Alberta picked up $8 million tab for land rent left unpaid by oil and gas companies in 2019

Data obtained via a freedom of information request shows taxpayers are footing the bill for delinquent companies’ payments to private landowners, to the tune of nearly $30 million since 2010

Sharon J. Riley

May 22, 2020

6 min read

The Alberta government failed to recoup more than $8 million in land rents it paid to landowners on behalf of oil and gas companies last year, data obtained by The Narwhal via a freedom of information request reveals.

Industry paid back just $302,000, or less than four per cent of what was owed in 2019 — a continuation of a trend that has seen companies rack up nearly $30 million in rent debt to the government since 2010.

“If companies can’t afford to pay landowners to operate on private land, that’s a flashing red light that something is terribly wrong,” Regan Boychuk of the Alberta Liabilities Disclosure Project told The Narwhal.

“There’s no effort afoot to solve this problem,” he added.

Companies are supposed to pay rent to landowners when they drill a well on their land. If a company doesn’t pay, a landowner can apply to the Government of Alberta’s Surface Rights Board for compensation. The government is then tasked with recouping that money from delinquent oil and gas companies.

But data shows it is seldom successful.

Since 2010, Alberta oil and gas companies have racked up nearly $30 million in debt to the Alberta government in this way.

Data obtained through freedom of information requests shows only $638,000, or just over two per cent, has been recovered over that period.

The total amount paid out by government to landowners on behalf of delinquent oil and gas companies has skyrocketed in recent years, increasing 1,183 per cent since 2010. Data: Surface Rights Board / FOIP request with Alberta Environment and Parks. Graph: Carol Linnitt / The Narwhal

Meanwhile, the amount paid out by the government for land rent on behalf of delinquent oil and gas companies has increased 1,183 per cent since 2010.

At the same time, the province’s Orphan Well Association has been loaned more than half a billion dollars in recent years and in April the struggling conventional oil and gas industry in Alberta has been handed $1 billion in grants from the federal government to plug and clean up inactive wells languishing on the landscape, to be administered by the provincial government.

The Government of Alberta is currently accepting applications for the second phase of the $1-billion grant package, with $100 million earmarked specifically for the cleanup of sites owned by companies for which taxpayers have had to pay their land rent. For accepted wells, the government will now also pay for 100 per cent of well plugging and cleanup.

“We have to start asking the question, ‘why can’t they pay basic bills?’ ” Boychuk said. “And that leads to some uncomfortable answers about the future of the industry.”

In 2019, less than four per cent of the more than $8.4 million paid out by government on behalf of delinquent oil and gas companies was recouped, leaving taxpayers to cover the rest of the bill. Data: Surface Rights Board / FOIP request with Alberta Environment and Parks. Graph: Carol Linnitt / The Narwhal

‘Gaming the system’

There are more than 336,000 oil and gas wells across Alberta, according to the provincial government. Many of them are on private land. 

If a company fails to pay the annual rent they have agreed on, the landowner can apply for a “recovery of rentals” from the Surface Rights Board, as per the Surface Rights Act, and receive their compensation from Alberta’s general revenue fund. That’s taxpayer money.

The Narwhal reported last year that the tab for taxpayer money paying land rent on behalf of oil and gas companies was already $20 million. It’s now grown by close to $10 million, according to data provided to The Narwhal by the Surface Rights Board. 

This is supposed to be a temporary fix, as the government is then meant to recoup taxpayers’ money by tracking down the company and collecting the funds. 

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When an application is addressed, the board will try to contact the company and order them to pay. If that doesn’t work, the board directs the Minister of Environment and Parks to pay the landowner out of the government’s general revenue. (Alberta Environment and Parks and the Surface Rights Board did not reply to requests for an interview by publication time.)

To Daryl Bennett, a farmer and director with the landowner group Action Surface Rights, who has spent years trying to help landowners get the payments they’re owed, the government’s efforts are seldom enough.

“In the past, there’ve been cases where they just didn’t try,” he said. In those cases, barring a company from the site will have little effect, as the well is likely inactive anyway

Bennett said he believes companies have learned that skipping out on land rent can be a way to cut their costs.

“It’s just the way the system is — the way the law is. If companies don’t pay, the government is supposed to step in,” Bennett told The Narwhal. “A lot of companies have learned to game the system and take advantage of it.”

“It’s the business. When times are good, it’s good,” he said. “When it’s not, then they easily socialize the losses.”

“They’re just abusing the system to cut payments to landowners and kick the can down the road for years,” Bennett said.

Daryl Bennett of landowner group Action Surface Rights. Photo: Theresa Tayler / The Narwhal

Companies ‘just don’t have the money’

Boychuk points to a number of other bills many oil and gas companies have been struggling to pay in recent years, from municipal taxes to levies owed to the Alberta Energy Regulator. 

“A lot of those companies just don’t have the money,” Bennett said, noting that this was a problem prior to the COVID-19 pandemic, too.

“Even before the pandemic, a bunch of them were hoping that the oil price would rise enough that they could sell their stuff to somebody and get their money out of it. They were already underwater,” he said.

Then the pandemic hit, flattening demand at the same time a global supply glut pushed benchmark prices into negative numbers.

Jay Averill, media relations manager for the Canadian Association of Petroleum Producers, told The Narwhal that current events have forced many oil and gas companies into financial hardship.

“Since the middle of March over $8.6 billion in capital expenditure cuts have been announced in the Canadian upstream oil and gas sector,” Averill said in an emailed statement. “This is in response to the low commodity prices resulting from the global economic slowdown caused by the COVID-19 pandemic along with the oil price war between Saudi Arabia and Russia.”

Others, like Boychuk, point to a longer-term trend of reduced profitability in the oilpatch, noting it’s not just the pandemic that has pushed companies into the red. Either way, unpaid bills have been increasingly falling on taxpayers, often the same people most affected by the volatility of the industry.

“It’s a catch-22 situation,” Bennett said. “If you force [companies] to pay, they go bankrupt. Then they don’t pay anything and you lose all the jobs and everything else.”

New head of Alberta Energy Regulator wants to rebuild confidence in leadership

Laurie Pushor comes into the role with some criticism from opposition critics in both Saskatchewan and Alberta

The Canadian Press · Posted: May 02, 2020 8:59 AM MT | Last Updated: May 2

The newly-appointed chief executive officer of the Alberta Energy Regulator says he wants to rebuild confidence in the industry and the regulator. (Government of Saskatchewan)

Like a sports coach coming off a disappointing season, the new head of the agency that regulates Alberta’s heavily challenged energy industry knows he’s got some work to do.

“One (goal) is rebuilding confidence in the leadership internally,” Laurie Pushor said in an interview.

