Bush says Congress stands in way of cheaper energy

By Investor's Business Daily


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Following are excerpts from President Bush's Rose Garden press conference recently that dealt with energy.

This is a tough time for our economy. Across our country many Americans are understandably anxious about issues affecting their pocketbook, from gas and food prices to mortgage and tuition bills. They're looking to their elected leaders in Congress for action.

Unfortunately, on many of these issues all they're getting is delay.

Americans are concerned about energy prices, and I can understand why. I think the last time I visited with you I said it was like a tax increase on the working people. The past 18 months, gas prices have gone up by $1.40 per gallon. Electricity prices for small business and families are rising as well.

I've repeatedly submitted proposals to help address these problems. Yet time after time, Congress chose to block them.

One of the main reasons for high gas prices is that global oil production is not keeping up with growing demand. Members of Congress have been vocal about foreign governments increasing their oil production; yet Congress has been just as vocal in opposition to efforts to expand our production here at home.

They repeatedly blocked environmentally safe exploration in ANWR (the Arctic National Wildlife Refuge). The Department of Energy estimates that ANWR could allow America to produce about a million additional barrels of oil every day, which translates to about 27 millions of gallons of gasoline and diesel every day.

That would be about a 20% increase of crude oil production over U.S. levels, and it would likely mean lower gas prices. And yet such efforts to explore in ANWR have been consistently blocked.

Another reason for high gas prices is the lack of refining capacity. It's been more than 30 years since America built its last new refinery. Yet in this area, too, Congress has repeatedly blocked efforts to expand capacity and build more refineries.

As electricity prices rise, Congress continues to block provisions needed to increase domestic electricity production by expanding the use of clean, safe nuclear power. Instead, many of the same people in Congress who complain about high energy costs support legislation that would make energy even more expensive for our consumers and small businesses.

Congress is considering bills to raise taxes on domestic energy production, impose new and costly mandates on producers, and demand dramatic emissions cuts that would shut down coal plants, and increase reliance on expensive natural gas. That would drive up prices even further. The cost of these actions would be passed on to consumers in the form of even higher prices at the pump and even bigger electric bills.

Instead of increasing costs and increasing new roadblocks to domestic energy production, Congress needs to clear away obstacles to more affordable, more reliable energy here at home.

Q: Would you support a summer moratorium on the federal gas tax?

President Bush: We'll look at any idea in terms of energy, except I will tell you this: If Congress is truly interested in solving the problem, they can send the right signal by saying we're going to explore for oil and gas in the U.S. territories, starting with ANWR. We can do so in an environmentally friendly way.

I proposed, you might remember, taking some abandoned military bases and providing regulatory relief so we can build new refineries. If we're generally interested in moving forward with an energy policy, that sends a signal to the world that we're going to try to become less reliant upon foreign oil, we can explore at home as well as continue on with an alternative-fuels program.

Q: Was that a "yes" on the moratorium?

A: I'm going to look at everything they propose. We'll take a look.

Q: What more can you do to persuade Saudi Arabia during your upcoming visit to reconsider output levels and cut prices?

A: I have made the case that the high price of oil injures economies. But I think we better understand that there's not a lot of excess capacity in this world right now. Hopefully high prices will spur more exploration to bring excess capacity on, but demand is rising faster than supply. That's why you're seeing global energy prices rise. And that's why it's important for us to try to take the pressure off by saying we're going to start exploring here at home.

Q: The World Bank says about 85% of the increase in corn price since 2002 is due to increased demand for biofuels. And your secretary of state indicated that she thought that might be part of the problem. Do you agree with that? And what more can the United States do to help make food more affordable around the world?

A: Actually, I have a little different take: I thought it was 85% of the world's food prices are caused by weather, increased demand and energy prices — just the cost of growing product — and that 15% has been caused by the arrival of ethanol.

By the way, the high price of gasoline is going to spur more investment in ethanol as an alternative to gasoline. And the truth of the matter is it's in our national interests that our farmers grow energy, as opposed to us purchasing energy from parts of the world that are unstable or may not like us.

