Federal hydropower regulators have issued an original license to an Ohio city to construct, operate, and maintain a 50-megawatt hydroelectric project at an existing U.S. Army Corps of Engineers lock and dam site. If developed as licensed, the City of Wadsworth, Ohio's Robert C. Byrd Hydroelectric Project will join other projects focused on adding hydroelectric generation to existing dams.
The Army Corps owns 21 locks and dams on the Ohio River, which it operates for commercial and recreational navigation. These facilities include the RC Byrd Locks and Dam, originally built in the 1930s and renovated within the past 25 years.
On March 28, 2011, the City of Wadsworth, Ohio, applied to the Federal Energy Regulatory Commission for a license to construct, operate, and maintain the Robert C. Byrd Hydroelectric Project No. 12796. As proposed by the city, the project would include new intake and tailrace structures along with a powerhouse holding two turbine generator units with a total installed capacity of 50 megwatts, but not the existing Army Corps dam.
On August 30, 2017, the Federal Energy Regulatory Commission issued its Order Issuing Original License for the RC Byrd Project. The license, which authorizes the installation of 50 MW of new, renewable energy generation capacity, requires a number of measures to protect environmental resources at the project, including measures proposed by the licensee as well as additional terms and conditions developed by Commission staff and other agencies.
According to the licensing order, the project will generate approximately 266,000 megawatt-hours per year, with a levelized annual cost of constructing and operating the project of about $40,586,280, or $152.58/MWh. While the Commission found this to be more expensive than the cost of alternative power in the first year of licensure, the Commission also noted "that hydroelectric projects offer unique operational benefits to the electric utility system." These ancillary service benefits "include the ability to help maintain the stability of a power system, such as by quickly adjusting power output to respond to rapid changes in system load; and to respond rapidly to a major utility system or regional blackout by providing a source of power to help restart the fossil-fuel generating stations and put them back on line."
Consistent with the Commission's general policy regarding license term for projects located on a federal dam, the Commission issued the RC Byrd Project license for a term of 50 years, the maximum allowable under the Federal Power Act.
If developed as licensed, the RC Byrd Project would be part of a trend toward adding hydroelectric generating facilities to existing dams owned by the Army Corps or other dam owners. Congress and the Commission, as well as state agencies, have expressed support for adding hydropower to existing dams and lock structures.
Energy powers society; society's choices shape energy policy. A blog about our energy resources and the choices they present for society.
Showing posts with label Ohio. Show all posts
Showing posts with label Ohio. Show all posts
Coal power plants retiring in 2015
Thursday, May 21, 2015
The U.S. portfolio of electric power plants will continue to shift in 2015, according to a federal assessment projecting that nearly 16 gigawatts (GW) of generating capacity will retire in 2015. Most of the capacity to be retired this year is coal-fired generation. This continues a multi-year trend away from coal, and toward natural gas and renewable resources.
According to the U.S. Energy Information Administration, nearly 16 GW of generating capacity is expected to retire in 2015. Of this, 81% (12.9 GW) is coal-fired generation. Generator retirements are heavily composed of coal-fired generation, split between bituminous coal (10.2 GW) and subbituminous coal (2.8 GW). Most of this retiring coal capacity is found in the Appalachian region, with slightly more than 8 GW combined in Ohio, West Virginia, Kentucky, Virginia, and Indiana.
New environmental regulations and struggles to remain cost-competitive explain most of these retirements. This year, the Environmental Protection Agency's Mercury and Air Toxics Standards (MATS) take effect. MATS requires existing large coal- and oil-fired electric generators to meet stricter emissions standards by retrofitting the units with new emissions control technologies. While some units have been granted extensions to operate through April 2016, some power plant operators are choosing to retire units instead of making cost-prohibitive investments in pollution control.
Most of the coal-fired units slated for retirement are smaller and operate at a lower capacity factor than average coal-fired units in the United States. According to EIA, the to-be-retired units have an average summer nameplate capacity of 158 MW, just 60% as big as the 261 MW average for other coal-fired units. In 2014, the average capacity factor for all coal units was 61%, but the subset of coal units retiring in 2015 had an average capacity factor of just 36%. The relatively small size and low capacity factor of these power plants make it harder for them to compete economically against other generation sources. This competition is especially difficult if sufficient natural gas-fired generating capacity is available, as the cost of natural gas has fallen to levels not seen since 2012.
The coal capacity retiring in 2015 accounted for 1.6% of total U.S. generation during 2014. At the same time, electric generating companies expect to add more than 20 GW of utility-scale generating capacity to the power grid. This new capacity is dominated by wind (9.8 GW), natural gas (6.3 GW), and solar (2.2 GW), which together compose 91% of expected new capacity in 2015.