“Confidence in the public and government and the industry that we are a good team of people and that we’re doing our best and that we’re open to continuing to improve.”

Pushor, two weeks into the job, replaces Jim Ellis as boss of the Alberta Energy Regulator. Ellis left last November after investigators found serious mismanagement, misuse of about $2.3 million and a “culture of fear” among whistleblowers.

“Improvement will include continuing to strengthen transparency and continuing to strengthen accountability for our performance,” Pushor promised.

Pushor also comes into the role under a cloud of doubt, say opposition critics from both Saskatchewan and Alberta. 

He was a central figure in a Saskatchewan government land-deal scandal that cost taxpayers millions of dollars — and the subject of a scathing audit — prompting an RCMP investigation. 

That’s not the only challenge he and the energy regulator face.

There’s an enormous backlog of abandoned and orphaned wells that will cost someone billions to clean up. There are difficult relationships between the regulator, First Nations and landowners.

And there’s the industry itself for which profits and reserves are declining.

Don’t count Alberta out yet, said Pushor. Notwithstanding the uncertainties of COVID-19 and international oil price wars, there’s still money to be made, he said.

“If you look at recovery rates and the innovation that industry is applying to known reserves, not only might we not be presiding over an industry in decline, but you might see a bit of a renaissance in conventional production.”

Rebuilding trust with First Nations is another priority for Pushor. In his previous job as Saskatchewan’s deputy minister of energy and resources, he worked with a traditional knowledge-keeper, he said.

“He is relentless in reminding me that it’s about relationships,” said Pushor, who promises plenty of face-to-face time with Indigenous leaders.

“If you’re not in a relationship, you’re not going to be able to move things forward. We, as the regulator, need to be in a good relationship with First Nations.”

Pushor wants the same kind of contact with landowner groups, who have often been critical of how industry uses their land and treats them.

“It’ll start with three or four of the larger groups out there that have organized. I look forward to catching up and understanding their issues and seeing what can be done to move things ahead.”

When it comes to cleaning up wells, Pushor acknowledges he’s got some work to do to grasp the legal ins and outs. Critics have long pushed for a legislated timeline for dealing with old infrastructure and say that the province’s calculations on whether a well owner has the wherewithal for cleanup are antiquated.

Pushor asks for a little time to dig into those issues.

“The government’s the policymaker,” he said. “They’re going to give us the framework they want us to operate in.”

There’s an inevitable tension between business, environmental and public concerns, Pushor said.

“That tension is real and it should be. What makes a regulator effective is ensuring that tension is balanced.”

Critics say Pushor’s involvement in the Saskatchewan scandal should have disqualified him from the position, and that checkered past will make it difficult for the AER to restore its reputation.

Pushor believes the public still has faith in the AER, despite its internal and external problems.

“Confidence in the industry and the regulator, while they may have eroded somewhat, remains relatively stable. But we can always do better and we should.”

Orphan wells cleanup funding ‘a subsidy to industry,’ says Alberta farmer

Daryl Bennett is grateful for the $1.7M fund, but says companies that abandoned the wells should foot the bill

CBC Radio · Posted: Apr 17, 2020 6:02 PM ET | Last Updated: April 17

The federal government says it will employ thousands of people to clean up abandoned oil and gas wells — but an Alberta farmer says the companies responsible for the mess should be the ones footing the bill. 

Prime Minister Justin Trudeau announced on Friday $1.7 billion to clean up orphaned and abandoned oil and gas wells in Alberta, Saskatchewan and British Columbia, which he estimates will help create 5,200 jobs in Alberta alone.

“Our goal is to create immediate jobs in these provinces while helping companies avoid bankruptcy, and supporting our environmental targets,” Trudeau said.

Taber, Alta., farmer Daryl Bennett, a surface rights activist representing landowners across the province, has long had an orphan well on his property. Here is part of his conversation with As It Happens guest host Piya Chattopadhyay.

What do you make of the federal government ponying this $1.7 billion up? 

Let’s make no mistake. It’s a subsidy to industry.

Industry should have put the money aside to do this. So there’s lots of executives of those companies that have left with millions of dollars of profits or more, and now they’ve left the taxpayer to foot the bill. 

But society has benefited from the cheap oil and gas development, and it was taken on condition the landowners’ lands would be reclaimed. So since society allowed the system to be abused, society has a responsibility to make sure these wells are cleaned up. 

How far does the $1.7 billion go?

Well, they haven’t really announced exactly how that money is being spent. We’re assuming that they might be trying to put some of these sites into renewable energy. Some of the counties might be getting some money. 

But if it all went to reclaiming wells, you’re probably looking at an average $100,000 to $200,000 per well. So it’ll do some wells, but it’s certainly not going to solve the problem.

Prime Minister Justin Trudeau announced $1.7 billion to clean up orphan wells in Alberta, Saskatchewan and British Columbia, and aid for rural businesses and people working in the arts and culture sectors.

What are your fellow landowners saying about today’s announcement?

There’s lots of landowners that are happy that these wells will be cleaned up. They’ve been an eyesore on their lands. They’ve had weeds around them. They’ve been a safety hazard, a food safety hazard. So they do like seeing them get reclaimed. 

Now, you say this money is coming from taxpayers, but the oil and gas companies that abandon the wells aren’t rushing to clean them up. So how else was the problem going to be solved?

Industry was supposed to pay a levy sufficient to reclaim these wells. So, you know, a lot of these companies have gone bankrupt. They’ve privatized the profits and they’ve left. And now it’s left to the taxpayer or the remaining companies to to pay for the cleanup.

So the system was supposed to ensure that the polluter paid. That system was abused. It was not enforced. And now it’s left to the taxpayer.

You used the word “abused” there. … What exactly do you mean by that? 

A lot of these sites have sat there for 30, 40 years. Our landowner associations have been telling government that this was a problem waiting to happen for 20 years. And so they didn’t enforce any timelines on when these wells should be reclaimed.

So these companies now have learned that they can abuse a system. They don’t have to pay the landowner. They don’t have to pay the property tax. And now it appears they don’t have to pay to reclaim the land either.

That’s a pretty good business model when you’re allowed to suck the resources out and not have to pay any of the environmental or social liability costs for doing so.

With more job losses and companies going bankrupt, more orphan wells, what can your province, the province of Alberta, do to force these companies to take responsibility for these abandoned wells?

They probably can’t do anything now with the low oil prices. A lot of them aren’t even paying the property taxes. They’re not paying the orphan well levies. They’re not paying the annual rentals. They don’t have the money.

If they were forced to pony up the money, they’d all go bankrupt. So it’s a catch- 22 situation. The horse is out of the barn.

