Solar a natural fit for Calgary

By Calgary Sun


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There are bright ideas and then there are ideas that just make sense.

Calgary is about to make it easier for residents to put solar panels on their homes, clearing the way to an energy source that's clean, renewable and well-suited to this sun-filled city.

On August 21, Calgary's planning commission approved a new policy to remove the need for development permits to install solar panels.

The change needs to be approved by council this fall, but shows all signs of going ahead.

Tim Schulhauser, a photo-voltaic technician with solar energy company Sedmek Inc., says it could help streamline the solar installation process.

"We've had quite a few projects delayed this summer because of development permits," he says, adding the permits can cost up to $3,000 and take weeks to procure.

"This would bring down the cost and speed things along."

The city's action is well-timed, as the solar power industry is currently growing by 30% to 40% a year and breaking into new technologies that will soon make solar panels lighter, cheaper and more efficient.

It's also just as the province has passed legislation requiring energy companies to pay residents for the renewable energy they feed back into the grid.

Until now, some companies, such as Enmax, have paid customers for their surplus power, but others have simply taken the electricity without offering compensation.

It's about time Calgarians who create green energy get rewarded.

Until now, it seems they've just been getting headaches.

In addition to the expense of installing solar power – anywhere from $10,000 to $100,000-plus, depending on the system – eco-minded homeowners have to do enormous amounts of hoop-jumping and red tape-dodging to do their good deed.

Perhaps this is why solar power has been slow to catch on here, in comparison to Europe and parts of the U.S., where government incentives and paybacks have helped boost it into the mainstream.

Ontario, for example, has begun buying solar power from users for $0.42 per kilowatt hour, as opposed to the $0.13 rate for regular grid power.

This means an efficient solar-powered household – pumping surplus solar energy into the grid by day and using small amounts of lower-priced grid energy at night – can actually turn an annual profit of $2,000 or more.

Policies like this are causing surges in solar power popularity and getting the business world on side.

Just this week, investors gave two thin film solar companies major cash infusions.

California's Nonosolar pulled in $300 million, while Colorado's AVA Solar brought in $104 million.

But how long will it be before the average person can afford to get their electricity from the sun?

The Economist recently predicted the price of solar technology would remain high until the price of silicon falls.

"Happily, it seems likely to do so soon," the magazine reported, noting silicon output for solar uses could nearly double next year.

Based on information from New Energy Finance, a research firm, silicon prices should fall 40% next year, then over 70% by 2015, as new sources come online.

As it is, U.S. Department of Energy reports the cost of making a one-watt solar cell has gone from $50 two decades ago to under $3 today.

Combine this with the rising price of conventional energy, Schulhauser says, and it's only a matter of time before solar power is on par – or cheaper – than electricity from the grid.

"Grid parity in Europe is expected to be in about five years," he says. "It will take longer here, where our electricity is less expensive, but it's not that far down the road."

And how much power can solar technology actually supply? According to the U.S. energy department, the solar energy in a 100-sq.-mile area of Nevada could supply all the energy needs of the United States – a country with 10 times Canada's population.

It seems solar energy is going to be increasingly more relevant as time goes on.

Here in Calgary, where there's sun about 333 days of the year, according to Environment Canada, we're in a great position to take advantage of it.

It's heartening to see our city offering some modest encouragement to the trailblazers who are championing this rising technology.

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Hurricane Michael by the numbers: 32 dead, 1.6 million homes, businesses without power

Hurricane Michael Statistics track catastrophic wind speed, storm surge, rainfall totals, power outages, evacuations, and fatalities across Florida and the Southeast, detailing Category 4 intensity, Saffir-Simpson scale impacts, and emergency response resources.

 

Key Points

Hurricane Michael statistics detail wind speed, storm surge, rainfall, outages, and deaths from Category 4 landfall.

✅ 155 mph landfall winds; 14 ft storm surge; 12 in rainfall max

✅ 1.6M without power; 30,000 restoring crews; 6 states emergency

✅ 325k ordered evacuations; 32 deaths; FEMA and Guard deployed

 

Hurricane Michael, a historic Category 4 storm, struck the Florida Panhandle early Wednesday afternoon, unleashing heavy rain, high winds and a devastating storm surge.