According to the U.S. Energy Information Administration, nearly 16 GW of generating capacity is expected to retire in 2015. Of this, 81% (12.9 GW) is coal-fired generation. Generator retirements are heavily composed of coal-fired generation, split between bituminous coal (10.2 GW) and subbituminous coal (2.8 GW). Most of this retiring coal capacity is found in the Appalachian region, with slightly more than 8 GW combined in Ohio, West Virginia, Kentucky, Virginia, and Indiana.
New environmental regulations and struggles to remain cost-competitive explain most of these retirements. This year, the Environmental Protection Agency's Mercury and Air Toxics Standards (MATS) take effect. MATS requires existing large coal- and oil-fired electric generators to meet stricter emissions standards by retrofitting the units with new emissions control technologies. While some units have been granted extensions to operate through April 2016, some power plant operators are choosing to retire units instead of making cost-prohibitive investments in pollution control.
Most of the coal-fired units slated for retirement are smaller and operate at a lower capacity factor than average coal-fired units in the United States. According to EIA, the to-be-retired units have an average summer nameplate capacity of 158 MW, just 60% as big as the 261 MW average for other coal-fired units. In 2014, the average capacity factor for all coal units was 61%, but the subset of coal units retiring in 2015 had an average capacity factor of just 36%. The relatively small size and low capacity factor of these power plants make it harder for them to compete economically against other generation sources. This competition is especially difficult if sufficient natural gas-fired generating capacity is available, as the cost of natural gas has fallen to levels not seen since 2012.
The coal capacity retiring in 2015 accounted for 1.6% of total U.S. generation during 2014. At the same time, electric generating companies expect to add more than 20 GW of utility-scale generating capacity to the power grid. This new capacity is dominated by wind (9.8 GW), natural gas (6.3 GW), and solar (2.2 GW), which together compose 91% of expected new capacity in 2015.
Marcellus shale gas drilling slows
Tuesday, July 10, 2012
Natural gas drilling activity has declined in parts of the Marcellus Shale formation under Pennsylvania and other eastern states, largely as a result of low gas prices. These prices in turn are largely the result of significant increases in the available supply of recoverable natural gas made possible by horizontal drilling techniques and hydraulic fracturing or fracking. As a consequence, many natural gas producers are focusing on areas of shale rich in both gas and natural gas liquids.
The Marcellus Shale, a layer of ancient marine sediment rich in organic material and extending beneath Pennsylvania, Ohio, West Virginia, New York, and Maryland, is believed to be one of the world's largest natural gas fields. In 2008, drilling activity in the Marcellus Shale began to increase significantly, as these newer drilling techniques and increases in the price of other fuels like oil made the shale gas economically feasible to recover. (Compare this map of Marcellus shale drilling activity in Pennsylvania from 7/25/2008 to this map of permits issued as of March 9, 2012.) As of this spring, Pennsylvania alone had issued 11,772 permits for vertical and horizontal gas wells in the Marcellus formation.
One result of the expansion of shale gas production is a significant decrease in the price of natural gas. Since 2008, natural gas prices at the Henry Hub in Louisiana (where gas as a commodity is typically priced) have fallen from over $12 per million British thermal units (MMBtu) to as low as $2 per MMBtu. Other factors have played a role in this price decline, such as a mild winter with lower-than-expected heating demand and the overall economic slowdown, but the increase in supply due to shale gas production is viewed as a major cause of the price decline.
Now, one of the effects of the price decline is a decrease in natural gas drilling activity. This decrease is particularly marked in areas where the shale produces "dry gas", or natural gas that is primarily methane and is low in so-called natural gas liquids. Natural gas liquids -- hydrocarbons other than methane that are extracted when natural gas is processed in a natural gas treatment facility -- include ethane, propane, and butanes. These natural gas liquids are important feedstocks for the production of many chemicals and plastics, and add value to the natural gas produced from "wet" shales.
Where shale gas contains significant amounts of natural gas liquids, production appears steady or increasing, while gas producers in areas with lower amounts of natural gas liquids are now saying that they are having a hard time making money off gas alone. If this trend continues, areas of dry gas like much of the known portions of the Marcellus Shale may continue to see a slowdown in drilling activity while producers focus on areas rich in natural gas liquids.