They should have addressed this a few years ago when oil was $100 a barrel, but they didn’t. And now the money’s not there. And subsequently, it’s left to the taxpayer to foot the bill. 

Oil and gas has seen a steep downturn even before COVID-19 came along. Is the orphan well problem about to get worse? 

Yes, it is about to get worse. 

The prime minister says this project will put 5,200 people back to work in Alberta alone. The Canadian Association of Petroleum Producers is expecting about 10,000 jobs to be created out of this announcement today. How big of a deal is that announcement in Alberta? 

It’s huge for Alberta. Our economy is way down. A lot of workers in these oil companies have been put out of work. Now they’ll at least have a job and they’ll be able to pay taxes.

What kind of workers do you expect will be doing the cleanup?

Well, that’s interesting, because we’ve heard that a lot of the contractors that put the wells in are now the ones being hired to take the wells out. And we do know there are some abuses in the system. And we’ve let the Orphan Well Association know that some of that is occurring. 

But it’s a lot of the oil service companies that have had to lay off people that will now be able to hire them back and put them to work in reclaiming these wells.

How soon do you expect crews to be on your property cleaning up that orphan well of yours?

The Orphan Well Association has been doing a very good job.

They were about to run out of money in the next two years because the provincial money was going to run out and they’re just wondering what they’re going to do.

So this $1.7 billion will allow them to continue to operate as they have been, and to do a little bit more than they have been doing.

Written by Sheena Goodyear with files from CBC News. Interview produced by Jeanne Armstrong. Q&A has been edited for length and clarity.

Alberta to give $100-million loan to decommission orphan wells

Lauren Boothby

Edmonton Journal

Updated: March 2, 2020

Alberta is offering a $100-million loan to decommission 800 to 1,000 orphan wells, a move that is expected to create 500 direct and indirect jobs in the oil services sector.

The investment to the Orphan Well Association (OWA) will help the non-profit start 1,000 environmental site assessments that aim to return the land to its condition before the wells were built. The details on the loan will be finalized by April 1.

Premier Jason Kenney said the funds will provide a “lifeline” to oilpatch workers hit by layoffs.

“This is a very important announcement about getting oilfield workers back to work right now when we need it, there is more investment coming into the oilpatch. And we believe there’s a path forward through pipelines,” Kenney said at Savanna Well Servicing in Leduc on Monday morning.

In 2017, Alberta gave the OWA an interest-free $235-million loan to clean up orphan wells across the province. The Financial Post reported in December that there are still more than 15,000 wells drilled before 1964 that have not been remediated. The OWA sent a letter to the Alberta Energy Regulator in January, saying the province’s rules around reclaiming abandoned oil and gas wells are inadequate.

Lars De Pauw, executive director of the association, said at the news conference Monday the organization has about 6,500 abandoned sites in its inventory. He said the loan will help speed up reclamation and reduce the impact to landowners hosting abandoned wells.

Energy Minister Sonya Savage said the $100-million loan is an example of how the government is ensuring the oil and gas industry can be successful and responsible.

“Meeting their obligations includes bearing the cost of cleaning up inactive and orphaned wells. Because of recent challenges, orphan wells are becoming a growing concern in Alberta. And to be frank, it’s a situation that needs to be addressed,” she said. “Our government recognizes the pressing need to turn the tide on growing oil and gas liabilities.”

Savage said the funds would also create indirect jobs with suppliers, equipment and service providers, mechanics, and concrete manufactures, as well as local businesses as cleanup crews visit different communities. She also reiterated the government’s plans to release a suite of new laws that would address orphan wells in the next few weeks.

Irfan Sabir, NDP’s critic for energy and natural gas, said he’s glad to see funding to clean up wells, but questions the party’s decision to frame the investment as a job-creating tool.

“It’s not a long-term solution. They’re saying they will create 500 direct and indirect jobs, but since they took office we have lost 50,000 jobs,” he said. “I think they need to invest more in diversification, of creating, refining, opening new markets so Alberta can get back to work.”

Major oil and gas investment to be announced this month

Last week, Kenney hinted the province may invest in a major oil and gas project. On Monday, he said details on that project would be announced by the end of the month that show “the government of Alberta’s commitment to getting pipelines built, the key part of infrastructure for the future.”

[email protected]

@laurby

Unpaid bills: Are rural Albertans growing tired of carrying the freight for delinquents in the oilpatch?

There are calls for consolidation as some companies fail to pay their taxes

Kyle Bakx · CBC News · Posted: Jan 30, 2020 4:00 AM ET | Last Updated: January 30

Sequoia Resources remains in receivership after ceasing operations in March 2018. (Kyle Bakx/CBC)

There is no denying how much the oilpatch has provided Alberta over all these years — the jobs, tax revenue, government royalties and economic activity — a benefit to nearly every corner of the province, no matter how remote.

It’s oil and gas funding community centres and arenas. It’s oil and gas revenues helping pave rural roads. It’s oil and gas building the tallest office towers in Western Canada.

At least, until recently.

The prolonged downturn in prices has taken the shine off the industry and affection for the sector is also taking a hit.

Last week, rural towns and municipalities announced they are owed $173 million by oil and gas companies in unpaid taxes.

There’s also the revelation the Alberta Energy Regulator is purposely collecting a lower amount from some companies to prevent more of them from going bankrupt. The security deposits are supposed to help cover the cost of cleaning up old oil and gas wells, if those companies fail and no one buys the assets.

On both fronts, some argue, Albertans are giving industry a subsidy. 

Raising taxes, slashing services

With the outstanding tax balance, many rural towns and counties are faced with raising taxes on other businesses and homeowners and slashing services. The regulator’s shortfall in security deposit increases the likelihood more government money will be needed in the future to clean up wells.

The situation has some people wondering whether it’s time for a reckoning for Alberta’s delinquent oilpatch companies. 

Make no mistake, the majority of companies are paying their bills and are spending money every year to properly reclaim their oil wells. 

There is a debate in Alberta about whether to give industry a break or find a way to make companies pay. (Kyle Bakx/CBC)

Still, there are black sheep — mainly smaller oil and gas companies.

They are behind on their bills and teetering on the edge of going belly up.

With so much uncertainty surrounding future oil or natural gas prices, maybe some of these smaller companies won’t last, regardless of whether they are subsidized or not.

Opinions are pretty split. On a provincial CBC Radio call-in show on the oilpatch tax issue, half of the people demanded companies pay up, while the other half said the industry deserved a break.

Time to purge

The tax shortfall is throwing municipal budgets into a tailspin.

The Municipal District of Taber in Southern Alberta is owed more than $2 million from oil and gas companies, which represents close to 10 per cent of its budget.

As a result, the municipality has laid off workers, halted the replacement of equipment, and scrapped plans for road improvements and a recreation centre. There’s no money for anything new.