Q: The gas tax moratorium (is) perhaps the most immediate relief to people who are buying gasoline every day, because it would be an 18.4-cents-a-gallon tax cut. Sens. Clinton and McCain are in favor of it; Sen. Obama is not. But Americans are hearing about this every day. So could you flesh out some of your thinking about why this would be a good idea or not.

A: If it's a good idea, we embrace it; if not, we're analyzing the different ideas coming forward.

Q: You just said there's not a lot of excess supply out there. Some energy experts think we may have already passed, or (are) within a couple of years of passing, the maximum oil-pumping capability. In other words, we may be close to tapping all we've got. Do you think that's the case? And if you do, why haven't you put more resources into renewable energy research, sir?

A: We've put a lot into ethanol. As a matter of fact, the solution to the issue of corn-fed ethanol is cellulosic ethanol, which is a fancy word for saying we're going to make ethanol out of switch grasses, or wood chips. And we're spending a lot of money along those lines.

But energy policy needs to be comprehensive. We've got to understand we're in a transition period. The problem is there's been a lot of focus by the Congress in the intermediate and long-term steps — the long-term steps being hydrogen; the intermediate steps being biofuels and battery technology. But not enough emphasis on the here and now.

You say that people think... there's not any more reserves to be found. Well, there are reserves to be found in ANWR; that's a given. I just told you that there's about 27 million gallons of diesel and gasoline from domestically produced crude oil that's not being utilized.

And not only that, we can explore in environmentally friendly ways. New technologies enable (drilling) like we've never been able to do before — slant-hole technologies and the capacity to use a single drill site to explore a field in a way that doesn't damage the environment.

Yet, this is a litmus-test issue for many in Congress. Somehow if you mention ANWR, it means you don't care about the environment. I'm hoping that when people say "ANWR," it means you don't care about the gasoline prices that people are paying.

Q: Fourteen senators, including your own senator, Kay Bailey Hutchison from Texas, are calling on you to stop filling the Strategic Petroleum Reserve. You've been asked that several times over the past few years. I know what your answer has been. But do you think now, with the rising prices, the record high oil prices, it's time to change course?

A: In this case, I have analyzed the issue, and I don't think it would affect price for this reason: We're buying, at the moment, about 67,000 to 68,000 barrels of oil per day, fulfilling statutory obligations to fill up the SPR. World demand is 85 million barrels a day. So the purchases for SPR account for 1/10th of 1% of global demand. I don't think that's going to affect price when you affect 1/10th of 1%, and I do believe it is in our national interests to get the SPR filled in case there's a major disruption of crude oil around the world.

One of the things al-Qaida would like to do is blow up oil facilities, understanding that we're in a global market (and) an attack on an oil facility in a major oil-exporting country would affect the economies of their enemy — that would be us and other people who can't stand what al-Qaida stands for.

Therefore, if that's the case, the SPR is necessary to be able to deal with that kind of contingency. If I thought it would affect the price of oil positively, I'd seriously consider it. But when you're talking about 1/10th of 1% of global demand, I don't think that on a cost-benefit analysis, you get any benefits from making the decision. I do think it costs you oil in the case of a national security risk.

Q: You have spoken today about opening ANWR for drilling and also refineries. But these are clearly long-term solutions to the problem of rising gas prices. What can you tell Americans about what your administration is doing in the short term?

A: Opening up ANWR is not long-term; it's intermediate term. But it sends a clear signal... to the markets that the United States is not going to restrict exploration, that the United States is going to encourage exploration.

Part of this is to set the psychology right (by saying) to the world: We're not going to become more beholden on your oil, we're going to open up and be aggressive and have an aggressive energy policy. (And) secondly, we're going to send the signal we're going to be building new refineries.