The Marcellus Shale, a layer of ancient marine sediment rich in organic material and extending beneath Pennsylvania, Ohio, West Virginia, New York, and Maryland, is believed to be one of the world's largest natural gas fields. In 2008, drilling activity in the Marcellus Shale began to increase significantly, as these newer drilling techniques and increases in the price of other fuels like oil made the shale gas economically feasible to recover. (Compare this map of Marcellus shale drilling activity in Pennsylvania from 7/25/2008 to this map of permits issued as of March 9, 2012.) As of this spring, Pennsylvania alone had issued 11,772 permits for vertical and horizontal gas wells in the Marcellus formation.
One result of the expansion of shale gas production is a significant decrease in the price of natural gas. Since 2008, natural gas prices at the Henry Hub in Louisiana (where gas as a commodity is typically priced) have fallen from over $12 per million British thermal units (MMBtu) to as low as $2 per MMBtu. Other factors have played a role in this price decline, such as a mild winter with lower-than-expected heating demand and the overall economic slowdown, but the increase in supply due to shale gas production is viewed as a major cause of the price decline.
Now, one of the effects of the price decline is a decrease in natural gas drilling activity. This decrease is particularly marked in areas where the shale produces "dry gas", or natural gas that is primarily methane and is low in so-called natural gas liquids. Natural gas liquids -- hydrocarbons other than methane that are extracted when natural gas is processed in a natural gas treatment facility -- include ethane, propane, and butanes. These natural gas liquids are important feedstocks for the production of many chemicals and plastics, and add value to the natural gas produced from "wet" shales.
Where shale gas contains significant amounts of natural gas liquids, production appears steady or increasing, while gas producers in areas with lower amounts of natural gas liquids are now saying that they are having a hard time making money off gas alone. If this trend continues, areas of dry gas like much of the known portions of the Marcellus Shale may continue to see a slowdown in drilling activity while producers focus on areas rich in natural gas liquids.
January 10, 2011 - Ballville Dam removal; Lake Erie wind
Monday, January 10, 2011
As many dams in America are approaching their centenary years, dam owners face pressures to maintain or upgrade their infrastructure to comply with safety or environmental regulations - or else face dam removal. Located outside Fremont, Ohio, the Ballville Dam now faces this choice.
Constructed in 1911, the Ballville Dam was built on the Sandusky River about a dozen miles upstream from Lake Erie to impound and direct water into a downstream hydroelectric station. The dam is 34.4 feet high and over 300 feet long. In 1946, the downstream hydroelectric facility ceased generation. In 1959, the city of Fremont bought the Ballville dam for water supply. In the ensuing 50 years, issues including upkeep and maintenance costs for the dam led the city to create an alternative reservoir to replace the dam. The dam has been implicated in fish passage problems, and its removal is anticipated to open up over 22 miles of habitat to gamefish like walleye. The dam has also been implicated in problems with ice jams above Fremont. All this, without a revenue stream from the dam, has led Fremont to work towards dam removal. Fremont has since won approximately $6 million dollars in grant funding to support dam removal, which is slated for summer 2011.
If the dam is removed, large amounts of backed up sediment - including a contaminant burden of heavy metals and polyaromatic hydrocarbons - will either come with it or be swept downstream into Lake Erie. A report suggests 350,000 cubic meters of sediment may need to be removed to establish the channel of the Sandusky River through the impoundment. However, the report suggests that the sediment pollutant concentrations are less than or equal to those in existing Lake Erie sediment, and thus that mixing with the lake would dilute any effects.
Interestingly, the Ballville Dam has faced trouble before. Two years after its construction, the dam failed due to poor anchoring into the sediment, causing serious flooding in Fremont. Today's dam was rebuilt using a stronger foundation. In 1913, the dam served a useful purpose: supporting the nearby hydroelectric station. In 2011, without that support for hydroelectric generation, will the Ballville Dam be removed?
Meanwhile, on Lake Erie, the Lake Erie Energy Development Corporation continues to make progress toward the nation's first inland offshore wind development: five wind turbines in state waters about 7 miles off Cleveland. Great Lakes wind offers many of the advantages of both terrestrial and oceanic wind, while posing other challenges. Will the Lake Erie project be the first to reach success?
Constructed in 1911, the Ballville Dam was built on the Sandusky River about a dozen miles upstream from Lake Erie to impound and direct water into a downstream hydroelectric station. The dam is 34.4 feet high and over 300 feet long. In 1946, the downstream hydroelectric facility ceased generation. In 1959, the city of Fremont bought the Ballville dam for water supply. In the ensuing 50 years, issues including upkeep and maintenance costs for the dam led the city to create an alternative reservoir to replace the dam. The dam has been implicated in fish passage problems, and its removal is anticipated to open up over 22 miles of habitat to gamefish like walleye. The dam has also been implicated in problems with ice jams above Fremont. All this, without a revenue stream from the dam, has led Fremont to work towards dam removal. Fremont has since won approximately $6 million dollars in grant funding to support dam removal, which is slated for summer 2011.