Of the 44 oil and gas producers operating in the municipality, 15 did not pay their taxes.

“Some of them are actually bankrupt and out of business, but some are just choosing not to pay because there is nothing to force them to pay,” said Reeve Merrill Harris on CBC Radio’s The Calgary Eyeopener.

“If you’re a viable, active company, taxes shouldn’t be an option. They should be something that has to be paid.”

Other municipalities are also raising taxes.

That’s got rural landowners complaining about a “triple whammy” of grief with the oilpatch.

Many farmers aren’t getting the full payment from energy companies to use their land, taxes are going up as municipalities aren’t getting paid, and, if they have a geriatric well on their property, they don’t know when it will get cleaned up.

That’s why there is talk in some rural communities of getting rid of the deadbeats.

Landowner Dwight Popowich doesn’t buy the argument that oilpatch companies need a break.

“In my mind, it’s time to consolidate the industry, get the weak players out of the system, get the resource back in the hands of financially stable companies. That’s our problem,” said Popowich, who owns land near the town of Two Hills.

The inactive natural gas well on Dwight Popowich’s land has not produced anything since 2012. The owner has since ceased operations. (Kyle Bakx/CBC)

If a small company can’t afford to pay bills, nor afford its eventual cleanup costs, maybe it shouldn’t still be operating, critics say.

The industry is receiving other assistance too. The provincial government introduced a 35 per cent municipal tax break for shallow natural gas producers. The province also lowered the corporate tax rate.

The financial hand-holding of the industry needs to end, according to former Alberta Liberal leader David Swann.

“What other industry, what other corporation is getting this kind of treatment?” he said. “We are just propping them up year after year and ignoring the fact that they are an industry on the way out.”

A reckoning on tax burden

For the oilpatch, the tax issue isn’t anything new. The problem surfaced more than a decade ago and companies have argued for years that their municipal tax bills are escalating too quickly.

Canadian Natural Resources, the largest oil and gas producer in the country, previously said its property taxes swelled five times more than its revenues from 2004 to 2014.

CNRL, of course, still has healthy profits. In the latest quarter, it posted earnings of $1.23 billion, compared with $1.35 billion a year earlier.

It’s the smaller companies that are at higher risk of going belly up.

These companies have employees, investors and suppliers, and are often spending money in parts of the province with limited economic activity.

During the downturn of the last five years, the oilpatch’s pain has been felt across many other sectors, such as rural hotels, for instance.

Before demanding these companies pay their taxes and full deposits to the regulator, some argue the financial fallout should be considered.

In 2019, Trident Exploration ceased operations. Over the last five years, several oil and natural gas producers have closed their doors. (Kyle Bakx/CBC)

The whole sector is already under enough stress and there’s no need to add more pressure, according to Brad Herald, with the Canadian Association of Petroleum Producers.

Forcing companies into bankruptcy would have repercussions.

“That’s challenging for the workers and communities involved where they operate,” he said.

There’s no need to add more financial pressure on the oilpatch, according to Brad Herald, with the Canadian Association of Petroleum Producers. (Kyle Bakx/CBC)

The industry points out that the value of oilpatch assets has declined over the last five years, but taxes haven’t.

“There has to be a meeting of the minds,” said business commentator Deb Yedlin on The Calgary Eyeopener. “The formula that exists today is not reflective of the reality.”

Although the issue may not be new, it seems to be getting worse.

Some in the oilpatch say municipalities should reconsider how much companies are charged in taxes.  Others argue a reckoning has already happened in the oilpatch as the downturn has claimed dozens of companies.

What happened in Texas?

A historical case study from Texas shines some light on what could happen when oil and gas companies are forced to pay up.

In 2001, the state’s regulator decided to increase the amount industry owed as security toward eventual cleanup of oil and gas wells.

Small companies were upset, arguing it would drive them out of business.

They were right, although it wasn’t necessarily a bad thing.

University of California San Diego economics professor Judson Boomhower crunched the data and concluded small companies were largely bought up by larger companies. 

Oil and gas production remained steady and the sector’s environmental performance improved with fewer of the smaller players.

His findings were released last year in the American Economic Review.

A similar outcome could happen in Alberta, said Boomhower. One big difference, though, is the province’s large number of inactive oil and gas wells. If smaller firms go belly up, some of those wells may become orphans.

“There is a huge population of idle wells [in Alberta], so I do think that is a risk you have to take seriously,” he said.

Alberta has about 94,000 inactive wells and 3,400 orphan wells. (Kyle Bakx/CBC)

The risk of more orphans begs the question whether the wells were likely to become orphans in the next few years anyway, or whether some of the wells would likely have been properly reclaimed by operators.

Alberta has an industry-funded association that handles orphan wells, the Orphan Well Association, which is already underfunded and has a backlog of sites. Still, government money already has been spent to help with the growing backlog of wells, pipelines and facilities needing cleanup.

That’s why the Texas case study provides some useful insight, but the impact of a reckoning for unpaid bills isn’t clear, for the environment or rural Alberta.

Group cleaning up old oil wells says Alberta government rules inadequate

8 hrs ago

The Canadian Press

EDMONTON — A group tasked with cleaning up thousands of abandoned energy facilities in Alberta says the province’s rules for ensuring polluters reclaim their wells before selling them off are inadequate.

The industry-funded Orphan Well Association made the criticism in a letter to Alberta’s energy regulator, which is considering a proposed transfer of hundreds of toxic gas wells, pipelines and other facilities from an energy giant to a much smaller company.

“The (association) has seen a dramatic increase in the number of orphan properties over the last several years and we believe part of the issue stems from a historically inadequate assessment of the transfer risks,” says the letter from association head Lars DePauw.

“The (association) believes that the current regulatory system for assessing the overall financial viability of asset transfers is not adequate and needs to be augmented.”

Shell Canada has agreed to sell 284 sour gas wells, 66 facilities and 82 pipelines in the southern Alberta foothills to Pieridae Energy, a Calgary-based company with a market value less than the price of the assets and a stock price under $1.

The Alberta Energy Regulator must rule on the licence transfers at a time when the inventory of energy facilities abandoned by bankrupt companies grows.

The number of wells transferred to the association sits at 3,400. Alberta has budgeted more than $70 million for cleanup by 2023 — a more than 50 per cent increase in otherwise belt-tightening times.

“We believe that the applications represent an extraordinary situation in the current Alberta market,” the association said in the Dec. 5 letter.

Pieridae has said it will retain Shell employees who are expert in handling sour gas. It also said the transaction meets provincial rules that stipulate a purchaser’s assets must be at least twice its liabilities before licence transfers are approved.

