Texas oil billionaire eyes Alberta wind power

By CBC News


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Texas billionaire T. Boone Pickens told a Calgary business audience he's looking to make a potential investment in wind energy in Alberta.

"If it's a better deal in Alberta than it is in Texas, I'd be more interested in Alberta than I would Texas," he said at a sold-out luncheon at the Westin Hotel. "I want to make the best deal I can wherever I invest my money."

The Pickens Plan, introduced last year, calls for the United States to cut its dependence on foreign oil by more than one-third by making natural gas and wind power much bigger parts of America's energy supply.

The United States receives more crude oil from Canada than from any other country.

Pickens, who made his fortune in oilpatch investments, is behind a plan to build the world's largest wind farm in Texas.

His proposal calls for the private sector to build thousands of wind turbines, which would supply one-fifth of electricity in the U.S. The wind power would free up supplies of natural gas, traditionally used in power generation, to be used as a transportation fuel instead of diesel and gasoline.

He said Canadians need not worry about the plan to wean the United States off of foreign oil.

"It's going to be good for America. It's going to be good for Canada," the 81-year-old oilman said in front of 770 members of Calgary's business community. "It's going to be good for the producers. It's going to be good for everybody."

Pickens said the only loser in the deal is foreign oil. "And I don't call you foreign," he added, eliciting peals of laughter.

"It's just natural, to me, that the United States and Canada work together and we're, of course, a good customer to the Canadians, and it's easier to sell it to us than anyone else, so it would naturally come here," Pickens told reporters.

"From our standpoint, we would prefer Canadian oil because it's more stable than any place in the world. That's just a natural relationship that I think just grows, and no reason for it to decrease."

Pickens laid out a rosy outlook for natural gas prices, which traded above $4 US per 1,000 cubic feet but have languished well below that mark for months.

"I think next year $7 US will be the average price for the year for natural gas. I'm optimistic about the price."

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Electric Cooperatives, The Lone Shining Utility Star Of The Texas 2021 Winter Storm

Texas Electric Cooperatives outperformed during Winter Storm Uri, with higher customer satisfaction, equitable rolling blackouts, and stronger grid reliability compared to deregulated markets, according to ERCOT-area survey data of regulated utilities and commercial providers.

 

Key Points

Member-owned utilities in Texas delivering power, noted for reliability and fair outages during Winter Storm Uri.

✅ Member-owned, regulated utilities serving local communities

✅ Rated higher for blackout management and communication

✅ Operate outside deregulated markets; align incentives with users

 

Winter Storm Uri began to hit parts of Texas on February 13, 2021 and its onslaught left close to 4.5 million Texas homes and businesses without power, and many faced power and water disruptions at its peak. By some accounts, the preliminary number of deaths attributed to the storm is nearly 200, and the economic toll for the Lone Star State is estimated to be as high as $295 billion. 

The more than two-thirds of Texans who lost power during this devastating storm were notably more negative than positive in their evaluation of the performance of their local electric utility, mirrored by a rise in electricity complaints statewide, with one exception. That exception are the members of the more than 60 electric cooperatives operating within the Texas Interconnection electrical grid, which, in sharp contrast to the customers of the commercial utilities that provide power to the majority of Texans, gave their local utility a positive evaluation related to its performance during the storm.

In order to study Winter Storm Uri’s impact on Texas, the Hobby School of Public Affairs at the University of Houston conducted an online survey during the first half of March of residents 18 and older who live in the 213 counties (91.5% of the state population) served by the Texas power grid, which is managed by the Electric Reliability Council of Texas (ERCOT). 

Three-quarters of the survey population (75%) live in areas with a deregulated utility market, where a specified transmission and delivery utility by region is responsible for delivering the electricity (purchased from one of a myriad of private companies by the consumer) to homes and businesses. The four main utility providers are Oncor, CenterPoint CNP -2.2%, American Electric Power (AEP) North, and American Electric Power (AEP) Central. 

