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The state of Ohio is preparing to cut emissions from coal-burning power plants by 85 percent, but the plan should have minimal impact on Ohio utilities.

The reduction will bring Ohio into compliance with nitrogen oxide emissions standards ordered by the federal government in 1998.

The Ohio Environmental Protection Agency's preliminary plan calls for cuts by May 1, 2004, of 114,000 tons a year of nitrogen oxide, a pollutant that causes acid rain and smog.

Ohio wants to cut annual emissions from 163,132 to 49,535 tons.

"Under Ohio EPA's plan, the goal is to encourage utilities and industry to begin reducing emissions as soon as possible," said agency director Christopher Jones.

Utility companies and other industries that voluntarily implement reductions in 2001, 2002 and 2003 will be rewarded with credits that can be used in 2004 and 2005 at other plants in their system or dealt to other utilities.

Credits also can be earned by plants that reduce energy consumption by increasing efficiency and using renewable sources.

Public comment on the Ohio plan -- it is the third one submitted by the state; the others were rejected by the federal EPA -- is being accepted through Friday. Comments should be directed to Ohio EPA, Division of Air Pollution Control, Attention: Engineering Section, P.O. Box 1049, Columbus, OH 43216.

For more information on the matter, contact Jim Tichich at 614-644-4844. Ohio expects to finalize its plan by June. It must be approved by the federal EPA.

Failure to have a plan in place by mid-2002 would cost the state federal highway dollars.

The state plan is being scrutinized by environmental groups, said Kurt Waltzer of the Columbus-based Ohio Environmental Council.

The cuts will have no impact on what customers pay for electricity because electric prices cannot be raised in Ohio for five years under the state's deregulation rules.

The reductions should have minimal impact on Ohio utility companies because they have known that such cuts were likely under federal clean-air mandates.

Ohio's plan is consistent with the federal plan and should not cause problems, said Ralph Di-Nicola, spokesman for the Akron-based FirstEnergy Corp.

The company "is already well on its way toward compliance," with $250 million earmarked for improvements at its coal-burning plants, he said.

Thomas Ayers, spokesman for the Columbus-based American Electric Power Co., the parent company of the Ohio Power Co. of Canton, said the state plan "should not really cause major impacts."

Last May AEP installed $200 million in anti-pollution equipment at two units of its Gen. James Gavin power plant in Cheshire on the Ohio River in Gallia County.

The company is installing similar equipment at its Cardinal No. 1 plant near Brilliant and its Muskingum River No. 5 plant near Beverly, Ayers said.

The new equipment at those three power plants should enable the utility to comply with the cuts, he said.

In 1998, the federal EPA required 22 states and the District of Columbia to submit plans for reducing nitrogen oxide.

Ohio's utility companies were ordered to cut emissions by 85 percent.

Ohio, six other states and several utilities took the federal EPA to court concerning the reductions.

The U.S. Circuit Court of Appeals for the District of Columbia backed the EPA, although it voided the rules for three states -- Wisconsin, Missouri and Georgia.

The U.S. Supreme Court last March refused to hear the case.

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Two huge wind farms boost investment in America’s heartland

MidAmerican Energy Wind XI expands Iowa wind power with the Beaver Creek and Prairie farms, 169 turbines and 338 MW, delivering renewable energy, grid reliability, rural jobs, and long-term tax revenue through major investment.

 

Key Points

MidAmerican Energy Wind XI is a $3.6B Iowa wind buildout adding 2,000 MW to enhance reliability, jobs, and tax revenue.

✅ 169 turbines at Beaver Creek and Prairie deliver 338 MW.

✅ Wind supplies 36.6 percent of Iowa electricity generation.

✅ Projects forecast $62.4M in property taxes over 20 years.

 

Power company MidAmerican Energy recently announced the beginning of operations at two huge wind farms in the US state of Iowa.

The two projects, called Beaver Creek and Prairie, total 169 turbines and have a combined capacity of 338 megawatts (MW), enough to meet the annual electricity needs of 140,000 homes in the state.