Regan Boychuk of the Alberta Liabilities Disclosure Project, a group of academics and landowners who have filed concerns about the Pieridae transfer, said those measurements are not credible.

Assets are calculated on the basis of the average industry profit per barrel of oil. That figure — now $37 — hasn’t changed since 2010, when oil sold for about $100 a barrel.

That average is supposed to be recalculated every three years, said Boychuk.

“The regulator has never followed its own policy,” he said. “It is not a proper accounting of the cost of this type of work.”

Concerns about the transfer are shared by at least two major energy companies.

“Pieridae has been operating at a loss since it began operations,” said a letter from Cenovus to the energy regulator. “Material uncertainties exist around their ability to continue as a going concern.”

“Pieridae Energy Limited (has) limited on-hand financial resources to address the current and future liabilities associated with operating the assets,” said Canadian Natural Resources.

“If the licence transfers are allowed, there is a high probability that Pieridae will be unable to respond to circumstances should any operational, health, safety or environmental problems arise.”

Both companies said the association could get stuck with a $500-million bill if Pieridae is unable to clean up.

Worries about safety and cleanup are echoed by 14 area landowners.

“This looks like the old shell game,” wrote Michael O’Keefe of Cochrane.

Sharon Rubeling of Rocky Mountain House points out Pieridae is partly financed through a Toronto company behind a previous asset transfer that eventually left hundreds of wells orphaned.

She adds that Albertans are already invested in Pieridae through loans from AIMCo, which administers public pensions in Alberta. AIMCo also owns five million shares in Pieridae.  

This report by The Canadian Press was first published Jan. 15, 2020

— Follow Bob Weber @row1960 on Twitter

Bob Weber, The Canadian Press

Alberta ranchers, farmers furious over oil and gas companies’ failure to clean up their geriatric wells

And they’re concerned an extra 93,805 wells could become orphaned given Alberta’s economic outlook, completely overwhelming clean-up efforts

Geoffrey Morgan

Updated: December 18, 2019

Calgary Herald

An oil gauge likely from the 1970s at an old well site. Alexa Althoff for National Post files

Geriatric orphan wells, boomtowns going bust and the fate of coal-mining towns in the age of renewables: In a four-part series, FP visits Alberta’s forgotten small communities to see how they are struggling with changes in the broader economy.

CALGARY – In 1897, a German aristocrat named Count Alfred von Hammerstein was on a journey to the Yukon, where he hoped to make a fortune during the Klondike gold rush. As he arrived in what would later be called Alberta, he decided to stay and try to exploit the reserves of black gold in the oilsands.

Von Hammerstein raised money to sail drilling crews down the Athabasca River on sometimes ill-fated expeditions north of Fort McMurray. On one river trip, two members of the crew drowned. On another, the count’s leg was injured in what historical records vaguely describe as a “shooting accident.” In the end, the 14 wells he drilled, all before 1909, were unsuccessful.

The count learned “the oilsands would not give up their secrets easily,” according to an Alberta government report written in 1978, but he has since been ensconced as “one of the most colourful characters” in the Canadian Petroleum Hall of Fame.

But one of the wells von Hammerstein drilled has a more inglorious history. The well, drilled in 1906 or 1907 near the First Nations community of Fort McKay, is believed to be the province’s oldest orphan well, meaning nobody is financially responsible for cleaning it up.

Von Hammerstein died in 1941, long before wildcatters needed reclamation certificates for the wells they drilled. Indeed, the count never even obtained a drilling licence.

That well may be the oldest orphan, but it’s not an outlier since there are some 3,406 orphan wells listed in the Orphan Well Association’s clean-up list and that’s not sitting well with landowners.

Farmers, ranchers and their lawyers say they’re furious that oil and gas companies are failing to clean up after themselves and they’re concerned that an additional 93,805 inactive wells could become orphaned given Alberta’s economic outlook, which would completely overwhelm both the Alberta Energy Regulator (AER) and the provincial government.

“The claim that Alberta’s oil and gas is the most ethically produced oil because of the environmentally and socially responsible way in which it’s produced is true only to an extent, and where it’s not true and where the government and industry need to up their game is in dealing with the legacy wells,” said Keith Wilson, a St. Albert, Alta.-based lawyer who represents landowners in fights with energy companies.

An abandoned oil well site in Alberta. Codie McLachlan/Postmedia files

Wilson said farmers and ranchers have historically counted themselves among the energy industry’s biggest supporters and they routinely sign lease agreements that allow companies to access their land. But the relationship has soured as Alberta’s economy has tanked and landowners encounter problems with both collecting rental payments and getting companies to clean up old contaminated sites.

Geriatric orphan wells such as Von Hammerstein’s are a particular sore spot for farmers, because older wells are more likely to contaminate the ground, are more difficult to clean up and take more time to remediate since they were drilled in an age when environmental standards were more lax.

Wilson, who has fought in court to force delinquent companies into cleaning up geriatric wells, said older wells are also more likely to be plagued with rusted out down-hole equipment and he frequently sees wells with cracked cement linings, leading to an increased likelihood that contaminants will flow into the earth.

Moreover, he said, most oil and gas companies prior to the 1990s used pits, dug right next to a well, rather than tanks, to store the fluids and mud used in drilling the well and production. Those pits, he said, dramatically complicate the remediation efforts of older wells because freezing and thawing every winter and spring sends the contaminants deeper into the ground, further spreading any contamination.

Satellite images show one old orphan well near Lloydminster, on the Alberta/Saskatchewan border, encircled by an unnaturally dark shade of brown. The well was drilled during the Second World War on July 25, 1941, and produced a total of 17,052 barrels of oil. Now, 78 years later, it has yet to be fully remediated.

Abandoned oil tanks at a site in Alberta. Ian Willms/Getty Images files

 “If you’re an oil company and you’ve got 1,000 old inactive wells and you’ve got 100 new inactive wells, you can probably clean up all those new minimum-disturbance, coal-bed methane wells for the cost of cleaning up one or two of those old historic 1950s-era wells,” Wilson said.

In November 2018, the AER issued a statement that pinned the environmental liability for cleaning up oil and gas infrastructure in the province at $58.65 billion. That admission came after one of the regulator’s vice-presidents said during a presentation that the number could be as high as $260 billion, a figure that included oilsands mining remediation.

Either way, the problem is daunting.

The Financial Post sorted through well data from before 1964, the year the Alberta government started requiring companies to obtain reclamation certificates for cleaning up their oil and gas wells, and found 6,077 wells that are still active today. An additional 5,487 wells have suspended production but have not been cleaned up, and 3,695 wells have been plugged, a state the industry and government calls “abandoned,” but not remediated.