The other 25% of the survey population live in areas with regulated markets, where a single company is responsible for both delivering the electricity to homes and businesses and serves as the only source from which electricity is purchased. Municipal-owned and operated utilities (e.g., Austin Energy, Bryan Texas Utilities, Burnet Electric Department, Denton Municipal Electric, New Braunfels Utilities, San Antonio’s CPS Energy CMS -2.1%) serve 73% of the regulated market. Electric cooperatives (e.g., Bluebonnet Electric Cooperative, Central Texas Electric Cooperative, Guadalupe Valley Cooperative, Lamb County Electric Cooperative, Pedernales Electricity Cooperative, Wood County Electric Cooperative) serve one-fifth of this market (21%), with private companies accounting for 6% of the regulated market.

The overall distribution of the survey population by electric utility providers is: Oncor (38%), CenterPoint (21%), municipal-owned utilities (18%), AEP Central & AEP North combined (12%), electric cooperatives (6%), other providers in the deregulated market (4%) and other providers in the regulated market (1%). 

There were no noteworthy differences among the 31% of Texans who did not lose power during the winter storm in regard to their evaluations of their local electricity provider or their belief that the power cuts in their locale were carried out in an equitable manner.  

However, among the 69% of Texans who lost power, those served by electric cooperatives in the regulated market and those served by private electric utilities in the deregulated market differed notably regarding their evaluation of the performance of their local electric utility, both in regard to their management of the rolling blackouts, amid debates over market reforms to avoid blackouts, and to their overall performance during the winter storm. Those Texans who lost power and are served by electric cooperatives in a regulated market had a significantly more positive evaluation of the performance of their local electric utility than did those Texans who lost power and are served by a private company in a deregulated electricity market. 

For example, only 24% of Texans served by electric cooperatives had a negative evaluation of their local electric utility’s overall performance during the winter storm, compared to 55%, 56% and 61% of those served by AEP, Oncor and CenterPoint respectively. A slightly smaller proportion of Texans served by electric cooperatives (22%) had a negative evaluation of their local electric utility’s performance managing the rolling blackouts during the winter storm, compared to 58%, 61% and 71% of Texans served by Oncor, AEP and CenterPoint, respectively.

Texans served by electric cooperatives in regulated markets were more likely to agree that the power cuts in their local area were carried out in an equitable manner compared to Texans served by commercial electricity utilities in deregulated markets. More than half (52%) of those served by an electric cooperative agreed that power cuts during the winter storm in their area were carried out in an equitable manner, compared to only 26%, 23% and 23% of those served by Oncor, AEP and CenterPoint respectively

The survey data did not allow us to provide a conclusive explanation as to why the performance during the winter storm by electric cooperatives (and to a much lesser extent municipal utilities) in the regulated markets was viewed more favorably by their customers than was the performance of the private companies in the deregulated markets viewed by their customers. Yet here are three, far from exhaustive, possible explanations.

First, electric cooperatives might have performed better (based on objective empirical metrics) during the winter storm, perhaps because they are more committed to their customers, who are effectively their bosses. .  

Second, members of electric cooperatives may believe their electric utility prioritizes their interests more than do customers of commercial electric utilities and therefore, even if equal empirical performance were the case, are more likely to rate their electric utility in a positive manner than are customers of commercial utilities.  

Third, regulated electric utilities where a single entity is responsible for the commercialization, transmission and distribution of electricity might be better able to respond to the type of challenges presented by the February 2021 winter storm than are deregulated electric utilities where one entity is responsible for commercialization and another is responsible for transmission and distribution, aligning with calls to improve electricity reliability across Texas.

Other explanations for these findings may exist, which in addition to the three posited above, await future empirical verification via new and more comprehensive studies designed specifically to study electric cooperatives, large commercial utilities, and the incentives that these entities face under the regulatory system governing production, commercialization and distribution of electricity, including rulings that some plants are exempt from providing electricity in emergencies under state law. 