“We’re committed to providing reliable service and outstanding value to our customers, and wind energy accomplishes both,” said Mike Fehr, vice president of resource development at MidAmerican. “Wind energy is good for our customers, and it’s an abundant, renewable resource that also energizes the economy.”

The wind farms form part of MidAmerican Energy’s major Wind XI project, which will see an extra 2,000MW of wind power built, and $3.6 billion invested amid notable wind farm acquisitions shaping the market by the end of 2019. The company estimates it is the largest economic development project in Iowa’s history.

Iowa is something of a hidden powerhouse in American wind energy. The technology provides an astonishing 36.6 percent of the state’s entire electricity generation and plays a growing role in the U.S. electricity mix according to the American Wind Energy Association (AWEA). It also has the second largest amount of installed capacity in the nation at 6917MW; Texas is first with over 21,000MW.

Along with capital investment, wind power brings significant job opportunities and tax revenues for the state. An estimated 9,000 jobs are supported by the industry, something a U.S. wind jobs forecast stated could grow to over 15,000 within a couple of years.

MidAmerican Energy is also keen to stress the economic benefits of its new giant projects, claiming that they will bring in $62.4 million of property tax revenue over their 20-year lifetime.

Tom Kiernan, AWEA’s CEO, revealed last year that, as the most-used source of renewable electricity in the U.S., wind energy is providing more than five states in the American Midwest with over 20 percent of electricity generation, “a testament to American leadership and innovation”.

“For these states, and across America, wind is welcome because it means jobs, investment, and a better tomorrow for rural communities”, he added.

 

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Heating and Electricity Costs in Germany Set to Rise

Germany 2025 Energy Costs forecast electricity and heating price trends amid gas volatility, renewables expansion, grid upgrades, and policy subsidies, highlighting impacts on households, industries, efficiency measures, and the Energiewende transition dynamics.

 

Key Points

Electricity stabilizes, gas-driven heating stays high; renewables, subsidies, and efficiency measures moderate costs.

✅ Power prices stabilize above pre-crisis levels

✅ Gas volatility keeps heating bills elevated

✅ Subsidies and efficiency upgrades offset some costs

 

As Germany moves into 2025, the country is facing significant shifts in heating and electricity costs. With a variety of factors influencing energy prices, including geopolitical tensions, government policies, and the ongoing transition to renewable energy sources, consumers and businesses alike are bracing for potential changes in their energy bills. In this article, we will explore how heating and electricity costs are expected to evolve in Germany in the coming year and what that means for households and industries.

Energy Price Trends in Germany

In recent years, energy prices in Germany have experienced notable fluctuations, particularly due to the aftermath of the global energy crisis, which was exacerbated by the Russian invasion of Ukraine. This geopolitical shift disrupted gas supplies, which in turn affected electricity prices and strained local utilities across the country. Although the German government introduced measures to mitigate some of the price increases, many households have still felt the strain of higher energy costs.

For 2024, experts predict that electricity prices will likely stabilize but remain higher than pre-crisis levels. While electricity prices nearly doubled in 2022, they have gradually started to decline, and the market has adjusted to the new realities of energy supply and demand. Despite this, the cost of electricity is expected to stay elevated as Germany continues to phase out coal and nuclear energy while ramping up the use of renewable sources, which often require significant infrastructure investments.

Heating Costs: A Mixed Outlook

Heating costs in Germany are heavily influenced by natural gas prices, which have been volatile since the onset of the energy crisis. Gas prices, although lower than the peak levels seen in 2022, are still considerably higher than in the years before. This means that households relying on gas heating can expect to pay more for warmth in 2024 compared to previous years.

The government has implemented measures to cushion the impact of these increased costs, such as subsidies for vulnerable households and efforts to support energy efficiency upgrades. Despite these efforts, consumers will still feel the pinch, particularly in homes that use older, less efficient heating systems. The transition to more sustainable heating solutions, such as heat pumps, remains a key goal for the German government. However, the upfront cost of such systems can be a barrier for many households.

