Ameresco Completes Fourth Renewable EPC Project with Hoosier Energy

Kemper County power plant costs and delays highlight lignite coal gasification, syngas production, carbon capture targets, and looming rate plans as Mississippi Power navigates Public Service Commission oversight and shareholder-ratepayer risk.

Key Points

Costs exceed $7.5B with repeated delays; rate impacts loom as syngas, lignite, and carbon capture systems mature.

✅ Estimate tops $7.5B; customers could fund about $4.3B

✅ Carbon capture target: 65% CO2 via syngas from lignite

✅ Rate plans pending before the Public Service Commission

A Mississippi utility on Monday delayed making proposals for how its customers should pay for an ever-more-expensive power plant, even as the estimated cost of the facility crossed $7.5 billion.

The Kemper County power plant will be tasked with mining lignite coal a few hundred yards away from the plant. That coal is moved through a process that will convert it to syngas. The syngas is then used to drive the energy output of the plant, and the resulting electricity is then moved into the grid, where transmission projects influence regional reliability and capacity.

Thomas Fanning, CEO of parent Southern Co., told shareholders in May that Mississippi Power would file rate plans for its Kemper County power plant this month. But still unable to operate the plant steadily enough to declare it finished, Mississippi Power punted, instead asking to hold rates level for 11 months to pay off costs that have already been approved by regulators.

Mississippi Power says it now hopes to reach commercial operation in June. The plant is more than three years behind schedule, with 10 delays announced in the past 18 months. It was originally supposed to cost $2.9 billion.

The company also said monday that it will have to replace troublesome parts of the facility much sooner than expected, including units that cool the synthetic gas produced from soft lignite coal by two gasifier units, plus ash handling systems in the gasifiers.

Kemper is designed to take synthetic gas, pipe it through a chemical plant to remove carbon dioxide and other chemicals, and then burn the gas in turbines to generate electricity. It’s designed to capture 65 percent of carbon dioxide from the coal, releasing only as much of the climate-warming gas as a typical natural gas plant. It’s a key effort nationally to maintain coal as a viable fuel source, even as coal unit retirements proceed in other states.

Mississippi Power raised its estimate of Kemper’s cost by $209.4 million, with shareholders absorbing $185.9 million, while ratepayers could be asked to pay $23.5 million. Overall, customers could be asked to pay $4.3 billion. Southern shareholders have agreed to absorb $3.1 billion, which has risen by $500 million since November.

The elected three-member Public Service Commission in 2015 allowed the company to raise rates on its 188,000 customers by $126 million a year. That paid for $840 million in Kemper work, which began generating electricity in 2014 using piped-in natural gas. Some items covered by that 15 percent rate increase will be paid off in coming months, but Mississippi Power now proposes to repay costs from regulatory proceedings earlier than originally projected.

In testimony filed with the Public Service Commission, Mississippi Power Chief Financial Officer Moses Fagin said that keeping rates level would reduce whiplash to customers when rates rise later to pay for Kemper, would pay off accumulated costs more quickly and would help the company wean itself off financial support from Southern Co. while maintaining credit ratings and positioning for a possible bond rating upgrade over time.

“Cash flow is important to the company in maintaining its current ratings and beginning to rebuild its credit strength on a more independent basis apart from the extraordinary parental support that has been required in recent years to maintain financial integrity,” Fagin testified.

Spokesman Jeff Shepard said Mississippi Power is still drawing up two rate plans — one requiring a sharp, immediate rate increase, and a “rate mitigation plan” that might cushion increases amid declining returns in coal markets. He said the company isn’t sure when it will file them. Fagin suggested the Public Service Commission set a new deadline of March 2, 2018.

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STM Electric Buses Montreal launch a zero-emission pilot with rapid charging stations on the 36 Monk line from Angrignon to Square Victoria, winter-tested for reliability and aligned with STM's 2025 fully electric fleet plan.

Key Points

STM's pilot deploys zero-emission buses with charging on the 36 Monk line, aiming for a fully electric fleet by 2025.