Altogether, there are 15,259 wells drilled before 1964 that have not been remediated, or 39.6 per cent of 38,491 wells drilled before that date.

In addition, 18,266 of the wells drilled prior to 1964 are exempt from reclamation certificates.

“Not every old one is complicated,” said Lars DePauw, executive director of the Orphan Well Association (OWA), which is funded through a levy paid by the industry and collected by the AER.

An abandoned oil-well site west of St. Alberta, Alta. Codie McLachlan/Postmedia files

DePauw said the association prioritizes wells to clean up by their potential threat to public safety. Any well that could be releasing hydrogen disulphide gas is cleaned up first. He said the OWA targets wells in specific regions in area-based closure programs. “After that, we get to chronology,” he said.

Since November 2018, the OWA has been working on Von Hammerstein’s orphan well. It first plugged the well with cement, monitored it for a year and then capped the well bore last month, though additional work is being planned.

The OWA had been remediating 60 wells per year, but the oil price crash and resulting bankruptcies have forced the association to increase that to 1,000 annually.

One of the largest single funders of the OWA, by virtue of its size, is Calgary-based Canadian Natural Resources Ltd.

According to farmers and surface rights lawyers, CNRL, which produces more than one million barrels of oil and gas per day, is also one of the most active at cleaning up.

The company is a “top performer” in the number of inactive wells it reclaims, spokesperson Nicholas Gafuik said in an emailed statement. “In 2018, we abandoned 1,293 wells and submitted 1,012 reclamation certificates. In 2019, Canadian Natural is targeting approximately 2,000 wells to be abandoned.”

Gafuik said the company supports the AER’s area-based closure approach because it accelerates the pace of reclamation by being cost effective. “By strategically grouping well and pipeline abandonment by area, we increase efficiencies and manage our impact on the land better,” he said.

A Canadian Natural Resources Ltd. oilsands mine. Ryan Jackson/Edmonton Journal files

Farmers and lawyers praise CNRL’s pro-activeness and the OWA’s attempt to accelerate remediation efforts, but remain concerned by the magnitude of the problem. At the current pace, it would take the OWA and CNRL, the two most active well remediation organizations in the province, 32 years to clean up all the inactive and orphan wells in Alberta.

Daryl Bennett, a farmer in the Municipal District of Taber, said he has wells drilled in the 1940s and 1950s on his property. He calls them “bottom dwellers” and his frustration getting them remediated led him to get involved with local surface rights groups and advocate on behalf of farmers and ranchers dealing with oil and gas producers.

Given the challenges inherent in cleaning up older wells, Bennett said he and other landowners in Southern Alberta have been seeking approvals to build solar power installations on top of old well sites. Renewable power installations, he said, would allow farmers to earn money off land that has previously been contaminated.

“At some point, (the Alberta government or the OWA) are going to be buying some land,” he said.

Other landowners are concerned that given the dire state of Alberta’s economy — anemic economic growth, provincial government austerity budgets and low commodity prices — the unfunded liability will be dropped on farmers and ranchers.

“Knock on wood, hope the landowner won’t be doing the reclamation,” said Graham Gilchrist, principal at Gilchrist Consulting in Leduc, who advises farmers and ranchers in the area around Edmonton on dealing with orphan wells and delinquent rental payments from energy companies.

Gilchrist and Bennett both believe Alberta needs a bonding system that forces companies wanting to drill a well to first post collateral so that neither taxpayers nor landowners are ever responsible for the costs of cleaning up orphaned or inactive oil wells.

Daryl Bennett. Theresa Taylor for The Narwhal

Lawyers and researchers have also described the need for legislated time limits on cleaning up inactive wells, which they said would dramatically reduce the backlog of 93,805 inactive wells that could be tomorrow’s orphans.

In both Texas and North Dakota, two states that produce large volumes of oil and gas, bonds and time limits have resulted in far fewer orphaned wells and fewer long-term inactive wells than exist in Alberta. Texas was also able to reduce its backlog of orphan sites.

In years past, the Alberta government and industry groups have resisted set time limits to clean up old wells because they said inactive older wells can still be economically viable during periods of higher oil and gas prices.

But historical data show that 60-year-old wells only have a one-per-cent chance of being reactivated in that scenario, according to a study by University of Calgary economist Lucija Muehlenbachs that was published in the International Economic Review in February 2015.

“The probability that an inactive well is going to be reactivated decreases the older it is,” she said. “These inactive wells are not getting reactivated.”

Time limits in Alberta have been successful in the past, but the province has not required bonds prior to drilling activity.

Alberta regulators first introduced a “special well fund” to finance the cost of plugging wells in 1986. Then, in 1993, the government introduced the first levy for orphan wells and began screening the risk that oil and gas companies might orphan their wells by keeping a ratio of how many inactive wells a company owns relative to its active wells.

The government in 1997 then implemented the Long Term Inactive Well Program, which pushed oil and gas companies to be more proactive within stricter time limits.

“That 1997 program was pretty effective,” said Barry Robinson, a lawyer at Ecojustice Canada who acts on behalf of farmers and ranchers, noting that the program included a five-year time frame for plugging inactive oil and gas wells.

That program was replaced in 2000 with the current system that does not include time limits on well remediation.

Robinson said one client in Pincher Creek, in the southwestern corner of the province, has a well that was drilled on his land in 1957.

“This well was drilled when his father owned the land and now he’s saying, ‘I don’t want to pass this onto my kid,’” he said, noting the problem has become an intergenerational one.

This well was drilled when his father owned the land and now he’s saying, ‘I don’t want to pass this onto my kid’

Barry Robinson, a lawyer at Ecojustice Canada

In 1995, Robinson said, there were 12,000 inactive wells in Alberta, but that has since ballooned 680 per cent.

A February 2018 presentation by Robert Wadsworth, AER vice-president, closure and liability, showed the number of inactive wells has grown at a rate of six per cent per year since 2000.

Alberta’s current government faces a dual challenge when dealing with the problem. Farmers and ranchers voted in massive numbers for the United Conservatives in the provincial election earlier this year, helping UCP candidates beat NDP candidates in many rural ridings by tens of thousands of votes. However, the UCP also promised to reinvigorate the energy sector by removing red tape and encouraging investment.

Now, with two parts of the government’s support base locked in fights over orphan wells, delinquent rental payments and rural property tax arrears, the province is reconsidering existing legislation as it conducts a full review of the AER.

An abandoned well site in Alberta. Codie McLachlan/Postmedia files

 “Currently, the government is working with the Alberta Energy Regulator and industry to review the liability management framework in Alberta,” Energy Minister Sonya Savage said in an email. “Our government wants to ensure that the economic environment exists for private industry to be successful and able to bear the costs of well abandonment.”