 

Here is a look at the dangerous storm by the numbers:

155 mph: Wind speed -- nearly the highest possible for a Category 4 hurricane -- with which Michael made landfall near Mexico Beach and Panama City. A hurricane with 157 mph or higher is a Category 5, the strongest on the Saffir-Simpson hurricane wind scale.

129 mph: Peak wind gust reported Wednesday at Tyndall Air Force Base, which is about 12 miles southeast of Panama City, Florida.

32: Number of storm-related deaths attributed to Michael thus far, including an 11-year-old girl who local officials say was killed when part of a metal carport crashed into her family's mobile home in Lake Seminole, Georgia, and a 38-year-old man who was killed when a tree fell onto his moving car in Statesville, North Carolina.

 

Waves take over a house as Hurricane Michael comes ashore in Alligator Point, Fla., Oct. 10, 2018.

14 feet: Maximum height forecast for the storm surge when Michael's strong winds pushed the ocean water onto land. A storm surge just over 9 feet was reported Wednesday in Apalachicola, Florida.

12 inches: Isolated maximum amount of rain that Michael was expected to dump across the Florida Panhandle and the state's Big Bend region, as well as in southeast Alabama and parts of southwest and central Georgia.

9 inches: Maximum amount of rain that Michael could bring to isolated areas from Virginia to North Carolina.

1.6 million: Number of homes and businesses without power in Florida, Alabama, Georgia, South Carolina, North Carolina and Virginia as of Friday morning, a reminder that extended outages can persist after major disasters.

30,000: Number of workers mobilized from across the country to help restore power, underscoring the risks of field repairs such as line crew injuries during recovery.

6: Number of states that had emergency declarations in anticipation of Michael: Florida, Alabama, Georgia, South Carolina, North Carolina and Virginia.

325,000: Estimated number of people in the storm's path who were told to evacuate by local authorities.

6,000: Approximate number of people who stayed in the roughly 80 shelters across Florida, Alabama, Georgia, South Carolina and North Carolina on Wednesday night, while those sheltering at home were urged to avoid overheated power strips that can spark fires.

3,000: Number of personnel the Federal Emergency Management Agency deployed ahead of landfall, while utilities prepared on-site staffing plans to maintain operations during widespread disruptions.

35: Number of counties in Florida, of the state's 67, where Gov. Rick Scott declared a state of emergency prior to landfall, and grid reliability warnings often underscore systemic risks during national emergencies.

3,500: Number of Florida National Guard troops activated for pre-landfall coordination and planning, with an emphasis on high water and search-and-rescue operations.

600: Number of Florida state troopers assigned to the Panhandle and Big Bend region to assist with response and recovery efforts, including public reminders about downed line safety in affected communities.

500: Number of disaster relief workers that the American Red Cross was sending to affected areas in the Sunshine State.

200: Approximate number of patients being evacuated from at least two hospitals in Florida due to damage from the hurricane, highlighting how critical facilities depend on staff who have raised workforce safety concerns during other crises. Bay Medical Center Sacred Heart in Panama City said in a statement Thursday that its facility was damaged during the storm and thus is transferring more than 200 patients, including 39 who are critically ill, to regional hospitals. Gulf Coast Regional Medical Center, also in Panama City, announced in a statement Thursday that it's evacuating its roughly approximately patients, starting with the most critically ill, "because of the infrastructure challenges in our community."

 

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Egypt Plans Power Link to Saudis in $1.6 Billion Project

Egypt-Saudi Electricity Interconnection enables cross-border power trading, 3,000 MW capacity, and peak-demand balancing across the Middle East, boosting grid stability, reliability, and energy security through an advanced electricity network, interconnector infrastructure, and GCC grid integration.

 

Key Points

A 3,000 MW grid link letting Egypt and Saudi Arabia trade power, balance peak demand, and boost regional reliability.

