Fortis BC awards incentive for reducing energy consumption

By FortisBC


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Quesnel, BC – Quesnel River Pulp, a division of West Fraser, has made significant commitments to reducing its energy consumption. For those achievements, the mill has received a $250,000 incentive from FortisBC, which could grow to $1 million over the next three years. The pulp mill is the first participant in FortisBC’s Industrial Technology Retrofit Program, which offers monetary incentives to industrial natural gas customers in exchange for energy efficiency improvement projects.

“Incentives like this make significant commitments to energy reduction for industrial customers viable,” said Doug Stout, vice president of energy solutions and external relations for FortisBC. “We’re thankful for the opportunity to collaborate with West Fraser, and we look forward to working with industrial customers to assist in improving the efficiency of their operations.”

By undertaking the program, Quesnel River Pulp will receive funding up to 50 per cent of the cost of its energy efficient upgrades, to a maximum of $1 million. The incentive from FortisBC covers the costs of the project, including new equipment, installation and old equipment removal, including taxes. With the aid of the incentive, Quesnel River Pulp may be able to reduce the payback period on its equipment investment within a few years.

“The incentive from FortisBC offers significant value to our operation. Our plant process uses a lot of energy, and this partnership with FortisBC has allowed us to make smart decisions with respect to equipment upgrades,” said Keith Carter, general manager of Quesnel River Pulp. “These upgrades reduce our dependence on fossil fuel energy sources and create savings which are critical to the competitiveness of our business.”

A major component contributing to the efficiency was the replacement of heat exchangers with more efficient spiral-wound units. The new units reduce the amount of natural gas required for drying the pulp. The pulp mill will save approximately 70,000 gigajoules GJs of natural gas annually, the equivalent amount of natural gas consumed by all customers in the city of Vancouver over the course of two days. The savings will also amount to an estimated 3,317 tonnes of greenhouse gas emissions, the equivalent of taking 650 cars off the road per year.

The Industrial technology Retrofit Program is available for FortisBC industrial customers who use more than 10,000 GJs for process heating. Depending on consumption, participants have the option of receiving up to 75 per cent of the cost of implementing new equipment up to a maximum of $375,000, or receiving up to 50 per cent of the cost to a maximum of $1 million. Industrial customers can learn if this program is right for them by contacting FortisBC at 1-888-224-2710 or visiting their website at fortisbc.com/industry.

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N.B. Power hits pause on large new electricity customers during crypto review

N.B. Power Crypto Mining Moratorium underscores electricity demand risks from bitcoin mining, straining the energy grid and industrial load capacity in New Brunswick, as a cabinet order prioritizes grid reliability, utility planning, and allocation.

 

Key Points

Official pause on new large-scale crypto mining to protect N.B. Power grid capacity, stability, and reliable supply.

✅ Cabinet order halts new large-scale crypto load requests

✅ Review targets grid reliability, planning, and capacity

✅ Non-crypto industrial customers exempt from prolonged pause

 

N.B. Power says a freeze on servicing new, large-scale industrial customers in the province remains in place over concerns that the cryptocurrency sector's heavy electricity use could be more than the utility can handle.

The Higgs government quietly endorsed the moratorium in a cabinet order in March 2022 and ordered a review of how the sector might affect the reliable electricity supply and broader electricity future planning in the province.

The cabinet order, filed with the Energy and Utilities Board, said N.B. Power had "policy, technical and operational concerns about [its] capacity to service the anticipated additional load demand" from energy-intensive customers such as crypto mines.

It said the utility had received "several new large-scale, short-notice service requests" to supply electricity to crypto mining companies that could put "significant pressure" on the existing electricity supply.

The order, signed by Premier Blaine Higgs, said non-crypto companies shouldn't be subject to the pause for any longer than required for the review, amid shifts in regional plans like the Atlantic Loop that are altering timelines. Ws.

The freeze was ordered months after Taal Distributed Information Technologies Inc. announced plans to establish a 50-megawatt bitcoin mining operation and transaction processing facility in Grand Falls.

A town official said this week that the deal never went ahead.

24 hours a day
The Taal facility would have joined a 70-megawatt bitcoin mine in Grand Falls operated by Hive Blockchain Technologies.

Hive's Bitcoin mine comprises four large warehouses containing thousands of computers running 24 hours a day to earn cryptocurrency units.