Still, opinion about electricity providers during Winter Storm Uri is clear: Texans served by regulated electricity markets, especially by electric cooperatives, were much more satisfied with their providers’ performance than were those in deregulated markets. Throughout its history, Texas has staunchly supported the free market. Could Winter Storm Uri change this propensity, or will attempts to regulate electricity lessen as the memories of the storm’s havoc fades? With a hotter summer predicted to be on the horizon in 2021 and growing awareness of severe heat blackout risks, we may soon get an answer.   

 

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Charting a path to net zero electricity emissions by the middle of the century

Clean Energy Standard charts a federal path to decarbonize the power sector, scaling renewables, wind, solar, nuclear, and carbon capture to slash emissions, create green jobs, and reach net-zero targets amid the climate crisis.

 

Key Points

A federal policy to expand clean power and cut emissions with renewables, nuclear, and carbon capture toward net-zero.

✅ Mandates annual increases in clean electricity supply

✅ Includes renewables, nuclear, hydro, and carbon capture

✅ Targets rapid emissions cuts and net-zero by mid-century

 

The world has been put on notice. Last year, both the UN Intergovernmental Panel on Climate Change and the U.S. National Climate Assessment warned that we need to slash greenhouse gas emissions to avoid disastrous impacts of global warming. Their direct language forecasting devastating effects on our health, economics, environment, and ways of life has made even more urgent the responsibility we all have to act boldly to combat the climate crisis.

This week, we’re adding one important tool for addressing the climate crisis to the national conversation.

Together, we’re taking that bold action. The Climate reports made clear that to limit the global temperature rise and stave off devastating impacts to our climate—human-caused CO2 emissions must fall rapidly by 2030 and that we, as a global community, underscored at the Katowice climate talks, must reach net-zero emissions by the middle of the century. The Clean Energy Standard is federal legislation that offers a pathway toward decarbonizing our power sector and helping our nation accomplish a goal of net-zero emissions by the 2050s.

Under this plan, any company selling retail electricity will have a mandate to increase the amount of clean energy provided to its customers. It will incentivize clean electricity investment to put the U.S. on a sustainable path.

To deal most effectively with a crisis, all tools must be on the table. Our plan focuses solely on emissions, and there is a place for all technologies that can put us on the path to net zero. That will mean drastic increases in wind and solar energy for sure, as states like California pursue a 100% carbon-free electricity mandate to accelerate deployment, but nuclear power, hydro power, and fossil fuels with carbon capture and storage all have important roles to play.

We’re doing this because the science is clear – tackling our climate crisis requires serious and rapid action to control greenhouse gas emissions, and the push for decarbonization is irreversible according to many. Inaction on the climate crisis puts our families at risk, and we’re not wasting any time. This is also an opportunity to create good-paying green jobs that can last generations and uplift the middle class.

We are doing this for the environment, but also for jobs and economic competitiveness. The green economy is the future and we’re ready to see it grow, with states like New York advancing a Green New Deal that drives innovation. The United States can lead, or we can follow, and we want our nation to lead.

And, because as a New Mexican and a Minnesotan, we know that the impacts of climate change go far beyond the headlines and political discourse. It means devastation within tamarack forests and an increase in deadly fires. It means hotter summers and shorter winters with extreme temperature swings throughout the year. It means devastating flash floods with increasingly intense rain. It’s impacting our pocketbooks when farmers and small businesses who work the land in rural communities are unable to make ends meet.

States across the country are already acting to combat the climate crisis – including Minnesota's 2050 carbon-free electricity plan and New Mexico. But in order to truly address climate change, we have to be in this together as Americans. If the problem is far-reaching, our solutions must be equally as holistic.

It's why we've worked with green groups and activists, unions, and communities across the country - from urban to rural - to create a solution that understands the different starting points communities face in reaching net zero emissions, but doesn't shrink from the absolute need to reach that standard.

There is not one solution to climate change – it will take a collective group of individuals prepared to boldly act. And we are ready to take on that fight.