✅ $1.6B project; Egypt invests ~$600M; 2-year construction timeline

✅ 3,000 MW capacity; peak-load shifting; cross-border reliability

✅ Links GCC grid; complements Jordan and Libya interconnectors

 

Egypt will connect its electricity network to Saudi Arabia, joining a system in the Middle East that has allowed neighbors to share power, similar to the Scotland-England subsea project that will bring renewable power south.

The link will cost about $1.6 billion, with Egypt paying about $600 million, Egypt’s Electricity Minister Mohamed Shaker said Monday at a conference in Cairo, as the country pursues a smart grid transformation to modernize its network. Contracts to build the network will be signed in March or April, and construction is expected to take about two years, he said. In times of surplus, Egypt can export electricity and then import power during shortages.

"It will enable us to benefit from the difference in peak consumption,” Shaker said. “The reliability of the network will also increase.”

Transmissions of electricity across borders in the Gulf became possible in 2009, when a power grid connected Qatar, Kuwait, Saudi Arabia and Bahrain, a dynamic also seen when Ukraine joined Europe's grid under emergency conditions. The aim of the grid is to ensure that member countries of the Gulf Cooperation Council can import power in an emergency. Egypt, which is not in the GCC, may have been able to avert an electricity shortage it suffered in 2014 if the link with Saudi Arabia existed at the time, Shaker said.

The link with Saudi Arabia should have a capacity of 3,000 megawatts, he said. Egypt has a 450-megawatt link with Jordan and one with Libya at 200 megawatts, the minister said. Egypt will seek to use its strategic location to connect power grids in Asia, where the Philippines power grid efforts are raising standards, and elsewhere in Africa, he said.

In 2009, a power grid linked Qatar, Kuwait, Saudi Arabia and Bahrain, allowing the GCC states to transmit electricity across borders, much like proposals for a western Canadian grid that aim to improve regional reliability. 

 

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Nonstop Records For U.S. Natural-Gas-Based Electricity

U.S. Natural Gas Power Demand is surging for electricity generation amid summer heat, with ERCOT, Texas grid reserves tight, EIA reporting coal and nuclear retirements, renewables intermittency, and pipeline expansions supporting combined-cycle capacity and prices.

 

Key Points

It is rising use of natural gas for power, driven by summer heat, plant retirements, and new combined-cycle capacity.

✅ ERCOT reserve margin 9%, below 14% target in Texas

✅ Gas share of U.S. power near 40-43% this summer

✅ Coal and nuclear retirements shift capacity to combined cycle

 

As the hot months linger, it will be natural gas that is leaned on most to supply the electricity that we need to run our air conditioning loads on the grid and keep us cool.

And this is surely a great and important thing: "Heat causes most weather-related deaths, National Weather Service says."

Generally, U.S. gas demand for power in summer is 35-40% higher than what it was five years ago, with so much more coming (see Figure).

The good news is regions across the country are expected to have plenty of reserves to keep up with power demand.

The only exception is ERCOT, covering 90% of the electric load in Texas, where a 9% reserve margin is expected, below the desired 14%.

Last summer, however, ERCOT’s reserve margin also was below the desired level, yet the grid operator maintained system reliability with no load curtailments.

Simply put, other states are very lucky that Texas has been able to maintain gas at 50% of its generation, despite being more than justified to drastically increase that.

At about 1,600 Bcf per year, the flatness of gas for power demand in Texas since 2000 has been truly remarkable, especially since Lone Star State production is up 50% since then.

Increasingly, other U.S. states (and even countries) are wanting to import huge amounts of gas from Texas, a state that yields over 25% of all U.S. output.

Yet if Texas justifiably ever wants to utilize more of its own gas, others would be significantly impacted.

At ~480 TWh per year, if Texas was a country, it would be 9th globally for power use, even ahead of Brazil, a fast growing economy with 212 million people, and France, a developed economy with 68 million people.

In the near-term, this explains why a sweltering prolonged heat wave in July in Texas, with a hot Houston summer setting new electricity records, is the critical factor that could push up still very low gas prices.