But there is no magic wand to wave right now. It took us a while to get to this fix. Congress (could have) responded (by passing) ANWR in the late 1990s... but it didn't go forward. It's my considered judgment that, given the technological advances, to say we'll destroy the environment is just (not) an accurate statement.

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BC Hydro says province sleeping in, showering less in pandemic

BC Hydro pandemic electricity trends reveal weekend-like energy consumption patterns: later morning demand, earlier evenings, more cooking, streaming on smart TVs, and work-from-home routines, with tips to conserve using laptops and small appliances.

 

Key Points

Weekend-like shifts in power demand from work-from-home routines: later mornings, earlier evenings, and more streaming.

✅ Later morning electricity demand; earlier evening peaks

✅ More cooking and baking; increased streaming after dinner

✅ Conservation tips: laptops, small appliances, smart TVs

 

The latest report on electricity usage in British Columbia reveals the COVID-19 pandemic has created an atmosphere where every day feels like a Saturday, a pattern also reflected in BC electricity demand during peak seasons.

BC Hydro says overall power usage hasn't changed much, but similar Ontario electricity demand shifts suggest regional differences, while Manitoba demand fell more noticeably, and a survey of 500 people shows daily routines have shifted dramatically since mid-March when pandemic-related closures began.

The hydro report says, with nearly 40 per cent of B.C. residents working from home, trends in residential electricity use confirm almost half are sleeping in and eating breakfast later, while about a quarter say they are showering less.

Those patterns more closely resemble what hydro says is typical weekend power consumption, and could influence time-of-use rates as electricity demand occurs later in the morning and earlier in the evening.

The report also finds many people are cooking and baking more than before the pandemic, preparing the evening meal earlier, streaming or viewing more television after dinner even as Ottawa's electricity consumption dipped earlier in the pandemic, and 80 per cent are going to bed later.

Although electricity use is normal for this time of year, hydro says homebound residents can conserve by using laptops instead of desktops, small appliances such as Instant Pots instead of ovens, and streaming movies or TV shows on a smart televisions instead of game consoles, even as Hydro One peak rates continue to shape consumption patterns elsewhere.

 

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Freezing Rain Causes Widespread Power Outages in Quebec

Quebec Ice Storm 2025 disrupted power across Laurentians and Lanaudiere as freezing rain downed lines; Hydro-QuE9bec crews accelerated grid restoration, emergency response, and infrastructure resilience amid ongoing outages and severe weather alerts.

 

Key Points

Quebec Ice Storm 2025 brought freezing rain, outages, and grid damage, hitting Laurentians and Lanaudiere hardest.

✅ Peak: 62,000 Hydro-QuE9bec customers without electricity

✅ Most outages in Laurentians and Lanaudiere regions

✅ Crews repairing lines; restoration updates ongoing

 

A significant weather event struck Quebec in late March 2025, as a powerful ice storm caused widespread power outages across the province. The storm led to extensive power outages, affecting tens of thousands of residents, particularly in the Lanaudière and Laurentians regions. ​

Impact on Power Infrastructure

The freezing rain accumulated on power lines and vegetation, leading to numerous power outages across the network. Hydro-Québec reported that at its peak, over 62,000 customers were without electricity, with the majority of outages concentrated in the Laurentians and Lanaudière regions. By the afternoon, the number decreased to approximately 30,000, and further to just under 18,500 by late afternoon. 

Comparison with Previous Storms

While the March 2025 ice storm caused significant disruptions, it was less severe compared to the catastrophic ice storm of April 2023, which left 1.1 million Hydro-Québec customers without power. Nonetheless, the 2025 storm's impact was considerable, leading to the closure of municipal facilities and posing challenges for local economies, a pattern echoed when Toronto outages persisted for hundreds after a spring storm.

Ongoing Challenges

As of April 1, 2025, some areas continued to experience power outages, and incidents such as a manhole fire left thousands without service in separate cases. Hydro-Québec and municipal authorities worked diligently to restore services and address the aftermath of the storm, while Hydro One crews restored power to more than 277,000 customers after damaging storms in Ontario. Residents were advised to stay updated through official channels for restoration timelines and safety information.