The Role of Renewable Energy and the Green Transition

Germany has set ambitious goals for its energy transition, known as the "Energiewende," which aims to reduce reliance on fossil fuels and increase the share of renewable energy sources in the national grid. In 2024, Germany is expected to see further increases in renewable energy generation, particularly from wind and solar power. While this transition is essential for reducing carbon emissions and improving long-term energy security, the shift comes with its own challenges already documented in EU electricity market trends reports.

One of the main factors influencing electricity costs in the short term is the intermittency of renewable energy sources. Wind and solar power are not always available when demand peaks, requiring backup power generation from fossil fuels or stored energy. Additionally, the infrastructure needed to accommodate a higher share of renewables, including grid upgrades and energy storage solutions, is costly and will likely contribute to rising electricity prices in the near term.

On a positive note, Germany's growing investment in renewable energy is expected to make the country less reliant on imported fossil fuels, particularly natural gas, which has been a major source of price volatility. Over time, as the share of renewables in the energy mix grows, the energy system should become more stable and less susceptible to geopolitical shocks, which could lead to more predictable and potentially lower energy costs in the long run.

Government Interventions and Subsidies

To help ease the burden on consumers, the German government has continued to implement various measures to support households and businesses. One of the key programs is the reduction in VAT (Value Added Tax) on electricity, which has been extended in some regions. This measure is designed to make electricity more affordable for all households, particularly those on fixed incomes facing EU energy inflation pressures that have hit the poorest hardest.

Moreover, the government has been providing financial incentives for households and businesses to invest in energy-efficient technologies, such as insulation and energy-saving heating systems, complementing the earlier 200 billion euro energy shield announced to buffer surging prices. These incentives are intended to reduce overall energy consumption, which could offset some of the rising costs.

The outlook for heating and electricity costs in Germany for 2024 is mixed, even as energy demand hit a historic low amid economic stagnation. While some relief from the extreme price spikes of 2022 may be felt, energy costs will still be higher than they were in previous years. Households relying on gas heating will likely see continued elevated costs, although those who invest in energy-efficient solutions or renewable heating technologies may be able to offset some of the increases. Similarly, electricity prices are expected to stabilize but remain high due to the country’s ongoing transition to renewable energy sources.

While the green transition is crucial for long-term sustainability, consumers must be prepared for potentially higher energy costs in the short term. Government subsidies and incentives will help alleviate some of the financial pressure, but households should consider strategies to reduce energy consumption, such as investing in more efficient heating systems or adopting renewable energy solutions like solar panels.

As Germany navigates these changes, the country’s energy future will undoubtedly be shaped by a delicate balance between environmental goals and the economic realities of transitioning to a greener energy system.

 

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Australia's energy transition stalled by stubbornly high demand

Australia Renewable Energy Transition: solar capacity growth, net-zero goals, rising electricity demand, coal reliance, EV adoption, grid decarbonization, heat waves, air conditioning loads, and policy incentives shaping clean power, efficiency, and emissions reduction.

 

Key Points

Australia targets net-zero by 2050 by scaling renewables, curbing demand, and phasing down coal and gas.

✅ Solar capacity up 200% since 2018, yet coal remains dominant.

✅ Transport leads energy use; EV uptake lags global average.

✅ Heat waves boost AC load, stressing grids and emissions goals.

 

A more than 200% increase in installed solar power generation capacity since 2018 helped Australia rank sixth globally in terms of solar capacity last year and emerge as one of the world's fastest-growing major renewable energy producers, aligning with forecasts that renewables to surpass coal in global power generation by 2025.

However, to realise its goal of becoming a net-zero carbon emitter by 2050, Australia must reverse the trajectory of its energy use, which remains on a rising path, even as Asia set to use half of electricity underscores regional demand growth, in contrast with several peers that have curbed energy use in recent years.

Australia's total electricity consumption has grown nearly 8% over the past decade, amid a global power demand surge that has exceeded pre-pandemic levels, compared with contractions over the same period of more than 7% in France, Germany and Japan, and a 14% drop in the United Kingdom, data from Ember shows.