If the dam is removed, large amounts of backed up sediment - including a contaminant burden of heavy metals and polyaromatic hydrocarbons - will either come with it or be swept downstream into Lake Erie. A report suggests 350,000 cubic meters of sediment may need to be removed to establish the channel of the Sandusky River through the impoundment. However, the report suggests that the sediment pollutant concentrations are less than or equal to those in existing Lake Erie sediment, and thus that mixing with the lake would dilute any effects.
Interestingly, the Ballville Dam has faced trouble before. Two years after its construction, the dam failed due to poor anchoring into the sediment, causing serious flooding in Fremont. Today's dam was rebuilt using a stronger foundation. In 1913, the dam served a useful purpose: supporting the nearby hydroelectric station. In 2011, without that support for hydroelectric generation, will the Ballville Dam be removed?
Meanwhile, on Lake Erie, the Lake Erie Energy Development Corporation continues to make progress toward the nation's first inland offshore wind development: five wind turbines in state waters about 7 miles off Cleveland. Great Lakes wind offers many of the advantages of both terrestrial and oceanic wind, while posing other challenges. Will the Lake Erie project be the first to reach success?
May 26, 2010 - Lake Erie to host first freshwater offshore wind farm in USA?
Wednesday, May 26, 2010
General Electric announced this week that it has been selected to provide wind turbines for the Lake Erie Energy Development Corp wind project, which is expected to be the first freshwater wind farm in the United States. The Lake Erie project is under development off the shores of Cleveland, Ohio. GE will initially furnish five 4 MW turbines, which should start operations in 2012. Ultimately, the nonprofit development company wants up to 1,000 MW of installed capacity by 2020.
There's a fair bit of excitement about this project. It will be the first freshwater wind farm in the USA. However, Canada is ahead of us, with the Windstream Wolfe Island Shoals project in Lake Ontario. Windstream is farther along in the development process. Last month, it was awarded a contract by the Ontario Power Authority to buy the 300 MW project's output under a feed-in tariff program, with an initial price of 18.5 cents (CAD) per kWh.
There's a fair bit of excitement about this project. It will be the first freshwater wind farm in the USA. However, Canada is ahead of us, with the Windstream Wolfe Island Shoals project in Lake Ontario. Windstream is farther along in the development process. Last month, it was awarded a contract by the Ontario Power Authority to buy the 300 MW project's output under a feed-in tariff program, with an initial price of 18.5 cents (CAD) per kWh.
Tuesday, March 9, 2010
Maine moves to ban the importation of out-of-state firewood for use in campfires, due to the threat of non-native invasive insect species moving into Maine through the firewood.
More residential weatherization money! Rep. Chellie Pingree held a workshop yesterday with Efficiency Maine and Maine State Housing Authority to -- yet again -- publicize weatherization programs. MSHA has about $34 million for low-income weatherization projects, and Efficiency Maine has $9 million in federal stimulus funds for all income levels.
An editorial in the Toledo Blade calls for Ohio to do more to attract solar energy manufacturers, noting that since 2000 Ohio has slipped from "global leader in solar energy" to 14th out of the United States in number of solar manufacturers.
Remember the huge underground coal mine fire that destroyed the town of Centralia, Pennsylvania? It's back in the news today. The state is moving to take the property within the town by eminent domain, apparently so it can sell the mineral (coal) rights to a mining company. Meanwhile, the few remaining residents are claiming fraud, namely that the underground fire isn't so dangerous and that their property should remain theirs.
International energy news: Senegal and Syria both want civilian nuclear power.
More residential weatherization money! Rep. Chellie Pingree held a workshop yesterday with Efficiency Maine and Maine State Housing Authority to -- yet again -- publicize weatherization programs. MSHA has about $34 million for low-income weatherization projects, and Efficiency Maine has $9 million in federal stimulus funds for all income levels.
An editorial in the Toledo Blade calls for Ohio to do more to attract solar energy manufacturers, noting that since 2000 Ohio has slipped from "global leader in solar energy" to 14th out of the United States in number of solar manufacturers.
Remember the huge underground coal mine fire that destroyed the town of Centralia, Pennsylvania? It's back in the news today. The state is moving to take the property within the town by eminent domain, apparently so it can sell the mineral (coal) rights to a mining company. Meanwhile, the few remaining residents are claiming fraud, namely that the underground fire isn't so dangerous and that their property should remain theirs.
International energy news: Senegal and Syria both want civilian nuclear power.
Subscribe to:
Posts (Atom)