✅ 36 Monk route: Angrignon to Square Victoria with rapid charging

✅ Winter-tested performance; 15-25 km range per charge

✅ Quebec-built: motors Boucherville; buses Saint-Eustache

The first of three STM electric buses are rolling in Montreal, similar to initiatives with Vancouver electric buses elsewhere in Canada today.

The test batch is part of the city's plan to have a fully electric fleet by 2025, mirroring efforts such as St. Albert's electric buses in Alberta as well.

Over the next few weeks, one bus at a time will be put into circulation along the 36 Monk line, a rollout approach similar to Edmonton's first electric bus efforts in that city, going from Angrignon Metro station to Square Victoria Metro station. 

Rapid charging stations have been set up at both locations, a model seen in TTC's battery-electric rollout to support operations, so that batteries can be charged during the day between routes. The buses are also going to be fully charged at regular charging stations overnight.

Each bus can run from 15 to 25 kilometres on a single charge. The Monk line was chosen in part for its length, around 11 kilometres.

The STM has been testing the electric buses to make sure they can stand up to Montreal's harsh winters, drawing on lessons from peers such as the TTC electric bus fleet in Toronto, and now they are ready to take on passengers.

Keeping it local

The motors were designed in Boucherville, and the buses themselves were built in Saint-Eustache.

No timeline has been set for when the STM will be ready to roll out the whole fleet, but Montreal Mayor Denis Coderre, who was on hand at Tuesday's unveiling, told reporters he has confidence in the $11.9-million program.

"We start with three. Trust me, there will be more." said Coderre.

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Renewables Beat Brown Coal in Australia, as solar and wind surged to nearly 10,000 GWh, stabilizing the grid with battery storage during peak demand, after Hazelwood's closure, Green Energy Markets reported.

Key Points

It describes a 2017-18 summer when solar, wind, and storage generated more electricity than brown coal in Australia.

✅ Solar and wind hit nearly 10,000 GWh in summer 2017-18

✅ Brown coal fell to about 9,100 GWh after Hazelwood closure

✅ Batteries stabilized peak demand; Tesla responded in milliseconds

Renewable energy generated more electricity than brown coal during Australia’s summer for the first time in 2017-18, according to a new report by Green Energy Markets.

Continued growth in solar, as part of Australia's energy transition, pushed renewable generation in Australia to just under 10,000 gigawatt hours between December 2017 and February 2018. With the Hazelwood plant knocked out of the system last year, brown coal’s output in the same period was just over 9,100 GWh.

Renewables produced 40% more than gas over the period, and was exceeded only by black coal, reflecting trends seen in U.S. renewables surpassing coal in 2022.

#google#

The report, commissioned by GetUp, found renewables were generating particularly large amounts of electricity when it was most needed, producing 32% more than brown coal during summer between 11am and 7pm, when demand peaks.

Coal in decline: an energy industry on life support

Solar in particular was working to support the system, on average producing more than Hazelwood was capable of producing between 9am and 5pm.

A further 5,000 megawatts of large-scale renewables projects was under construction in February, supporting 17,445 jobs, while renewables became the second-most prevalent U.S. electricity source in 2020.

GetUp’s campaign director, Miriam Lyons, said the latest renewable energy index showed renewables were keeping the lights on while coal became increasingly unreliable, a trend echoed as renewables surpassed coal in the U.S. in recent years.

“Over summer renewables kept houses cool and lights on during peak demand times when people needed electricity most,” Lyons said. “Meanwhile dirty old coal plants are becoming increasingly unreliable in the heat.

“These ageing clunkers failed 36 times over summer.

“Clean energy rescued people from blackouts this summer. When the clapped-out Loy Yang coal plant tripped, South Australia’s giant Tesla battery reacted in milliseconds to keep the power on.

“It’s clear that a smart electricity grid based on a combination of renewable energy and storage is the best way to deliver clean, affordable energy for all Australians.”

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Alberta Electricity Rate Cap shields RRO customers with a 6.8 cents/kWh price ceiling, stabilizing power bills amid capacity market transition, using carbon tax funding to offset spikes and enhance consumer protection from volatility.