Sustained growth in Australia's electricity demand has in turn meant that power producers must continue to heavily rely on coal for electricity generation on top of recent additions in supply of renewable energy sources, with low-emissions generation growth expected to cover most new demand.

Australia has sharply boosted clean energy capacity in recent years, but remains heavily reliant on coal & natural gas for electricity generation
To accomplish emissions reduction targets on time, Australia's energy use must decline while clean energy supplies climb further, as that would give power producers the scope to shut high-polluting fossil-powered energy generation systems ahead of the 2050 deadline.

DEMAND DRIVERS
Reducing overall electricity and energy use is a major challenge in all countries, where China's electricity appetite highlights shifting consumption patterns, but will be especially tough in Australia which is a relative laggard in terms of the electrification of transport systems and is prone to sustained heat waves that trigger heavy use of air conditioners.

The transport sector uses more energy than any other part of the Australian economy, including industry, and accounted for roughly 40% of total final energy use as of 2020, according to the International Energy Agency (IEA.)

Transport energy demand has also expanded more quickly than other sectors, growing by over 5% from 2010 to 2020 compared to industry's 1.3% growth over the same period.

Transport is Australia's main energy use sector, and oil products are the main source of energy type
To reduce energy use, and cut the country's fuel import bill which topped AUD $65 billion in 2022 alone, according to the Australian Bureau of Statistics, the Australian government is keen to electrify car fleets and is offering large incentives for electric vehicle purchases.

Even so, electric vehicles accounted for only 5.1% of total Australian car sales in 2022, according to the International Energy Agency (IEA).

That compares to 13% in New Zealand, 21% in the European Union, and a global average of 14%.

More incentives for EV purchases are expected, but any rapid adoption of EVs would only serve to increase overall electricity demand, and with surging electricity demand already straining power systems worldwide, place further pressure on power producers to increase electricity supplies.

Heating and cooling for homes and businesses is another major energy demand driver in Australia, and accounts for roughly 40% of total electricity use in the country.

Australia is exposed to harsh weather conditions, especially heat waves which are expected to increase in frequency, intensity and duration over the coming decades due to climate change, according to the New South Wales government.

To cope, Australians are expected to resort to increased use of air conditioners during the hottest times of the year, and with reduced power reserves flagged by the market operator, adding yet more strain to electricity systems.

 

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Hydro One employees support Province of Ontario in the fight against COVID-19

Hydro One COVID-19 Quarantine Support connects Ontario's Ministry of Health with trained customer service teams to contact travellers, encourage self-isolation, explain quarantine rules, and share public health guidance to slow community transmission.

 

Key Points

Hydro One helps Ontario's MOH contact travellers and guide self-isolation for quarantine compliance.

✅ Trained agents contact returning travellers in Ontario

✅ Guidance on self-isolation, symptoms, and quarantine compliance

✅ Supports public health while freeing front-line resources

 

Hydro One Networks Inc. ("Hydro One") announced support to the Ministry of Health (MOH) with its efforts in contacting travellers entering Ontario to ensure they comply with Canada's mandatory quarantine measures to combat COVID-19. Hydro One has volunteered employees from its customer service operations to contact thousands of returning travellers to provide them with timely guidance on how to self-isolate and spot the symptoms of the virus to help stop its spread.

"Our team is ready to lend a helping hand and support the province to help fight this invisible enemy," said Mark Poweska, President and CEO, Hydro One. "Our very dedicated customer service staff are highly professional and will be a valuable resource in supporting the province as it works to keep Ontarians safe and slow the spread of COVID-19."

"We have seen a tremendous response from all our companies across Ontario to help us fight the COVID-19 outbreak. With this one, Hydro One is helping the province to remind Ontarians they need to stay safe at home, especially self-isolating customers throughout Ontario," said Christine Elliott, Deputy Premier and Minister of Health. "We thank them for stepping up to be part of the fantastic province-wide effort acting together and allowing our front line workers to focus their efforts where they are needed most during this challenging time."