In Congress, we have formed the House Select Committee on the Climate Crisis and the Senate Democrats’ Special Committee on the Climate Crisis to hear from everyday Americans how climate change is affecting them – and how we can come together to find solutions that build on the historic climate deal passed this year. We have heard the stories of young people worried about their futures. And we realize there is a sense of urgency to act.

Over the coming weeks and months, we will be building support from communities across the country to make this plan a reality. We will continue working with stakeholders to ensure every voice is heard. Most importantly, we will continue listening to you and your communities.

 

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N.S. senior suspects smart meter to blame for shocking $666 power bill

Nova Scotia Power smart meter billing raises concerns amid estimated billing, catch-up bills, and COVID-19 meter reading delays, after seniors report doubled electricity usage and higher utility charges despite consistent consumption and on-time payments.

 

Key Points

Smart meter billing uses digital reads, limits estimates, and may trigger catch-up charges after reading suspensions.

✅ COVID-19 reading pause led to estimated bills and later catch-ups

✅ Smart meters reduce reliance on estimated billing errors

✅ Customers can seek payment plans and bill reviews

 

A Nova Scotia senior says she couldn't believe her eyes when she opened her most recent power bill. 

Gloria Chu was billed $666 -- more than double what she normally pays, and similar spikes such as rising electricity bills in Calgary have drawn attention.

As someone who always pays her bi-monthly Nova Scotia Power bill in full and on time, Chu couldn't believe it.

According to her bill, her electricity usage almost tripled during the month of May, compared to last year, and is even more than it was last winter, and with some utilities exploring seasonal power rates customers may see confusing swings.

She insists she and her husband aren't doing anything differently -- but one thing has changed.

"I have had a problem since they put the smart meter in," said Chu, who lives in Upper Gulf Shore, N.S.

Chu got a big bill right after the meter was installed in January, too. That one was more than $530.

She paid it, but couldn't understand why it was so high.

As for this bill, she says she just can't afford it, especially amid a recently approved 14% rate hike in Nova Scotia.

"That's all of my CPP," Chu said. "Actually, it's more than my CPP."

Chu says a neighbor up the road who also has a smart meter had her bill double, too. In nearby Pugwash, she says some residents have seen an increase of about $20-$30.

Nova Scotia Power had put a pause on installing smart meters because of the COVID-19 pandemic, but it has resumed as of June 1, with the goal of upgrading 500,000 meters by 2021, even as in other provinces customers have faced fees for refusing smart meters during similar rollouts.

In this case, the utility says it's not the meter that's the problem, and notes that in New Brunswick some old meters gave away free electricity even as the pandemic forced Nova Scotia Power to suspend meter readings for two months.

"As a result, every one of our customers in Nova Scotia received an estimated bill," said Jennifer parker, Nova Scotia Power's director of customer care.

The utility estimated Chu's bill at $182 -- less than she normally pays -- so her latest bill is considered a catch-up bill after meter readings resumed last month.

Parker admits how estimates are calculated isn't perfect.

"There would be a lot of customers who probably had a more accurate bill because of the way that we estimate, and that's actually one of things that smart meters will get rid of, is that we won't need to do estimated billing," Parker said.

Chu isn't quite convinced.

"It is pretty smart for the power company, but it's not smart for us," she said with a laugh.

Nova Scotia Power has put a hold on her bill and says it will work with Chu on an affordable solution, though the province cannot order the utility to lower rates which limits what can be offered.

She just hopes to never see a big bill like this again, while elsewhere in Newfoundland and Labrador a lump-sum electricity credit is being provided to help customers.

 

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Multi-billion-dollar hydro generation project proposed for Meaford military base

Meaford Pumped Storage Project aims to balance the grid with hydro-electric generation, a hilltop reservoir, and transmission lines near Georgian Bay, pending environmental assessment, permitting, and federal review of impacts on fish and drinking water.

 

Key Points

TC Energy proposal to pump water uphill off-peak and generate 1,000 MW at peak, pending studies and approvals.

✅ Balances grid by storing off-peak energy and generating at peak.