Future Preparedness

The recurrence of such severe weather events highlights the importance of robust infrastructure and emergency preparedness, as seen in BC Hydro's storm response to an 'atypical' event that demanded extensive coordination. Both utility companies and residents must remain vigilant, especially during seasons prone to unpredictable weather patterns, with local utilities like Sudbury Hydro crews working to reconnect service after regional storms.

 

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California electricity pricing changes pose an existential threat to residential rooftop solar

California Rooftop Solar Rate Reforms propose shifting net metering to fixed access fees, peak-demand charges, and time-of-use pricing, aligning grid costs, distributed generation incentives, and retail rates for efficient, least-cost electricity and fair cost recovery.

 

Key Points

Policies replacing net metering with fixed fees, demand charges, and time-of-use rates to align costs and incentives.

✅ Large fixed access charge funds grid infrastructure

✅ Peak-demand pricing reflects capacity costs at system peak

✅ Time-varying rates align marginal costs and emissions

 

The California Public Service Commission has proposed revamping electricity rates for residential customers who produce electricity through their rooftop solar panels. In a recent New York Times op‐​ed, former Governor Arnold Schwarzenegger argued the changes pose an existential threat to residential rooftop solar. Interest groups favoring rooftop solar portray the current pricing system, often called net metering, in populist terms: “Net metering is the one opportunity for the little guy to get relief, and they want to put the kibosh on it.” And conventional news coverage suggests that because rooftop solar is an obvious good development and nefarious interests, incumbent utilities and their unionized employees, support the reform, well‐​meaning people should oppose it. A more thoughtful analysis would inquire about the characteristics and prices of a system that supplies electricity at least cost.

Currently, under net metering customers are billed for their net electricity use plus a minimum fixed charge each month. When their consumption exceeds their home production, they are billed for their net use from the electricity distribution system (the grid) at retail rates. When their production exceeds their consumption and the excess is supplied to the grid, residential consumers also are reimbursed at retail rates. During a billing period, if a consumer’s production equaled their consumption their electric bill would only be the monthly fixed charge.

Net metering would be fine if all the fixed costs of the electric distribution and transmission systems were included in the fixed monthly charge, but they are not. Between 66 and 77 percent of the expenses of California private utilities do not change when a customer increases or decreases consumption, but those expenses are recovered largely through charges per kWh of use rather than a large monthly fixed charge. Said differently, for every kWh that a PG&E solar household exported into the grid in 2019, it saved more than 26 cents, on average, while the utility’s costs only declined by about 8 cents or less including an estimate of the pollution costs of the system’s fossil fuel generators. The 18‐​cent difference pays for costs that don’t change with variation in a household’s consumptions, like much of the transmission and distribution system, energy efficiency programs, subsidies for low‐​income customers, and other fixed costs. Rooftop solar is so popular in California because its installation under a net metering system avoids the 18 cents, creating a solar cost shift onto non-solar customers. Rooftop solar is not the answer to all our environmental needs. It is simply a form of arbitrage around paying for the grid’s fixed costs.

What should electricity tariffs look like? This article in Regulation argues that efficient charges for electricity would consist of three components: a large fixed charge for the distribution and transmission lines, meter reading, vegetation trimming, etc.; a peak‐​demand charge related to your demand when the system’s peak demand occurs to pay for fixed capacity costs associated with peak use; and a charge for electricity use that reflects the time‐ and location‐​varying cost of additional electricity supply.

Actual utility tariffs do not reflect this ideal because of political concerns about the effects of large fixed monthly charges on low‐​income customers and the optics of explaining to customers that they must pay 50 or 60 dollars a month for access even if their use is zero. Instead, the current pricing system “taxes” electricity use to pay for fixed costs. And solar net metering is simply a way to avoid the tax. The proposed California rate reforms would explicitly impose a fixed monthly charge on rooftop solar systems that are also connected to the grid, a change that could bring major changes to your electric bill statewide, and would thus end the fixed‐​cost avoidance. Any distributional concerns that arise because of the effect of much larger fixed charges on lower‐​income customers could be managed through explicit tax deductions that are proportional to income.