"We are pleased to see Hydro One volunteer its resources and expertise to support in the fight against COVID-19," said Greg Rickford, Minister of Energy, Northern Development and Mines. "In these unprecedented times, I am proud to see leaders in the energy sector rise to the challenge, from restoring power after major storms to supporting the people of our province."

Hydro One and its employees play a critical role in maintaining Ontario's electricity system. Since the COVID-19 outbreak began, Hydro One has been monitoring the evolving situation and adapting its operations, including on-site lockdowns for key staff as needed to ensure it continues to deliver the service Ontarians depend on while keeping our employees, customers and the public safe.

Hydro One has also developed a number of customer support measures during COVID-19, including a new Pandemic Relief Fund to offer payment flexibility and financial assistance to customers experiencing financial hardship, suspending late payment fees and returning approximately $5 million in security deposits to businesses across Ontario.

"Customers are counting on us now more than ever – not only to keep the lights on across the province, but to offer support during this difficult time," said Poweska. "Hydro One will continue to collaborate with industry partners and the province, including mutual aid assistance with other utilities, to find new ways to offer support where it is needed."

More information about how Hydro One is supporting its customers, including its ban on disconnections and other measures, can be found at www.HydroOne.com/PandemicRelief .

 

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Warning: Manitoba Hydro can't service new 'energy intensive' customers

Manitoba Hydro capacity constraints challenge clean energy growth as industrial demand, hydrogen projects, EV batteries, and electrification strain the grid; limited surplus, renewables, storage, and transmission bottlenecks hinder new high-load connections.

 

Key Points

Limited surplus power blocks new energy-intensive loads until added generation and transmission expand Manitoba's grid.

✅ No firm commitments for new energy-intensive industrial customers

✅ Single large load could consume remaining surplus capacity

✅ New renewables need transmission; gas, nuclear face trade-offs

 

Manitoba Hydro lacks the capacity to provide electricity to any new "energy intensive" industrial customers, the Crown corporation warns in a confidential briefing note that undercuts the idea this province can lure large businesses with an ample supply of clean, green energy, as the need for new power generation looms for the utility.

On July 28, provincial economic development officials unveiled an "energy roadmap" that said Manitoba Hydro must double or triple its generating capacity, as electrical demand could double over the next two decades in order to meet industrial and consumer demand for electricity produced without burning fossil fuels.

Those officials said 18 potential new customers with high energy needs were looking at setting up operations in Manitoba — and warned the province must be careful to choose businesses that provide the greatest economic benefit as well as the lowest environmental impact.

In a briefing note dated Sept. 13, obtained by CBC News, Manitoba Hydro warns it doesn't have enough excess power to hook up any of these new heavy electricity-using customers to the provincial power grid.

There are actually 57 proposals to use large volumes of electricity, Hydro says in the note, including eight projects already in the detailed study phase and nine where the proponents are working on construction agreements.

"Manitoba Hydro is unable to offer firm commitments to prospective customers that may align with Manitoba's energy roadmap and/or provincial economic development objectives," Hydro warns in the note, explaining it is legally obliged to serve all existing customers who need more electricity.

"As such, Manitoba Hydro cannot reserve electric supply for particular projects."

Hydro says in the note its "near-term surplus electricity supply" is so limited amid a Western Canada drought that "a single energy-intensive connection may consume all remaining electrical capacity."

Adding more electrical generating capacity won't be easy, even with new turbine investments underway, and will not happen in time to meet demands from customers looking to set up shop in the province, Hydro warns.

The Crown corporation goes on to say it's grappling with numerous requests from existing and prospective energy-intensive customers, mainly for producing hydrogen, manufacturing electric vehicle batteries and switching from fossil fuels to electricity, such as to use electricity for heat in buildings.

In a statement, Hydro said it wants to ensure Manitobans know the corporation is not running out of power — just the ability to meet the needs of large new customers, and continues to provide clean energy to neighboring provinces today.

"The size of loads looking to come to Manitoba are significantly larger than we typically see, and until additional supply is available, that limits our ability to connect them," Hydro spokesperson Bruce Owen said in a statement.