✅ Requires reservoir, break wall, transmission lines, generating station.

✅ Environmental studies and federal review underway before approvals.

 

Plans for a $3.3 billion hydro-electric project in Meaford are still in the early study stages, but some residents have concerns about what it might mean for the environment, as past Site C stability issues have illustrated for large hydro projects.

A one-year permit was granted for TC Energy Corporation (TC Energy) to begin studies on the proposed location back in May, and cross-border projects like the New England Clean Power Link require federal permits as well to proceed. Local municipalities were informed of the project in June.

TC Energy is proposing to have a pumped storage project at the 4th Canadian Division Training (4CDTC) Meaford property, which is on federal lands.

A letter sent to local municipalities explains that the plan is to balance supply and demand on the electrical grid by pumping water uphill during off-peak hours. It would then release the water back into Georgian Bay during peak periods, generating up to 1,000 megawatts of electricity.

The project is expected to create 800 jobs over four years of construction, in addition to long-term operational positions.


 

According to the company's website, the proposed pump station would require a large reservoir on the military base, a generating station, transmission lines infrastructure, and a break wall 850 metres from shore.

Some residents fear the project will threaten the bay and the fish, echoing Site C dam concerns shared with northerners, and the region's drinking water.

Meaford's mayor says the town has no jurisdiction on federal lands, but that a list of concerns has been forwarded to the company, while Ontario First Nations have urged government action on urgent transmission needs elsewhere.

TC Energy will tackle preliminary engineering and environmental studies to determine the feasibility of the proposed location, which could take up to two years.

Once the assessments are done, they need to be presented to the government for further review and approval, as seen when Ottawa's Site C stance left work paused pending a treaty rights challenge.

TC Energy's website states that the company anticipates construction to begin in 2022 if it gets all the go-ahead, with the plant to begin operations four years later.

Input from residents is being collected until April 2020, similar to when the National Energy Board heard oral traditional evidence on the Manitoba-Minnesota transmission line.

 

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PG&E Wildfire Assistance Program Accepting Applications for Aid

PG&E Wildfire Assistance Program offers court-approved aid and emergency grants for Northern California wildfires and Camp Fire victims, covering unmet needs, housing, and essentials; apply online by November 15, 2019 under Chapter 11-funded eligibility.

 

Key Points

A $105M, court-approved aid fund offering unmet-needs payments and emergency support for 2017-2018 wildfire victims.

✅ $5,000 Basic Unmet Needs per household, self-certified

✅ Supplemental aid for extreme circumstances after basic grants

✅ Apply online; deadline November 15, 2019; identity required

 

Beginning today, August 15, 2019, those displaced by the 2017 Northern California wildfires and 2018 Camp fire can apply for aid through an independently administered Wildfire Assistance Program funded by Pacific Gas and Electric Company (PG&E). PG&E’s $105 million fund, approved by the judge in PG&E’s Chapter 11 cases and related bankruptcy plan, is intended to help those who are either uninsured or need assistance with alternative living expenses or other urgent needs. The court-approved independent administrator is set to file the eligibility criteria as required by the court and will open the application process.

“Our goal is to get the money to those who most need it as quickly as possible. We will prioritize wildfire victims who have urgent needs, including those who are currently without adequate shelter,” said Cathy Yanni, plan administrator. Yanni is partnering with local agencies and community organizations to administer the fund, and PG&E also supports local communities through property tax contributions to counties.

“We appreciate the diligent work of the fund administrator in quickly establishing a way to distribute these funds and ensuring the program supports those with the most immediate needs. PG&E is focused on helping those impacted by the devastating wildfires in recent years and strengthening our energy system to reduce wildfire risks and prevent utility-caused catastrophic fires. We feel strongly that helping these communities now is the right thing to do,” said Bill Johnson, CEO and President of PG&E Corporation.