The current rooftop solar subsidies in California also should end because they have perverse incentive effects on fossil fuel generators, even as the state exports its energy policies to neighbors. Solar output has increased so much in California that when it ends with every sunset, natural gas generated electricity has to increase very rapidly. But the natural gas generators whose output can be increased rapidly have more pollution and higher marginal costs than those natural gas plants (so called combined cycle plants) whose output is steadier. The rapid increase in California solar capacity has had the perverse effect of changing the composition of natural gas generators toward more costly and polluting units.

The reforms would not end the role of solar power. They would just shift production from high‐​cost rooftop to lower‐​cost centralized solar production, a transition cited in analyses of why electricity prices are soaring in California, whose average costs are comparable with electricity production in natural gas generators. And they would end the excessive subsidies to solar that have negatively altered the composition of natural gas generators.

Getting prices right does not generate citizen interest as much as the misguided notion that rooftop solar will save the world, and recent efforts to overturn income-based utility charges show how politicized the debate remains. But getting prices right would allow the decentralized choices of consumers and investors to achieve their goals at least cost.

 

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From smart meters to big batteries, co-ops emerge as clean grid laboratories

Minnesota Electric Cooperatives are driving grid innovation with smart meters, time-of-use pricing, demand response, and energy storage, including iron-air batteries, to manage peak loads, integrate wind and solar, and cut costs for rural members.

 

Key Points

Member-owned utilities piloting load management, meters, and storage to integrate wind and solar, cutting peak demand.

✅ Time-of-use pricing pilots lower bills and shift peak load.

✅ Iron-air battery tests add multi-day, low-cost energy storage.

✅ Smart meters enable demand response across rural co-ops.

 

Minnesota electric cooperatives have quietly emerged as laboratories for clean grid innovation, outpacing investor-owned utilities on smart meter installations, time-based pricing pilots, and experimental battery storage solutions.

“Co-ops have innovation in their DNA,” said David Ranallo, a spokesperson for Great River Energy, a generation and distribution cooperative that supplies power to 28 member utilities — making it one of the state’s largest co-op players.

Minnesota farmers helped pioneer the electric co-op model more than a century ago, similar to modern community-generated green electricity initiatives, pooling resources to build power lines, transformers and other equipment to deliver power to rural parts of the state. Today, 44 member-owned electric co-ops serve about 1.7 million rural and suburban customers and supply almost a quarter of the state’s electricity.

Co-op utilities have by many measures lagged on clean energy. Many still rely on electricity from coal-fired power plants. They’ve used political clout with rural lawmakers to oppose new pollution regulations and climate legislation, and some have tried to levy steep fees on customers who install solar panels.

Where they are emerging as innovators is with new models and technology for managing electric grid loads — from load-shifting water heaters to a giant experimental battery made of iron. The programs are saving customers money by delaying the need for expensive new infrastructure, and also showing ways to unlock more value from cheap but variable wind and solar power.

Unlike investor-owned utilities, “we have no incentive to invest in new generation,” said Darrick Moe, executive director of the Minnesota Rural Electric Association. Curbing peak energy demand has a direct financial benefit for members.

Minnesota electric cooperatives have launched dozens of programs, such as the South Metro solar project, in recent years aimed at reducing energy use and peak loads, in particular. They include:

Cost calculations are the primary driver for electric cooperatives’ recent experimentation, and a lighter regulatory structure and evolving electricity market reforms have allowed them to act more quickly than for-profit utilities.

“Co-ops and [municipal utilities] can act a lot more nimbly compared to investor-owned utilities … which have to go through years of proceedings and discussions about cost-recovery,” said Gabe Chan, a University of Minnesota associate professor who has researched electric co-ops extensively. Often, approval from a local board is all that’s required to launch a venture.