The combined annual electricity consumption of the two mines would exceed what could be produced by the small modular nuclear reactor being designed by ARC Clean Energy Canada of Saint John, even as Nova Scotia advances efforts to harness the Bay of Fundy's powerful tides for clean power.

Put another way, the two mines would gobble up more than three months' electricity from N.B. Power's coal-fired Belledune generating station under current operations.

 

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Idaho gets vast majority of electricity from renewables, almost half from hydropower

Idaho Renewable Energy 2018 saw over 80% in-state utility-scale power from hydropower, wind, solar, biomass, and geothermal, per EIA, with imports declining as Snake River Plain resources and Hells Canyon hydro lead.

 

Key Points

Idaho produced over 80% in-state power from renewables in 2018, led by hydropower, wind, solar, and biomass.

✅ Hydropower supplies about half of capacity; Hells Canyon leads.

✅ Wind provides nearly 20% of capacity along the Snake River Plain.

✅ Utility-scale solar surged since 2016; biomass and geothermal add output.

 

More than 80% of Idaho’s in-state utility-scale electricity generation came from renewable resources in 2018, behind only Vermont, according to recently released data from the U.S. Energy Information Administration’s Electric Power Monthly and broader trends showing that solar and wind reached about 10% of U.S. generation in the first half of 2018.

Idaho generated 17.4 million MWh of electricity in 2018, of which 14.2 million MWh came from renewable sources, while nationally January power generation jumped 9.3% year over year according to EIA. Idaho uses a variety of renewable resources to generate electricity:

Hydroelectricity. Idaho ranked seventh in the U.S. in electricity generation from hydropower in 2018. About half of Idaho’s electricity generating capacity is at hydroelectric power plants, and utility actions such as the Idaho Power settlement could influence future resource choices, and seven of the state’s 10 largest power plants (in terms of electricity generation) are hydroelectric facilities. The largest privately owned hydroelectric generating facility in the U.S. is a three-dam complex on the Snake River in Hells Canyon, the deepest river gorge in North America.

Wind. Nearly one-fifth of Idaho’s electricity generating capacity and one-sixth of its generation comes from wind turbines. Idaho has substantial wind energy potential, and nationally the EIA expects solar and wind to be larger sources this summer, although only a small percentage of the state's land area is well-suited for wind development. All of the state’s wind farms are located in the southern half of the state along the Snake River Plain.

Solar. Almost 5% of Idaho’s electricity generating capacity and 3% of its generation come from utility-scale solar facilities, and nationally over half of new capacity in 2023 will be solar according to projections. The state had no utility-scale solar generation as recently as 2015. Between 2016 and 2017, Idaho’s utility-scale capacity doubled and generation increased from 30,000 MWh to more than 450,000 MWh. Idaho’s small-scale solar capacity also doubled since 2017, generating 33,000 MWh in 2018.

Biomass. Biomass-fueled power plants account for about 2% of the state’s utility-scale electricity generating capacity and 3% of its generation, contributing to a broader U.S. shift where 40% of electricity came from non-fossil sources in 2021. Wood waste from the state’s forests is the primary fuel for these plants.

Geothermal. Idaho is one of seven states with utility-scale geothermal electricity generation. Idaho has one 18-MW geothermal facility, located near the state’s southern border with Utah.

EIA says Idaho requires significant electricity imports, totaling about one-third of demand, to meet its electricity needs. However, Idaho’s electricity imports have decreased over time, and Georgia's recent import levels illustrate how regional dynamics can vary. Almost all of these imports are from neighboring states, as electricity imports from Canada accounted for less than 0.1% of Idaho’s total electricity supply in 2017.

 

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EPA Policy to limit telework emerges during pandemic

EPA Telework Policy restricts remote work, balancing work-from-home guidance during the COVID-19 pandemic with flexible schedules, union contracts, OMB guidance, and federal workforce rules, impacting managers, SES staff, and non-bargaining employees nationwide.

 

Key Points

A directive limiting many EPA staff to two telework days weekly, with pandemic exceptions and flexible schedules.

✅ Limits telework to two days per week for many employees

✅ Allows flexible schedules, including maxiflex, during emergencies

✅ Aligns with OMB, OPM, CDC guidance; honors union agreements

 

EPA has moved forward on a new policy that would restrict telework even as agency leadership has encouraged staff to work from home during the coronavirus outbreak.

The new EPA order obtained by E&E News would require employees to report to the office at least three days every week.