Applicants can request a “Basic Unmet Needs” payment of $5,000 per household for victims who establish basic eligibility requirements and self-certify that they have at least $5,000 of unmet needs that have not been compensated by the Federal Emergency Management Agency (FEMA). Payments are to support needs such as water, food, prescriptions, medical supplies and equipment, infant formula and diapers, personal hygiene items, and transportation fuels beyond what FEMA covered in the days immediately following the declared disasters, aligning with broader health and safety actions the company has taken.

Those who receive basic payments may also qualify for a “Supplemental Unmet Needs” payment. These funds will be available only after “Basic Unmet Needs” payments have been issued. Supplemental payments will be available to individuals and families who currently face extreme or extraordinary circumstances as compared to others who were impacted by the 2017 and 2018 wildfires, including areas affected by power line-related fires across California.

To qualify for the payments, applicants’ primary residence must have been within the boundary of the 2017 Northern California wildfires or the 2018 Camp fire in Butte County. Applicants also must establish proof of identity and certify that they are not requesting payments for an expense already paid for by FEMA.

Applicants can find more information and apply for assistance at https://www.norcalwildfireassistanceprogram.com/. The deadline to file for aid is November 15, 2019.

The $105 million being provided by PG&E was made available from the company’s cash reserves. PG&E will not seek cost recovery from its customers, and its rates are set to stabilize in 2025 according to recent guidance.

 

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Told "no" 37 times, this Indigenous-owned company brought electricity to James Bay anyway

Five Nations Energy Transmission Line connects remote First Nations to the Ontario power grid, delivering clean, reliable electricity to Western James Bay through Indigenous-owned transmission infrastructure, replacing diesel generators and enabling sustainable community growth.

 

Key Points

An Indigenous-owned grid link providing reliable power to Western James Bay First Nations, replacing polluting diesel.

✅ Built by five First Nations; fully Indigenous-owned utility

✅ 270 km line connecting remote James Bay communities

✅ Ended diesel dependence; enabled sustainable development

 

For the Indigenous communities along northern Ontario’s James Bay — the ones that have lived on and taken care of the lands as long as anyone can remember — the new millenium marked the start of a diesel-less future, even as Ontario’s electricity outlook raised concerns about getting dirtier in policy debates. 

While the southern part of the province took Ontario’s power grid for granted, despite lessons from Europe’s power crisis about reliability, the vast majority of these communities had never been plugged in. Their only source of power was a handful of very loud diesel-powered generators. Because of that, daily life in the Attawapiskat, Kashechewan and Fort Albany First Nations involved deliberating a series of tradeoffs. Could you listen to the radio while toasting a piece of bread? How many Christmas lights could you connect before nothing else was usable? Was there enough power to open a new school? 

The communities wanted a safe, reliable, clean alternative, with Manitoba’s clean energy illustrating regional potential, too. So did their chiefs, which is why they passed a resolution in 1996 to connect the area to Ontario’s grid, not just for basic necessities but to facilitate growth and development, and improve their communities’ quality of life. 

The idea was unthinkable at the time — scorned and dismissed by those who held the keys to Ontario’s (electrical) power, much like independent power projects can be in other jurisdictions. Even some in the community didn’t fully understand it. When the idea was first proposed at a gathering of Nishnawbe Aski Nation, which represents 49 First Nations, one attendee said the only way he could picture the connection was as “a little extension cord running through the bush from Moosonee.” 

But the leadership of Attawapiskat, Kashechewan and Fort Albany First Nations had been dreaming and planning. In 1997, along with members of Taykwa Tagamou and Moose Cree First Nations, they created the first, and thus far only, fully Indigenous-owned energy company in Canada: Five Nations Energy Inc., as partnerships like an OPG First Nation hydro project would later show in action, too. 

Over the next five years, the organization built Omushkego Ishkotayo, the Cree name for the Western James Bay transmission line: “Omushkego” refers to the Swampy Cree people, and “Ishkotayo” to hydroelectric power, while other regions were commissioning new BC generating stations in parallel. The 270-kilometre-long transmission line is in one of the most isolated regions of Ontario, one that can only be accessed by plane, except for a few months in winter when ice roads are strong enough to drive on. The project went online in 2001, bringing reliable power to over 7,000 people who were previously underserved by the province’s energy providers. It also, somewhat controversially, enabled Ontario’s first diamond mine in Attawapiskat territory.