Adding wind power or battery storage, for example, would require the construction of more transmission lines, and deals such as SaskPower's purchase depend on that interprovincial infrastructure as well.

Natural gas plants are relatively inexpensive to build but do not align with efforts to reduce carbon emissions. Nuclear power plants require at least a decade of lead time to build, and tend to generate local opposition.

Hydro has also ruled out building another hydroelectric dam on the Nelson River, where the Conawapa project was put on hold in 2014.

 

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Pacific Northwest's Renewable Energy Goals Hindered

Pacific Northwest Transmission Bottleneck slows clean energy progress as BPA's aging grid constrains renewable interconnections, delaying wind, solar, and data center growth; decarbonization targets depend on transmission upgrades, new substations, and policy reform.

 

Key Points

An interconnection and capacity shortfall on BPA's aging grid that delays renewables and impedes clean energy goals.

✅ BPA approvals lag: 1 of 469 projects since 2015.

✅ Yakama solar waits for substation upgrades until 2027.

✅ Data centers and decarbonization targets face grid constraints.

 

Oregon and Washington have set ambitious targets to decarbonize their power sectors, aiming for 100% clean electricity in the coming decades. However, a significant obstacle stands in the way: the region's aging and overburdened transmission grid, underscoring why 100% renewables remain elusive even as momentum builds.

The Grid Bottleneck

The BPA operates a transmission system that is nearly a century old in some areas, and its capacity has not expanded sufficiently to accommodate the influx of renewable energy projects, reflecting stalled grid spending in many parts of the U.S., according to recent analyses. Since 2015, 469 large renewable projects have applied to connect to the BPA's grid; however, only one has been approved—a stark contrast to other regions in the country. This bottleneck has left numerous wind and solar projects in limbo, unable to deliver power to the grid.

One notable example is the Yakama Nation's solar project. Despite receiving a $32 million federal grant under the bipartisan infrastructure law as part of a broader grid overhaul for renewables, the tribe faces significant delays. The BPA estimates that it will take until 2027 to complete the necessary upgrades to the transmission system, including a new substation, before the solar array can be connected. This timeline poses a risk of losing federal funding if the project isn't operational by 2031.

Economic and Environmental Implications

The slow pace of grid expansion has broader implications for the region's economy and environmental goals. Data centers and other energy-intensive industries are increasingly drawn to the Pacific Northwest due to its clean energy potential, while interregional projects like the Wyoming-to-California wind link illustrate how transmission access can unlock supply. However, without adequate infrastructure, these industries may seek alternatives elsewhere. Additionally, the inability to integrate renewable energy efficiently hampers efforts to reduce greenhouse gas emissions and combat climate change.

Policy Challenges and Legislative Efforts

Efforts to address the grid limitations through state-level initiatives have faced challenges, even as a federal rule to boost transmission advances nationally. In 2025, both Oregon and Washington considered legislation to establish state bonding authorities aimed at financing transmission upgrades. However, these bills failed to pass, leaving the BPA as the primary entity responsible for grid expansion. The BPA's unique structure—operating as a self-funded federal agency without direct state oversight—has made it difficult for regional leaders to influence its decision-making processes.

Looking Ahead

The Pacific Northwest's renewable energy aspirations hinge on modernizing its transmission infrastructure, aligning with decarbonization strategies that emphasize grid buildout. While the BPA has proposed several projects to enhance grid capacity, the timeline for completion remains uncertain. Without significant investment and policy reforms, the region risks falling behind in the transition to a clean energy future. Stakeholders across Oregon and Washington must collaborate to advocate for necessary changes and ensure that the grid can support the growing demand for renewable energy.

The Pacific Northwest's commitment to clean energy is commendable, but achieving these goals requires overcoming substantial infrastructure challenges, and neighboring jurisdictions such as British Columbia have pursued B.C. regulatory streamlining to accelerate projects. Addressing the limitations of the BPA's transmission system is critical to unlocking the full potential of renewable energy in the region. Only through concerted efforts at the federal, state, and local levels can Oregon and Washington hope to realize their green energy ambitions.

 

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