In recent weeks, Premier Jason Kenney has asked Ottawa for financial assistance to help remediate orphaned wells as a way to put unemployed oil and gas workers in rural areas back to work.

Various provincial governments in Alberta, including the recently ousted NDP, have formed panels on how to handle the problem of orphan wells, but it has only continued to grow in the 114 years since Alberta was formed.

Indeed, Alfred von Hammerstein’s orphan well north of Fort McMurray has remained unremediated for almost the entire history of the province, which was created by former prime minister Wilfrid Laurier in 1905. Thousands of other old inactive wells and legacy orphan wells have never been cleaned up either.

“What we’re seeing is a complete lack of action,” said Wilson, adding that company money during oil booms typically gets allocated to new drilling programs, while government money is allocated to building new infrastructure. “The excuse that these wells can be economic and reactivated if prices return to historic highs is false, because we’ve been through those cycles and no work has been done.”

Financial Post

As Alberta energy companies struggle to pay their bills, farmers, ranchers and counties feel the pinch

Geoffrey Morgan

December 12, 2019
11:29 AM EST

Last Updated
December 13, 2019
11:48 AM EST
Financial Post

Oil companies’ late or delinquent payments on land leases and municipal taxes are exposing fissures in Alberta’s rural communities

Landowners and county reeves say they’ve had to fight for both rent and even municipal tax payments from a growing number of energy producers.

Geriatric orphan wells, boomtowns going bust and the fate of coal-mining towns in the age of renewables. In a four-part series, FP visits Alberta’s forgotten small communities to see how they are struggling with changes in the broader economy.

CALGARY – Andy Hofer and members of his Hutterite colony in northwestern Alberta have been embroiled in an increasingly common dispute in recent years. So common that the Hutterian Brethren Church of Grandview, where Hofer is the field manager, has been in at least eight such disputes in the past year.

Like many farms in the province, the religious agricultural commune, in an attempt to supplement its income, has signed lease agreements with oil and gas companies that want to drill their land for hydrocarbons.

But as commodity prices have tumbled for both oil and natural gas, those rental payments have either dried up or, in some cases, disappeared. In the past year alone, the Hutterite colony has won eight cases at the Alberta Surface Rights Board against energy companies that either weren’t paying rent or tried to unilaterally reduce their rental payments.

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 “It was a fight at the start,” said Hofer, adding that his colony near Grande Prairie has 80 such lease agreements. “They tried to reduce (the rent) and it was difficult getting more money.”

What was once a mutually profitable relationship between oil companies and the farmers, ranchers and counties who own the land they work on has become increasingly strained in recent years. Landowners and county reeves say they’ve had to fight for both rent and even municipal tax payments from a growing number of energy producers.

Those fights have resulted in drawn-out legal battles with companies farmers and ranchers once considered partners, while counties with massive municipal property tax arrears are being forced to dip into savings to balance their budgets or pass additional costs onto residents, who are sometimes the same farmers dealing with unpaid oil and gas rents.

The problem has become so widespread that applications to the Surface Rights Board, the provincial tribunal that assists landowners, occupants and operators resolve disputes about surface access and compensation, to recover unpaid rents have soared.

More than 2,500 applications were made in the first nine months of 2019 compared to 505 motions in all of 2014. The number of applications so far in 2019 has already surpassed the entire 2018 total of 2,410.

“The board is swamped,” said Daryl Bennett, a farmer and advocate for landowners in the Municipal District of Taber, just east of Lethbridge.

He said landowners are forced to wait years for payment decisions as a result of the glut of applications and some long-awaited decisions are rendered with “lots of mistakes” since the board does not have the staff required to properly deal with the volume of complaints.

One thing is clear: the delinquent payments are exposing fissures in Alberta’s rural communities.

Farmers and ranchers own the surface rights to the land, while oil and gas companies own the mineral rights beneath the surface. Contracts in years past were negotiated to allow both sides to profit as farmers and ranchers could earn rental income by allowing exploration and production companies to put drilling rigs and pump jacks on their lands and exploit any reserves.

When the lease payments stop — either due to bankruptcy or companies looking to reduce their rent — landowners don’t have the luxury of handing out an eviction notice. Once a well is drilled and encased in cement, it’s a permanent fixture on the land until its fully remediated and that process takes years.

Increasingly, landowners are angry about having to chase oil companies for payments and, sometimes being forced to wait years for the Surface Rights Board to settle the disputes. At the same time, Canadian agricultural exports have been shut out of critical markets such as China, further handicapping already cash-strapped farms and ranches.

Daryl Bennett, a farmer and advocate for landowners in the Municipal District of Taber, just east of Lethbridge. Theresa Taylor for The Narwhal

The agriculture sector is also competing for space on railway lines to move their grain to ports, because oil companies are shipping more of their product on rail cars due to the shortage of pipelines.

Oil-by-rail exports hit 319,594 barrels per day in September, which is approaching the record high of 337,260 bpd set in December 2018 and double the five-year average of 159,584 bpd, according to the Canada Energy Regulator.

Canadian National Railway Co. data show it has moved 8.8 million tonnes of Western Canadian bulk grain this year through the end of November, which is a six per cent decrease relative to last year and a two per cent decrease relative to the three-year average.

But more than just farmers and ranchers are affected by energy companies looking to reduce their expenses.

County reeves and representatives for rural districts report that companies, particularly natural gas producers that have struggled with low commodity prices in recent years, are either late or delinquent in paying their municipal taxes.

Rural Municipalities of Alberta (RMA) president Al Kemmere said counties and rural municipalities “are seeing an increase in the number of taxes not being able to be collected compared with last year.”

Last year, the association reported communities were unable to collect $81 million in municipal taxes, with most of the arrears coming from energy sector companies.

The strain is exposing financial weaknesses in different pockets of Alberta, because oil and gas exploration and production has moved from conventional formations in the south to more lucrative, deeper-lying unconventional formations such as the Montney, Duvernay and oilsands in the north.

A review of the balance sheets of every rural municipality and county in the province finds a large division in the financial fortunes of Alberta’s counties in the deep south and those sitting on hot plays in the north.

The financial statements show that counties and rural municipalities in active oil and gas hotspots have accumulated large surpluses. For example, Wood Buffalo is home to the oilsands and reported a $5-billion surplus in 2018. The County of Grande Prairie, at the heart of the Montney and Duvernay formations, has a surplus of $543 million.

The 10 richest counties and rural municipal districts in the province have accumulated surpluses totalling $9.5 billion, about half as large as Alberta’s $18.1-billion Heritage Fund, which was established by former premier Peter Lougheed as the province’s long-term savings plan.

By contrast, the richest county in the province’s southeast, Cypress County, has an accumulated surplus of $244 million, only good enough for the 18th-highest reserves in the province.