But for California, our second highest gas using state, above-average snowpack should provide a stronger hydropower for this summer season relative to 2018.

Combined, Texas and California consume about 25% of U.S. gas, with Texas' use double that of California.

 

Across the U.S., gas could supply a record 40-43% of U.S. electricity this summer even as the EIA expects solar and wind to be larger sources of generation across the mix

Our gas used for power has increased 35-40% over the past five years, and January power generation also jumped on the year, highlighting broad momentum.

Our gas used for power has increased 35-40% over the past five years. DATA SOURCE: EIA; JTC

Indeed, U.S. natural gas for electricity has continued to soar, even as overall electricity consumption has trended lower in some years, at nearly 10,700 Bcf last year, a 16% rise from 2017 and easily the highest ever.

Gas is expected to supply 37% of U.S. power this year, even as coal-fired generation saw a brief uptick in 2021 in EIA data, versus 27% just five years ago (see Figure).

Capacity wise, gas is sure to continue to surge its share 45% share of the U.S. power system.

"More than 60% of electric generating capacity installed in 2018 was fueled by natural gas."

We know that natural gas will continue to be the go-to power source: coal and nuclear plants are retiring, and while growing, wind and solar are too intermittent, geography limited, and transmission short to compensate like natural gas can.

"U.S. coal power capacity has fallen by a third since 2010," and last year "16 gigawatts (16,000 MW) of U.S. coal-fired power plants retired."

This year, some 2,000 MW of coal was retired in February alone, with 7,420 MW expected to be closed in 2019.

Ditto for nuclear.

Nuclear retirements this year include Pilgrim, Massachusetts’s only nuclear plant, and Three Mile Island in Pennsylvania.

This will take a combined ~1,600 MW of nuclear capacity offline.

Another 2,500 MW and 4,300 MW of nuclear are expected to be leaving the U.S. power system in 2020 and 2021, respectively.

As more nuclear plants close, EIA projects that net electricity generation from U.S. nuclear power reactors will fall by 17% by 2025.

From 2019-2025 alone, EIA expects U.S. coal capacity to plummet nearly 25% to 176,000 MW, with nuclear falling 15% to 83,000 MW.

In contrast, new combined cycle gas plants will grow capacity almost 30% to around 310,000 MW.

Lower and lower projected commodity prices for gas encourage this immense gas build-out, not to mention non-stop increases in efficiency for gas-based units.

Remember that these are official U.S. Department of Energy estimates, not coming from the industry itself.

In other words, our Department of Energy concludes that gas is the future.

Our hotter and hotter summers are therefore more and more becoming: "summers for natural gas"

Ultimately, this shows why the anti-pipeline movement is so dangerous.

"Affordable Energy Coalition Highlights Ripple Effect of Natural Gas Moratorium."

In April, President Trump signed two executive orders to promote energy infrastructure by directing federal agencies to remove bottlenecks for gas transport into the Northeast in particular, where New England oil-fired generation has spiked, and to streamline federal reviews of border-crossing pipelines and other infrastructure.

Builders, however, are not relying on outside help: all they know is that more U.S. gas demand is a constant, so more infrastructure is mandatory.

They are moving forward diligently: for example, there are now some 27 pipelines worth $33 billion already in the works in Appalachia.

 

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India to Ration Coal Supplies as Electricity Demand Surges

India Coal Supply Rationing redirects shipments from high-inventory power plants to stations facing shortages as electricity demand surges, inventories fall, and outages persist; Coal India, NTPC imports, and smaller mines bolster domestic supply.

 

Key Points

A temporary policy redirecting coal from high-stock plants to shortage-hit plants amid rising demand

✅ Shipments halted 1 week to plants with >14 days coal stock

✅ Smaller mines asked to raise output; NTPC to import 270,000 tons

✅ Outages at Adani and Tata Mundra units pressure domestic supply

 

India will ration coal supplies to power plants with high inventories to direct more shipments to stations battling shortages, even as shortages ease in some regions, as surging demand outstrips production.