"Full-time employees are expected to report to the official worksite and duty station a minimum of three (3) days per week," says the order, dated as approved on Feb. 27. It went into effect March 15 — that night, EPA Administrator Andrew Wheeler authorized telework for the entire agency due to the pandemic.

The order focuses on EPA employees' work schedules and gives them new flexibilities that could come in handy during a public health emergency like the COVID-19 virus, when parts of the power sector consider on-site staffing to ensure continuity.

It also stipulates a deep reduction in EPA employees' capability to work remotely, leaving them with two days of telework per week. An agency order on telework, issued in January 2016, said staff could telework full time.

"The EPA supports the use of telework," said that order. "Regular telework may range from one day per pay period up to full time."

An EPA spokeswoman said the new order doesn't change the agency's guidance to staff to work from home during the pandemic.

"The health and safety of our employees is our top priority, and that is why we have requested that all employees telework, even as residential electricity use increases with more people at home, until at least April 3. There is no provision in the work schedules policy, telework policy or collective bargaining agreement that limits this request," said the spokeswoman.

"While EPA did implement the national work schedule policy effective 3/15/2020, it was implemented in order to provide increased work schedule flexibilities for non-bargaining unit employees who were not previously afforded flexible schedules, including maxiflex," she added.

"The implementation of the policy does not currently impact telework opportunities for EPA employees, and EPA has strongly encouraged all staff to telework," she said.

Still, the new order has caused consternation among EPA employees.

One EPA manager described it as another move by the Trump administration to restrict telework across the government.

"Amidst the COVID-19 crisis, this policy seems particularly ill-timed and unwise. It doesn't even give the administration the chance to evaluate the situation once the COVID-19 pandemic passes," said the manager.

"I think this is a dramatic change in the flexibilities available to the EPA employees without any data to support such a drastic move," the manager said. "It has huge ramifications for employees, many of whom commute over an hour each way to the office, increasing air pollution in the process."

Another EPA staffer said, "I honestly think such an order, given current circumstances, would elicit little more than a scoff and a smirk."

The person added, "How tone-deaf and heavy-handed can one administration be?"

Inside EPA first reported on the new order. E&E News obtained the memo independently.

The recently issued policy applies only to non-bargaining-unit employees, including "full-time and part-time" agency staff as well as "supervisors and managers in the competitive, excepted, Senior Level, Scientific and Professional, and Senior Executive Service positions."

In addition, the order covers "Public Health Service Officers, Schedule C, Administratively Determined employees and non-EPA employees serving on Intergovernmental Personnel Act assignments to EPA."

Nevertheless, EPA employees covered under union contracts must adhere to those contracts if the policy runs counter to them.

"If provisions of this order conflict with the provisions of a collective bargaining agreement, the provisions of the agreement must be applied," the order says.

EPA has taken a more restrictive approach with the agency's largest union, American Federation of Government Employees Council 238, which represents about 7,500 EPA employees. EPA imposed a contract on the council's bargaining unit employees last July that limited them to one day of telework per week, among other changes that triggered union protests.

EPA and AFGE have since relaunched contract negotiations, and how to handle telework is one of the issues under discussion. Both sides committed to complete those bargaining talks by April 15 and work with the Federal Service Impasses Panel if needed (Greenwire, Feb. 27).

 

Both sides of the telework debate
EPA's new order has been under consideration for some time.

E&E News obtained a draft version last year. The agency had circulated it for comment in July, noting the proposal "limits the number of days an employee may telework per week," among other changes (Greenwire, Sept. 12, 2019).

EPA, like other federal agencies under the Trump administration, has sought to reduce employees' telework. That effort, though, has run into the headwinds of a global pandemic, with a U.S. grid warning highlighting broader risks, leading agency leaders to reverse course and now encourage staff to work remotely in order to stop the spread of the COVID-19 virus.

Wheeler in an email last week told staff that he authorized telework for employees across the country. Federal worker unions had sought the opportunity for remote work on behalf of EPA employees, and the agency had already relaxed telework policies at various offices the prior week where the coronavirus had begun to take hold.

The EPA spokeswoman said the agency moved toward telework after guidance from other agencies.

"Consistent with [Office of Management and Budget], [Centers for Disease Control and Prevention] and [Office of Personnel Management] guidance, along with state and local directives, we have taken swift action in regions and at headquarters to implement telework for all employees. We continue to tell all employees to telework," said the spokeswoman.

Wheeler said in a later video message that his expectation was most EPA employees were working from home.

"I understand that this is a difficult and scary time for all of us," said the EPA administrator.