“The conventional play is dying out. It’s never going to come back the way it was,” Bennett said, adding that landowners in the south are looking at ways to repurpose the unremediated land left behind by bankrupt oil and gas companies because they no longer believe the wells in those areas will be bought by new operators.

Cypress County is home to older natural gas infrastructure around Medicine Hat, but areas in the south, which are no longer beehives of oil and gas activity, have average cash reserves of $143 million.

Some counties in the area have watched multiple bankrupt oil and gas companies such as Trident Exploration Corp. and Houston Oil & Gas Ltd. hand responsibility for cleaning up their aging wells to the Orphan Well Association, an independent non‐profit organization under the Alberta Energy Regulator.

“What it does create now more than anything is a situation where some have and some don’t have. We’re going to have to work with the provincial government on the distribution of the (municipalities grant) that we have from the province,” Kemmere said.

Proposal sees abandoned oil wells going solar

By Barb Glen

Published: November 21, 2019
The Western Producer

The idea taking shape in Alberta is to use existing energy site infrastructure to reduce solar project costs. | File photo

The plan started as a small pilot project in Alberta but has caught the attention of the provincial energy regulator

A plan is taking shape to erect small solar installations on the sites of Alberta’s abandoned oil and gas wells.

If successful, it could prove to be a classic case of making a silk purse from a sow’s ear, since myriad oil and gas company bankruptcies have resulted in the abandonment of thousands of wells, inundating the Orphan Well Association that has a mandate to seal the wells and reclaim the sites. Losses in the energy industry have also reduced municipal tax revenue and reduced or eliminated lease payments to landowners.

RenuWell, a project spearheaded by former Taber, Alta., area resident Keith Hirsche, is the entity behind a pilot project within the Municipal District of Taber. Hirsche, who has a background in oil and gas industry research, initially planned to start small but the idea has gained the attention of regulators and interest is building.

“We went to the M.D. of Taber with the idea of getting a development approval for (one) site and what it’s turned into is this policy piece funded by the MCCAC (Municipal Climate Change Action Centre) to kind of set the framework for doing this on a larger scale,” said Hirsche.

Now the Alberta Energy Regulator (AER) is interested in seeing solar installations at 100 to 200 sites per year, he said.

“I think once we get the first ones on the ground, a lot of that kind of prep work for the policy side has already been done and would facilitate that kind of expansion.”

RenuWell has held a number of meetings with landowners about the idea, and has found willing listeners among farmers and ranchers who have oil and gas sites on their land but who no longer receive lease payments from troubled or bankrupt energy companies.

Existing lease sites already have road and electrical access so that investment has already been made. The technical side of putting up small ground-mount solar arrays of 500 to 700 kilowatts is fairly simple, Hirsche said.

“We can basically go in and do a number of these small sites in a very repeatable fashion and we can reach similar costs to what the large scale utility projects can achieve. At least that’s what the business model says.”

Daryl Bennett, a farmer and member of the Action Surface Rights group, is involved in the project and has helped RenuWell in its contacts with landowners.

He lists some of its advantages as:

  • reducing Orphan Well Association inventory
  • reducing industry reclamation costs
  • reducing Surface Rights Board payments on behalf of the province
  • helping stabilize municipal tax revenues
  • reducing landowner electrical costs
  • stabilizing electrical grid
  • reducing need for large transmission lines

“A lot of these farmers want to keep getting the revenue (from lease payments.) We can just come in and put in these small solar panels. It stabilizes the grid. It doesn’t take new farmland out of production. It doesn’t require new transmission lines going across other people’s land. And it does pay some taxes to the county. So it’s a good news story for everybody,” said Bennett.

“It looks like it could easily go ahead and we’re talking hundreds of sites, maybe thousands.”

RenuWell is exploring various ownership options for the sites. Landowners may want to purchase and use the systems for their own power and irrigation needs. Co-operatives among farmers could be formed for larger agricultural electrical needs. Municipal or corporate ownership are two other options.

As well, “there’s a big solar developer that is interested in using us as kind of a new development model, rather than taking land that’s useful for agriculture for that purpose,” Hirsche said.

In a report written for the M.D. of Taber newsletter, RenuWell said its project addresses landowner concerns about large solar installations.

“A common concern was raised about maintaining the agricultural land base in the face of large utility-scale solar projects. This concern has been largely relieved due to our preference to re-use existing leases, which are located in lower productivity areas like pivot corners or tame grassland,” the report stated.

A major hurdle in the early stages was how to manage lease transfer, Hirsche said.

“The AER was really concerned that this would turn into another way of oil companies dumping liabilities, so it was a lot of work to kind of put the safety mechanism around that to reduce that risk.”

Getting a policy in place has smoothed the way for the pilot project and potentially larger solar conversions of sites. Hirsche said construction on the first site is expected to begin in early 2020, with electrical generation starting about three months later.

Ron Huvenaars, a farmer and chair of Action Surface Rights, said the RenuWell proposal is interesting.

“There’s a lot of potential there,” he said. “It seems like it should be a win–win but the first one has to get done. It’s always a little scary when you’re using numbers provided by somebody. … It’s like a lot of things. You’ve got to get the first one done and see how it goes.”

Bad weather cancels sugar beet harvest in southern Alberta

Sugar beet farmers are suffering in southern Alberta after severe cold and frost affected this year’s harvest.

Michael Franklin, Senior Digital Producer

@CTVMFranklin

Published Friday, November 8, 2019 1:59PM MST
Last Updated Friday, November 8, 2019 5:39PM MST

LETHBRIDGE – After a long, cold and wet summer, southern Alberta farmers won’t be able to harvest their damaged crops after Canada’s largest sugar company said it doesn’t have the capacity to process it.

Rogers Sugar Inc. announced Thursday, following an analysis in partnership with the Alberta Sugar Beet Growers, that it would not be harvesting any more sugar beets due to “severe snow and frost damage.”

As a result, only about 60,000 to 70,000 metric tonnes of refined sugar is expected to come from this year’s crop.

Sugar beets are grown by over 200 families in the southern Alberta region and supplies between eight and nine per cent of Canada’s sugar.

According to CTV Lethbridge weather special Dory Rossiter, ‘snowmaggedon’ in September dropped over 60 cm of snow in the region.

“In the far south of the province, we experienced only four days above 30 degrees during June, July and August. We also had 27 days of below average temperatures and 89 mm of rain, in total, during those same months.”

It’s believed only 55 per cent of the sugar beet crop was harvested before the company called off operations.

Rogers says it is looking at a number of options to provide sugar to its customers, including relying heavily on an excess supply of cane sugar from refineries in Vancouver and Montreal.