Great River Energy’s programs, which are rebranded and sold through member co-ops, yielded more than 101 million kilowatt-hours of savings last year — enough to power 9,500 homes for a year.

Beyond lowering costs for participants and customers at large, the energy-saving and behavior-changing programs sometimes end up being cited as case studies by larger utilities considering similar offerings. Advocates supporting a proposal by the city of Minneapolis and CenterPoint Energy to allow residents to pay for energy efficiency improvements on their utility bills through distributed energy rebates used several examples from cooperatives.

Despite the pace of innovation on load management, electric cooperatives have been relatively slow to transition from coal-fired power. More than half of Great River Energy’s electricity came from coal last year, and Dairyland Power, another major power wholesaler for Minnesota co-ops, generated 70% of its energy from coal. Meanwhile, Xcel Energy, the state’s largest investor-owned utility, has already reduced coal to about 20% of its energy mix.

The transition to cleaner power for some co-ops has been slowed by long-term contracts with power suppliers that have locked them into dirty power. Others have also been stalled by management or boards that have been resistant to change. John Farrell, director of the Institute for Local Self-Reliance’s Energy Democracy program, said generalizing co-ops is difficult. 

“We’ve seen some co-ops that have got 75-year contracts for coal, that are invested in coal mines and using their newsletter to deny climate change,” he said. “Then you see a lot of them doing really amazing things like creating energy storage systems … and load balancing [programs], because they are unique and locally managed and can have that freedom to experiment without having to go through a regulatory process.”

Great River Energy, for its part, says it intends to reach 54% renewable generation by 2025, while some communities, like Frisco, Colorado, are targeting 100% clean electricity by specific dates. Its members recently voted to sell North Dakota’s largest coal plant, but the arrangement involves members continuing to buy power from the new owners for another decade.

The cooperative’s path to clean power could become clearer if its experimental iron-air battery project is successful. The project, the first of its kind in the country, is expected to be completed by 2023.

 

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Blizzard and Extreme Cold Hit Calgary and Alberta

Calgary Winter Storm and Extreme Cold delivers heavy snowfall, ECCC warnings, blowing snow, icy roads, and dangerous wind chill across southern Alberta, as a low-pressure system and northerly inflow fuel hazardous travel and frostbite risks.

 

Key Points

A severe Alberta storm with heavy snow, strong winds, ECCC warnings, dangerous wind chill, and high frostbite risk.

✅ ECCC extends snowfall and winter storm warnings regionwide.

✅ Wind chill -28 to -47; frostbite possible within 5-30 minutes.

✅ AMA rescues surge; non-essential travel strongly discouraged.

 

Calgary and much of southern Alberta faced a significant winter storm that brought heavy snowfall, strong winds, and dangerously low temperatures. Environment and Climate Change Canada (ECCC) issued extended and expanded snowfall and winter storm warnings as persistent precipitation streamed along the southern borders. The combination of a low-pressure system off the West Coast, where a B.C. 'bomb cyclone' had left tens of thousands without power, and a northerly inflow at the surface led to significant snow accumulations in a short period.

The storm resulted in poor driving conditions across much of southern Alberta, with snow-packed and icy roads, as well as limited visibility due to blowing snow. ECCC advised postponing non-essential travel until conditions improved. As of 10 a.m. on January 17, the 511 Alberta map showed poor driving conditions throughout the region, while B.C. electricity demand hit an all-time high amid the cold.

In Calgary, the city recorded four centimeters of snow on January 16, with an additional four centimeters expected on January 17. Temperatures remained far below seasonal averages until the end of the week, and Calgary electricity use tends to surge during such cold snaps according to Enmax, with improvements starting on Sunday.