The coronavirus has become a real challenge for EPA, and utilities like BC Hydro Site C updates illustrate broader operational adjustments.

Agency staff have been exposed to the virus while some have tested positive, and nuclear plant workers have raised similar concerns, according to internal emails. That has led to employees self-quarantining while their colleagues worry they may next fall ill (Greenwire, March 20).

One employee said that since EPA's operations have been maintained with staff working from home, even as household electricity bills rise for many, it's harder for the Trump administration to justify restricting remote work.

"With the current climate, I think employees have shown we can keep the agency going with nearly 95% teleworking full time. It makes their argument hard to justify in light of things," said the EPA employee.

The Trump administration overall has pushed for more remote work by the federal workforce in the battle with the COVID-19 virus. The Office of Management and Budget issued guidance to agencies last week "to minimize face-to-face interactions" and "maximize telework across the nation."

Lawmakers have also pushed to expand telework for federal workers due to the virus.

Democratic senators sent a letter last week urging President Trump to issue an executive order directing agencies to use telework.

In addition, Sens. James Lankford (R-Okla.), Chris Van Hollen (D-Md.) and Kyrsten Sinema (D-Ariz.) introduced legislation that would allow federal employees to telework full time during the pandemic.

Some worry EPA's new order could further sour morale at the agency after the pandemic passes, as other utilities consider measures like unpaid days off to trim costs. Employees may leave if they can't work from home more.

"People will quit EPA over something like this. Maybe that's the goal," said the EPA manager.

 

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How the dirtiest power station in western Europe switched to renewable energy

Drax Biomass Conversion accelerates renewable energy by replacing coal with wood pellets, sustainable forestry feedstock, and piloting carbon capture and storage, supporting the UK grid, emissions cuts, and a net-zero pathway.

 

Key Points

Drax Biomass Conversion is Drax's shift from coal to biomass with CCS pilots to cut emissions and aid UK's net-zero.

✅ Coal units converted to biomass wood pellets

✅ Sourced from sustainable forestry residues

✅ CCS pilots target lifecycle emissions cuts

 

A power station that used to be the biggest polluter in western Europe has made a near-complete switch to renewable energy, mirroring broader shifts as Denmark's largest energy company plans to end coal by 2023.

The Drax Power Station in Yorkshire, England, used to spew out millions of tons of carbon dioxide a year by burning coal. But over the past eight years, it has overhauled its operations by converting four of its six coal-fired units to biomass. The plant's owners say it now generates 15% of the country's renewable power, as Britain recently went a full week without coal power for the first time.

The change means that just 6% of the utility's power now comes from coal, as the wider UK coal share hits record lows across the national electricity system. The ultimate goal is to stop using coal altogether.

"We've probably reduced our emissions more than any other utility in the world by transforming the way we generate power," Will Gardner, CEO of the Drax Group, told CNN Business.

Subsidies have helped finance the switch to biomass, which consists of plant and agricultural matter and is viewed as a promising substitute for coal, and utilities such as Nova Scotia Power are also increasing biomass use. Last year, Drax received £789 million ($1 billion) in government support.

 

Is biomass good for the environment?

While scientists disagree over the extent to which biomass as a fuel is environmentally friendly, and some environmentalists urge reducing biomass use amid concerns about lifecycle emissions, Drax highlights that its supplies come from from sustainably managed and growing forests.

Most of the biomass used by Drax consists of low-grade wood, sawmill residue and trees with little commercial value from the United States. The material is compressed into sawdust pellets.

Gardner says that by purchasing bits of wood not used for construction or furniture, Drax makes it more financially viable for forests to be replanted. And planting new trees helps offset biomass emissions.

Forests "absorb carbon as they're growing, once they reach maturity, they stop absorbing carbon," said Raphael Slade, a senior research fellow at Imperial College London.

But John Sterman, a professor at MIT's Sloan School of Management, says that in the short term burning wood pellets adds more carbon to the atmosphere than burning coal.

That carbon can be absorbed by new trees, but Sterman says the process can take decades.

"If you're looking at five years, [biomass is] not very good ... If you're looking at a century-long time scale, which is the sort of time scale that many foresters plan, then [biomass] can be a lot more beneficial," says Slade.

 

Carbon capture

Enter carbon capture and storage technology, which seeks to prevent CO2 emissions from entering the atmosphere and has been touted as a possible solution to the climate crisis.