Supplies to plants with more than two weeks’ coal inventory will be halted for a week, a team headed by federal Coal Secretary Alok Kumar decided on Saturday, the Power Ministry said in a statement. The government has also requested smaller mines to raise output to supplement shipments from state miner Coal India Ltd., and is taking steps to get nuclear back on track to diversify the energy mix.

A jump in electricity consumption spurred by a reviving economy and an extended summer, after an earlier steep demand decline in India, is driving demand for coal, which helps produce about 70% of the nation’s electricity. The surge in demand complicates India’s clean-energy transition efforts amid solar supply headwinds that cloud near-term alternatives, and may bolster arguments favoring the country’s dependence on coal to fuel economic growth.

“There’s no doubt India will continue to need coal for stable power for years,” said Rupesh Sankhe, vice president at Elara Capital India Pvt. in Mumbai. “Plants that meet environmental standards and are able to produce power efficiently will see utilization rising, but I doubt we’re going to have many new coal plants.”  

Coal stockpiles at the country’s power plants had fallen to 14.7 million tons as of Aug. 24, tumbling 62% from a year earlier, according to the latest data from the Central Electricity Authority. More than 88 gigawatts of generation plants, about half the capacity monitored by the power ministry, had inventories of six days or less as of that date, the data show. Power demand jumped 10.5% in July from a year earlier, even as global electricity use dipped 15% during the pandemic, according to the government.
Outages at some large plants that run on imported coal have increased the burden on those that burn domestic supplies, aiding shortfalls.

Adani Power Ltd. had almost 2 gigawatts of capacity in outage at its Mundra plant in Gujarat at the start of the week, while Tata Power Co. Ltd. had shut 80% of its 4-gigawatt plant in the same town for maintenance, power ministry data show.

NTPC Ltd., the largest power generator, will import the 270,000 tons of coal it left out from contracts placed earlier to mitigate the fuel shortage, reflecting higher imported coal volumes this fiscal, the power ministry said in a separate statement.

 

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Quebec premier inaugurates La Romaine hydroelectric complex

La Romaine Hydroelectric Complex anchors Quebec's hydropower expansion, showcasing Hydro-Québec ingenuity, clean energy, electrification, and grid capacity gains along the North Shore's Romaine River to power industry and nearly 470,000 homes.

 

Key Points

A four-station, $7.4B hydro project on Quebec's Romaine River producing 8 TWh a year for electrification and industry.

✅ Generates 8 TWh yearly, powering about 470,000 homes

✅ Largest Quebec hydro build since James Bay project

✅ Key to clean energy, grid capacity, and electrification

 

Quebec Premier François Legault has inaugurated the la Romaine hydroelectric complex on the province's North Shore.

The newly inaugurated Romaine hydroelectric complex could serve as a model for future projects, such as the Carillon Generating Station investment now planned in the province, Legault said.

"It brings me a lot of pride. It is truly the symbol of Quebec ingenuity," he said as he opened the vast power plant.

Legault was accompanied at today's event by Jean Charest, who was Quebec premier when construction began in 2009, as well as Hydro-Québec president and CEO Michael Sabia. 

La Romaine is comprised of four power stations and is the largest hydro project constructed in the province since the Robert Bourassa generation facility, which was commissioned in 1979. It is the biggest hydro installation since the James Bay project, bolstering Hydro-Québec's hydropower capacity across the grid today.

The construction work for Romaine-4 was supposed to finish in 2020, but it was delayed the COVID-19 pandemic, the death of four workers due to security flaws and soil decomposition problems. 

The $7.4-billion la Romaine complex can produce eight terawatt hours of electricity per year, enough to power nearly 470,000 homes.

It generates its power from the Romaine River, located north of Havre-St-Pierre, Que., near the Labrador border, where long-standing Newfoundland and Labrador tensions over Quebec's projects sometimes resurface today.

Legault said that Quebec still doesn't have enough electricity to meet demand from industry, including recent allocations of electricity for industrial projects across the province, and Quebecers need to consider more ways to boost the province's ability to power future projects. The premier has said previously that demand is expected to surge by an additional 100 terawatt-hours by 2050 — half the current annual output of the provincially owned utility.