The extreme cold posed significant risks, with wind chills of -28 to -39 capable of causing frostbite in 10 to 30 minutes, as a Quebec power demand record illustrated during the deep freeze. When wind chills dropped to -40 to -47, frostbite could occur in as little as five to 10 minutes. Residents were advised to watch for signs of frostbite, including color changes on fingers and toes, pain, numbness, tingling sensations, or swelling. Those most at risk included young children, older adults, people with chronic illnesses, individuals working or exercising outdoors, and those without proper shelter.

In response to the severe weather, the Alberta Motor Association (AMA) experienced a surge in calls for roadside assistance. Between January 12 and 14, there were approximately 32,000 calls, with about 22,000 of those requiring rescues between January 12 and 14. The high volume of requests led the AMA to temporarily cease providing wait time updates on their website due to the inability to provide accurate information, while debates over Alberta electricity prices also intensified during the cold.

The storm also had broader implications across Canada. Heavy snow was expected to fall across wide swaths of southern British Columbia and parts of southern Alberta, as BC Hydro's winter payment plan offered billing relief to customers during the stretch. Northern Alberta was under extreme cold warnings, with temperatures expected to dip to -40°C through the rest of the week. Similar extreme cold was forecast for southern Ontario, with wind chill values reaching -30°C.

As the storm progressed, conditions began to improve. The wind warning for central Alberta ended by January 17, though a blowing snow advisory remained in effect for the southeast corner of the province. Northwest winds gusting up to 90 km/h combined with falling snow continued to cause poor visibility in some areas, while California power outages and landslides were reported amid concurrent severe storms along the coast. Conditions were expected to improve by mid-morning.

In the aftermath of the storm, residents were reminded of the importance of preparedness and caution during severe winter weather. Staying informed through official weather advisories, adjusting travel plans, and taking necessary precautions can help mitigate the risks associated with such extreme conditions.

 

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Ireland goes 25 days without using coal to generate electricity

Ireland Coal-Free Electricity Record: EirGrid reports 25 days without coal on the all-island grid, as wind power, renewables, and natural gas dominated generation, cutting CO2 emissions, with Moneypoint sidelined by market competitiveness.

 

Key Points

It is a 25-day period when the grid used no coal, relying on gas and renewables to reduce CO2 emissions.

✅ 25 days coal-free between April 11 and May 7

✅ Gas 60%, renewables 30% of generation mix

✅ Eurostat: 6.8% drop in Ireland's CO2 emissions

 

The island of Ireland has gone a record length of time without using coal-fired electricity generation on its power system, Britain's week-long coal-free run providing a recent comparator, Eirgrid has confirmed.

The all-island grid operated without coal between April 11th and May 7th – a total of 25 days, it confirmed. This is the longest period of time the grid has operated without coal since the all-island electricity market was introduced in 2007, echoing Britain's record coal-free stretch seen recently.

Ireland’s largest generating station, Moneypoint in Co Clare, uses coal, with recent price spikes in Ireland fueling concerns about dispatchable capacity, as do some of the larger generation sites in Northern Ireland.

The analysis coincides with the European statistics agency, Eurostat publishing figures showing annual CO2 emissions in Ireland fell by 6.8 per cent last year; partly due to technical problems at Moneypoint.

Over the 25-day period, gas made up 60 per cent of the fuel mix, while renewable energy, mainly wind, accounted for 30 per cent, echoing UK wind surpassing coal in 2016 across the market. Coal-fired generation was available during this period but was not as competitive as other methods.

EirGrid group chief executive Mark Foley said this was “a really positive development” as coal was the most carbon intense of all electricity sources, with its share hitting record lows in the UK in recent years.

“We are acutely aware of the challenges facing the island in terms of meeting our greenhouse gas emission targets, mindful that low-carbon generation stalled in the UK in 2019, through the deployment of more renewable energy on the grid,” he added.

Last year 33 per cent of the island’s electricity came from renewable energy sources, German renewables surpassing coal and nuclear offering a parallel milestone, a new record. Coal accounted for 9 per cent of electricity generation, down from 12.9 per cent in 2017.

 

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