Drax, for example, is developing a system to capture the carbon it produces from burning biomass. But that could be 10 years away.

 

The Coal King is racing to avoid bankruptcy

The power station is currently capturing just 1 metric ton of CO2 emissions per day. Gardner says it hopes to increase this to 10,000 metric tons per day by the mid to late 2020s.

"The technology works but scaling it up and rolling it out, and financing it, are going to be significant challenges," says Slade.

The Intergovernmental Panel on Climate Change shares this view. The group said in a 2018 report that while the potential for CO2 capture and storage was considerable, its importance in the fight against climate change would depend on financial incentives for deployment, and whether the risks of storage could be successfully managed. These include a potential CO2 pipeline break.

In the United Kingdom, the government believes that carbon capture and storage will be crucial to reaching its goal of achieving net-zero greenhouse gas emissions by 2050, even as low-carbon generation stalled in 2019 according to industry analysis.

It has committed to consulting on a market-based industrial carbon capture framework and in June awarded £26 million ($33 million) in funding for nine carbon capture, usage and storage projects, amid record coal-free generation on the British grid.

 

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Are major changes coming to your electric bill?

California Income-Based Electricity Rates propose a fixed monthly fee set by income as utilities and the CPUC weigh progressive pricing, aiming to cut low-income bills while PG&E, SCE, and SDG&E retain usage-based charges.

 

Key Points

CPUC plan adds income-tiered fixed fees to lower low-income bills while keeping per-kWh usage charges.

✅ Adds fixed monthly fees by income to complement per-kWh charges

✅ Cuts bills for low-income households; higher earners pay more

✅ Utilities say revenue neutral; conservation signals preserved

 

California’s electric bills — already some of the highest in the nation — are rising as electricity prices soar across the state, but regulators are debating a new plan to charge customers based on their income level. 

Typically what you pay for electricity depends on how much you use. But the state’s three largest electric utilities — Southern California Edison Company, Pacific Gas and Electric Company and San Diego Gas & Electric Company — have proposed a plan to charge customers not just for how much energy they use, but also based on their household income, moving toward income-based flat-fee utility bills over time. Their proposal is one of several state regulators received designed to accommodate a new law to make energy less costly for California’s lowest-income customers.

Some state Republican lawmakers are warning the changes could produce unintended results, such as weakening incentives to conserve electricity or raising costs for customers using solar energy, and some have introduced a plan to overturn the charges in the Legislature.

But the utility companies say the measure would reduce electricity bills for the lowest income customers. Those residents would save about $300 per year, utilities estimate.

California households earning more than $180,000 a year would end up paying an average of $500 more a year on their electricity bills, according to the proposal from utility companies. 

The California Public Utilities Commission’s deadline for deciding on the suggested changes is July 1, 2024, as regulators face calls for action from consumers and advocates. The proposals come at a time when many moderate and low-income families are being priced out of California by rising housing costs.  

Who wants to change the fee structure?
Lawmakers passed and Gov. Gavin Newsom signed a comprehensive energy bill last summer that mandates restructuring electricity pricing across the state. 

The Legislature passed the measure in a “trailer-bill” process that limited deliberation. Included in the 21,000-word law are a few sentences requiring the public utilities commission to establish a “fixed monthly fee” based on each customer’s household income. 

A similar idea was first proposed in 2021 by researchers at UC Berkeley and the nonprofit thinktank Next 10. Their main recommendation was to split utility costs into two buckets. Fixed charges, which everyone has to pay just to be connected to the energy grid, would be based on income levels. Variable charges would depend on how much electricity you use.

Utilities say that part of customers’ bills still will be based on usage, but the other portion will reduce costs for lower- and middle-income customers, who “pay a greater percentage of their income towards their electricity bill relative to higher income customers,” the utilities argued in a recent filing. 

They said the current billing system is unjust, regressive and fails to recognize differences in energy usage among households,

“When we were putting together the reform proposal, front and center in our mind were customers who live paycheck to paycheck, who struggle to pay for essentials such as energy, housing and food,” Caroline Winn, CEO of San Diego Gas & Electric in a statement. 

The utilities say in their proposal that the changes likely would not reduce or increase their revenues.

James Sallee, an associate professor at UC Berkeley, said the utilities’ prior system of billing customers mostly by measuring their electric use to pay for what are essentially fixed costs for power is inefficient and regressive. 

The proposed changes “will shift the burden, on average, to a more progressive system that recovers more from higher income households and less from lower income households,” he said.

 

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