Legault's environmental plan of reducing greenhouse gases and achieving carbon neutrality by 2050 hinges on increased electrification and a strategy to wean off fossil fuels provincewide, so the electricity needs for transport and industry will be massive.

An updated strategic plan from Hydro-Quebec will be presented in November outlining those needs, president and CEO Michael Sabia told reporters on Thursday, after recent deals with NB Power underscored interprovincial demand.

Legault said the report will trigger a broader debate on energy transition and how the province can be a leader in the green economy. He said he wasn't ruling out any potential power sources — except for a return to nuclear power at this stage.

 

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Gov. Greg Abbott touts Texas power grid's readiness heading into fall, election season

ERCOT Texas Fall Grid Forecast outlines ample power supply, planned maintenance outages, and grid reliability, citing PUC oversight and Gov. Abbott's remarks, with seasonal assessment noting mild demand yet climate risks and conservation alerts.

 

Key Points

ERCOT's seasonal outlook for Texas on fall power supply, outages, and reliability expectations under PUC oversight.

✅ Projects sufficient supply in October and November

✅ Many plants scheduled offline for maintenance

✅ Notes PUC oversight and Abbott's confidence

 

Gov. Greg Abbott said Tuesday that the Texas power grid is prepared for the fall months and referenced a new seasonal forecast by the state’s grid operator, which typically does not draw much attention to its fall and spring grid assessments because of the more mild temperatures during those seasons.

Tuesday’s new forecast by the Electric Reliability Council of Texas showed that there should be plenty of power supply to meet demand in October and November. It also showed that many Texas power plants are scheduled to be offline this fall for maintenance work. Texas power plants usually plan to go down in the fall and spring for repairs to improve reliability ahead of the more extreme temperatures in winter and summer, when Texans crank up their heat and air conditioning and raise demand for power.

ERCOT for at least a decade announced its seasonal forecasts, but did not do so on Tuesday. The grid operator stopped announcing the reports after the 2021 winter storm event. A spokesperson for the grid operator, which posted the report to its website midday without notifying the public or power industry stakeholders, said there were no plans to discuss the latest forecast and referred questions about it to the Public Utility Commission, which oversees ERCOT. Abbott appoints the board of the PUC.

Abbott on Tuesday expressed his confidence about the grid in a news release, which included photos of the governor sitting at a table with incoming ERCOT CEO Pablo Vegas, outgoing interim CEO Brad Jones and Public Utility Commission Chair Peter Lake.

“The State of Texas continues to monitor the reliability of our electric grid, and I thank ERCOT and PUC for their hard work to implement bipartisan reforms we passed last year and for their proactive leadership to ensure our grid is stronger than ever before,” Abbott said in the release.

Abbott has not previously shared or called attention to ERCOT’s forecasts as he did on Tuesday.

Up for reelection this fall, Abbott has faced continued criticism, including from the Sierra Club over his handling of the 2021 deadly power grid disaster, when extended freezing temperatures shut down natural gas facilities and power plants, which rely on each other to keep electricity flowing. The resulting blackouts left millions of Texans without power for days in the cold, and hundreds of people died.

ERCOT’s forecasts for fall and spring are typically the least worrisome seasonal forecasts, energy experts said, because temperatures are usually milder in between summer and winter, even as ERCOT has issued an RFP to procure winter capacity to address shortages, so demand for power usually does not skyrocket like it does during extreme temperatures.

But they’ve warned that climate change could potentially lead to more extreme temperatures during times when Texas hasn’t experienced such weather in the past. For example, in early May six power plants unexpectedly broke down when a spring heat wave drove power demand up and highlighted broader heat-related blackout risks across the grid. ERCOT asked Texans to conserve electricity at home at the time.

Abbott released the seasonal report at a time when he has asserted unprecedented control over ERCOT. Although he had no formal role in ERCOT’s search for a new permanent CEO, he put a stranglehold on the process, The Texas Tribune previously reported. Since the winter storm, Abbott’s office has also dictated what information about the power grid ERCOT has released to the public.

 

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