Bcf/d higher. Natural gas inventories in Southern California are typically refilled over the summer months. However, electricity demand is higher in the summer months, and natural gas is a key fuel source for electric power generation in Southern California. According to SoCalGas, the current outages will create challenges this summer for meeting customer demand while also refilling storage inventories. The timing and extent of refilling natural gas at SoCalGas’ storage fields have changed since a leak at the Aliso Canyon storage complex was discovered in October 2015. Aliso Canyon, previously the second-largest natural gas storage facility in the United States, had its capacity reduced from 86 billion cubic feet (Bcf) to about 25 Bcf as a result of the leak. The total capacity of the four storage facilities in the SoCalGas service territory declined from 136 Bcf to 74 Bcf. Working gas inventories as of June 6, 2018, totaled 58.2 Bcf, which is low by historical standards, but 11 Bcf higher than at this time in 2017 and 4.1 Bcf lower than at this time in 2016. Since October 2017, SoCalGas has experienced a series of planned and unplanned natural gas pipeline outages that have reduced the ability to bring natural gas into Southern California. According to the May 7, 2018 SoCalGas maintenance schedule, pipeline repairs are not expected to be completed until the end of summer, with key pipelines—Lines 4000, 235-2, and 2000—showing no scheduled completion date. Pipeline capacity for summer 2018 is about 0.53 Bcf/d lower than at this time last summer, but storage deliverability is about 0.4 Bcf/d higher. Natural gas inventories in Southern California are typically refilled over the summer months. However, electricity demand is higher in the summer months, and natural gas is a key fuel source for electric power generation in Southern California. According to SoCalGas, the current outages will create challenges this summer for meeting customer demand while also refilling storage inventories. The timing and extent of refilling natural gas at SoCalGas’ storage fields have changed since a leak at the Aliso Canyon storage complex was discovered in October 2015. Aliso Canyon, previously the second-largest natural gas storage facility in the United States, had its capacity reduced from 86 billion cubic feet (Bcf) to about 25 Bcf as a result of the leak. The total capacity of the four storage facilities in the SoCalGas service territory declined from 136 Bcf to 74 Bcf. Working gas inventories as of June 6, 2018, totaled 58.2 Bcf, which is low by historical standards, but 11 Bcf higher than at this time in 2017 and 4.1 Bcf lower than at this time in 2016. The Assessment Group’s report issued a series of recommendations to help Southern California address reliability challenges, including: Importing liquefied natural gas (LNG) through the Otay Mesa receipt point at the San Diego-Mexico border Coordinating with natural gas customers to ensure they are prepared to respond to high and low operational flow orders to maintain system balance Expediting any pending electricity transmission upgrades Taking advantage of demand response pilot projects Exploring an increase in the maximum target inventory—or storage capacity—at Aliso Canyon EIA provides a daily summary of key energy conditions in Southern California on the Southern California Daily Energy Report. In addition to the daily summary, EIA provides occasional commentary and analysis on notable market conditions in Southern California.

Fossil fuel consumption in the electric power sector declined to 22.5 quadrillion British thermal units (quads) in 2017, the lowest level since 1994. The declining trend in fossil fuel consumption by the power sector has been driven by a decrease in the use of coal and petroleum with a slightly offsetting increase in the use of natural gas. Changes in the fuel mix and improvements in electricity generating technology have also led the power sector to produce electricity while consuming fewer fossil fuels. In 2017, coal consumption by the electric power sector reached its lowest level since 1982, and petroleum consumption in the power sector was the lowest on record, based on data since 1949. Recent natural gas consumption in the power sector has generally been increasing, but 2017 consumption was slightly lower than the record-high 2016 level. In energy-equivalent terms, more coal was consumed in the power sector than natural gas in 2017, at 12.7 quads and 9.5 quads, respectively. However, in terms of electricity generation, natural gas-fired power plants in the electric power sector produced more electricity than coal-fired plants, at 31% and 30% of the U.S. total, respectively, in 2017. Natural gas-fired units tend to be more energy efficient, requiring less energy content to produce a unit of electricity. As recently as 2000, natural gas-fired power plants were on average about as efficient as coal-fired plants. Since then, new natural gas-fired power plants have tended to use combined-cycle generators, which are more efficient because the waste heat from the gas turbine is routed to a nearby steam turbine that generates additional power. Combined-cycle units now make up most of the natural gas-fired electricity generation capacity. By the end of 2018, natural gas combined-cycle units may surpass conventional coal-fired power plants to become the most prevalent technology for generating electricity in the United States. As the natural gas-fired generation fleet has grown and become more efficient, the generation-weighted average efficiency of fossil fuel-fired electricity generation has improved. In 1994, fossil fuel power plants required 10,400 British thermal units (Btu) of primary energy to produce each kilowatthour (kWh); by 2017 that rate had fallen to 9,400 Btu/kWh. These changes in energy consumption and efficiency have also affected carbon dioxide (CO2) emissions from the electric power sector, which in 2017 were the lowest since 1987. Because coal combustion is much more carbon intensive than natural gas combustion, CO2 emissions from coal were more than double those from natural gas in 2017, even though natural gas provided more electricity generation.