Key Points

A four-year 6.8 cents/kWh ceiling on Alberta's RRO power price, backed by carbon tax to stabilize bills.

✅ Applies to RRO customers from Jun 2017 to May 2021

✅ Caps rates at 6.8 cents/kWh; lower RRO still applies

✅ Funded by carbon tax when market prices exceed cap

The Alberta government introduced a bill Tuesday, part of new electricity rules that will allow it to place a cap on regulated electricity rates for the next four years.

The move to cap consumer power rates at a maximum of 6.8 cents per kilowatt-hour for four years was announced in November 2016 by Premier Rachel Notley, although it was later scrapped by the UCP during a subsequent policy shift.

The cap is intended to protect consumers from price fluctuations from June 1, 2017, to May 31, 2021, as the province moves from a deregulated to a capacity power market amid a power market overhaul that is underway.

The price ceiling will apply to people with a regulated rate option. If the RRO is below 6.8 cents, they will still pay the lower rate.

The government isn't forecasting price fluctuations above 6.8 cents in this four-year period. If the price goes above that amount, funding would come from the carbon tax if required.

Funding may come from carbon tax

"We're taking a number of steps to keep prices low," said Energy Minister Marg McCuaig-Boyd. "But in the event that prices were to spike, the cap would automatically prevent the energy rate from going over 6.8 cents to give Albertans even more peace of mind." 

The government isn't forecasting price fluctuations above 6.8 cents in this four-year period. If the price goes above that amount, funding would come from the carbon tax.

McCuaig-Boyd said this would be an appropriate use for the carbon tax as the cap helps Albertans move to a greener energy system and change how the province produces and pays for electricity without relying as much on coal-fired electricity. 

The government estimates the program will cost $10 million a month for each cent the rate goes above 6.8 cents per kilowatt-hour. If rates remain below that amount, the program may not cost anything.

Wildrose electricity and renewables critic Don MacInytre said the move shows the government expects retail electricity rates will double over the next four years. 

MacIntyre argued a rate cap simply shifts increasing electricity costs away from consumers to the Alberta government. But ultimately everyone pays. 

"It's simply a shift of a burden from the ratepayer to the taxpayer, which is essentially the same person," he said. 

The City of Medicine Hat runs its own electrical system without a regulated rate option. The government will talk with the city to see if it is interested in taking part in the price cap protection.

About 60 per cent of eligible Albertans or one million households use the regulated rate option in their electricity contracts.

The current regulated rate option averages less than three cents per kilowatt-hour.

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Toronto EV Discovery Centre offers hands-on EV education, on-site test drives, and guidance on Ontario incentives, rebates, charging, and dealerships, helping drivers switch to electric vehicles and cut emissions through provincial climate programs.

Key Points

A public hub in Toronto for EV education, test drives, and guidance on Ontario incentives, rebates, and charging options.

✅ Free entry; neutral info on EV models and charging.

✅ On-site test drives; referrals to local dealerships.

✅ Backed by Ontario's cap-and-trade, utilities, and partners.

A centre where people can learn about electric vehicles and take them for a test drive has opened in Toronto, as similar EV events in Regina highlight growing public interest.

Ontario's Environment Minister Glen Murray says the Plug'n Drive Electric Vehicle Discovery Centre is considered the first of its kind and his government has pitched in $1 million to support it, alongside efforts to expand charging stations across Ontario.

Ontario's Environment Minister Glen Murray helps cut the ribbon on the first ever electric vehicle discovery centre. (CBC News)

Murray says the goal of the centre is to convince people to switch to electric vehicles in order to fight climate change, a topic gaining momentum in southern Alberta as well.

Visitors to the centre learn about how electric vehicles work and about Ontario government subsidies and rebates for electric car owners, as well as the status of the provincial charging network and infrastructure.

Visitors can test-drive vehicles from different companies and those who see something they like will receive a referral to an electric car dealership in their area.