The future the First Nations created 25 years ago is blissfully quiet, now that the diesel generators are shut off. “When the power went on, you could hear the birds,” Patrick Chilton, the CEO of Five Nations Energy, said with a smile. “Our communities were glowing.”

Power, politics and money: Five Nations Energy needed government, banks and builders on board
Chilton took over in 2013 after the former CEO, his brother Ed, passed away. “This was all his idea,” Chilton told The Narwhal in a conversation over Zoom from his office in Timmins, Ont. The company’s story has never been told before in full, he said, because he felt “vulnerable” to the forces that fought against Omushkego Ishkotayo or didn’t understand it, a dynamic underscored by Canada’s looming power problem reporting in recent years. 

The success of Five Nations Energy is a tale of unwavering determination and imagination, Chilton said, and it started with his older brother. “Ed was the first person who believed a transmission line was possible,” he said.

In a Timmins Daily Press death notice published July 2, 2013, Ed Chilton is described as having “a quiet but profound impact on the establishment of agreements and enterprises benefitting First Nations peoples and their lands.” Chilton doesn’t describe him that way, exactly. 

“If you knew my brother, he was very stubborn,” he said. A certified engineering technologist, Ed was a visionary whose whole life was defined by the transmission line. He was the first to approach the chiefs with the idea, the first to reach out to energy companies and government officials and the one who persuaded thousands of people in remote, underserved communities that it was possible to bring power to their region.

After that 1996 meeting of Nishnawbe Aski Nation, there came a four-year-long effort to convince the rest of Ontario, and the country, the project was possible and financially viable. The chiefs of the five First Nations took their idea to the halls of power: Queen’s Park, Parliament Hill and the provincial power distributor Hydro One (then Ontario Hydro). 

“All of them said no,” Chilton said. “They saw it as near to impossible — the idea that you could build a transmission line in the ‘swamp,’ as they called it.” The Five Nations Energy team kept a document at the time tracking how many times they heard no; it topped out at 37. 

One of the worst times was in 1998, at a meeting on the 19th floor of the Ontario Hydro building in the heart of downtown Toronto. There, despite all their preparation and planning, a senior member of the Ontario Hydro team told Chilton, Martin and other chiefs “you’ll build that line over my dead body,” Chilton recalled. 

At the time, Chilton said, Ontario Hydro was refusing to cooperate: unwilling to let go of its monopoly over transmission lines, but also saying it was unable to connect new houses in the First Nations to diesel generators it said were at maximum capacity. (Ontario Hydro no longer exists; Hydro One declined to comment.)

“There’s always naysayers no matter what you’re doing,” Martin said. “What we were doing had never been done before. So of course people were telling us how we had never managed something of this size or a budget of this size.” 

“[Our people] basically told them to blow it up your ass. We can do it,” Chilton said.

So the chiefs of the five nations did something they’d never done before: they went to all of the big banks and many, many charitable foundations trying to get the money, a big ask for a project of this scale, in this location. Without outside support, their pitch was that they’d build it themselves.

This was the hardest part of the process, said Lawrence Martin, the former Grand Chief of Mushkegowuk Tribal Council and a member of the Five Nations Energy board. “We didn’t know how to finance something like this, to get loans,” he told The Narwhal. “That was the toughest task for all of us to achieve.”

Eventually, they got nearly $50 million in funding from a series of financial organizations including the Bank of Montreal, Pacific and Western Capital, the Northern Ontario Heritage Fund Corporation (an Ontario government agency) and the engineering and construction company SNC Lavalin, which did an assessment of the area and deemed the project viable. 

And in 1999, Ed Chilton, other members of the Chilton family and the chiefs were able to secure an agreement with Ontario Hydro that would allow them to buy electricity from the province and sell it to their communities. 

 

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