The province hopes to have electric vehicles make up five per cent of all new vehicles sold by 2020. (Oliver Walters/CBC)

The Ontario government's Climate Change Action Plan includes a goal to have electric vehicles make up five per cent of all new vehicles sold by 2020, amid debate over whether the next wave will run on clean power in Ontario, and the discovery centre is part of that plan.

The centre is free for visitors. It's a public-private partnership funded from the provincial government's cap-and-trade revenue, with other funding from TD Bank Group, Ontario Power Generation, Power Workers' Union, Toronto Hydro and Bruce Power.

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Vehicle-to-Grid (V2G) enables bidirectional charging, letting EV batteries supply smart grid services to large buildings, support renewable energy integration, reduce battery degradation, and optimize demand response for efficient, resilient power management.

Key Points

Vehicle-to-Grid (V2G) is bidirectional EV charging that feeds the grid and buildings while protecting battery health.

✅ Uses idle EVs to power buildings and support renewables

✅ Smart algorithms minimize lithium-ion battery degradation

✅ Provides grid services, demand response, and peak shaving

Stored energy from electric vehicles (EVs) can be used to power large buildings -- creating new possibilities for the future of smart, renewable energy -- thanks to ground-breaking battery research from WMG at the University of Warwick.

Dr Kotub Uddin, with colleagues from WMG's Energy and Electrical Systems group and Jaguar Land Rover, has demonstrated that vehicle-to-grid (V2G) technology can be intelligently utilised to take enough energy from idle EV batteries to be pumped into the grid and power buildings -- without damaging the batteries.

This new research into the potentials of V2G shows that it could actually improve vehicle battery life by around ten percent over a year.

For two years, Dr Uddin's team analysed some of the world's most advanced lithium ion batteries used in commercially available EVs -- and created one of the most accurate battery degradation models existing in the public domain -- to predict battery capacity and power fade over time, under various ageing acceleration factors -- including temperature, state of charge, current and depth of discharge.

Using this validated degradation model, Dr Uddin developed a 'smart grid' algorithm, which supports grid coordination and intelligently calculates how much energy a vehicle requires to carry out daily journeys, and -- crucially -- how much energy can be taken from its battery without negatively affecting it, or even improving its longevity.

The researchers used their 'smart grid' algorithm to see if they could power WMG's International Digital Laboratory -- a large, busy building which contains a 100-seater auditorium, two electrical laboratories, teaching laboratories, meeting rooms, and houses approximately 360 staff -- with vehicle-to-building charging from EVs parked on the University of Warwick campus.

They worked out that the number of EVs parked on the campus (around 2.1% of cars, in line with the UK market share of EVs) could spare the energy to power this building, acting as capacity on wheels for electricity networks -- and that in doing so, capacity fade in participant EV batteries would be reduced by up to 9.1%, and power fade by up to 12.1% over a year.

It has previously been thought that extracting energy from EVs with V2G technology causes their lithium ion batteries to degrade more rapidly.

Dr Uddin's group (along with collaborators from Jaguar Land Rover) have proved, however, that battery degradation is more complex -- and this complexity, in operation, can be exploited to improve a battery's lifetime.

Given that battery degradation is dependent on calendar age, capacity throughput, temperature, state of charge, current and depth of discharge, V2G is an effective tool that can be used to optimise a battery's conditions such that degradation is minimised. Hence, taking excess energy from an idle EV to power the grid actually keeps the battery healthier for longer.

Dr Uddin commented on the research:

"These findings reinforce the attractiveness of vehicle-to-grid technologies to automotive Original Equipment Manufacturers: not only is vehicle-to-grid an effective solution for grid support -- and subsequently a tidy revenue stream -- but we have shown that there is a real possibility of extending the lifetime of traction batteries in tandem.

"The results are also appealing to policy makers interested in grid decarbonisation and addressing grid challenges from rising EVs across power systems."

The research, 'On the possibility of extending the lifetime of lithium-ion batteries through optimal V2G facilitated by an integrated vehicle and smart-grid system' is published in Energy.

It was funded by the Engineering and Physical Sciences Research Council and the WMG centre High Value Manufacturing Catapult, in partnership with Jaguar Land Rover.

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