Pipeline News North: April 2016

Special Report: Will NGLs beat out LNG? / Page 11 APRIL / MAY 2016

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a rallying cry for industry On the heels of a 600-truck strong convoy in support of liquefied natural gas development, Peace residents and businesses are getting set to pound the pavement once more; oil and gas land sales rebounded slightly last month; B.C. officials press their federal counterparts on Pacific NorthWest LNG; and investors continue to bet big on new gas processing plants in Northeast B.C.

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PNN

NUMBERS

The following figures were taken from the stories in this issue of Pipeline News North.

$7.4 billion: Increase in real Canadian GDP over 30 years if three LNG facilities in B.C. proceed. Story on Page 5.

848 trillion: Potential number of cubic feet of unconventional natural gas in the Liard Basin. Story on Page 10.

17%: Oil and gas production contributions to B.C.’s overall emissions.

Story on Page 17.

$1.9 million: Sales total for three leases and seven drilling licences sold at the March 23 land sale. Story on Page 6.

73: Number of goals scored in final matches of the Fort St. John Petroleum Association 4-on-4 hockey tournament.

More on Page 13.

560: Kilometres, as the crow flies, between Dawson Creek and Fort McMurray.

Story on Page 21.

$62 million: Amount of money that changed hands at Ritchie Bros. auction in March. Story on Page 7.

2,000: Number of local businesses the Northeast B.C. Resource Municipalities Coalition says oppose a carbon tax hike.

Story on Page 16.

54%: Percentage of British Columbians who believe LNG is a cleaner alternative to coal.

Story on Page 22.

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APRIL 15, 2016

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Accuracy of world oil data in question

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LNG could bring black ink to federal budget

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Oil and gas land sales recover in March

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Ritchie Bros. auction sets record

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Saturn plant advances to next phase

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Woodfibre LNG wins federal approval

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BC officials nudge feds on Pacific NorthWest LNG

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Jordan Cove LNG lands sales agreements

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Liard reserves four times larger than thought

Investors betting big on natural gas liquids

Oilmen cap off hockey season Petronas and the million-tonne question

Industry and province must work together on emissions

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Coalition clobbers calls for carbon tax hike

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Climate plan must not stifle investment: CAPP

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Local gov’t convention to feature oilsands tour Look for PNN on FB: pipelinenewsnorth

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Pipeline News North is politically independent and a member of the B.C. Press Council. The Pipeline News North retains sole copyright of advertising, news stories and photography produced by staff. Reproduction is prohibited without written consent of the editor.

APRIL 15, 2016

#oilsands

opening remarks

Accuracy of world oil production data in question I n our business, we constantly have our eyes glued to the price of crude oil – it dropped dramatically last year, recently it’s edged up a little - no wait, now it’s down again – what gives?

Everyone knows that price is determined by supply and demand, but it’s important to stand back a little from the numbers and consider how they were gathered in the first place.

Weekly reports that document U.S. crude oil inventory, production and the number of rigs in operation in North America have a significant effect on energy markets. In the U.S. and Canada, we are good—really good—at monitoring and reporting these metrics.

More than 70 per cent of global oil production, however, happens outside North America. And you

can be sure the measuring protocols elsewhere are not nearly as precise as ours.

Industry-watcher Terry Etam published an interesting article in oil and gas news portal BOE Report recently that reminded me why oil pricing can be so volatile— and why it’s important to take the long view.

Here in North America, production is regulated, measured and tracked closely. Relatively small changes in volumes are noted, analyses written, hands wrung, discussions held. And often, prices change as a result.

Meantime, some OPEC countries “estimate” production levels by simply counting the number of ships being loaded in their ports.

In places like Afghanistan, Nigeria, Libya and Russia, meters

are seldom found, theft is rampant and corruption reigns. Unmeasured production may (or may not) be produced from one month to the next. How can we possibly expect their statistics to be remotely accurate or anywhere close to the precision of measurements we fuss over here?

Yet, to come up with global supply figures, all these statistics—our impeccably precise and accurate ones and their little-more-thanguesses—are blended together and duly reported. Traders react to the tiniest of variations in these numbers—even though the precision of the summary reports far exceeds the accuracy of the underlying data.

What’s the lesson here? We need to remember that short-term price volatility is based in part on ques-

LNG could turn federal government’s red ink into black

T

he federal budget released March 22 painted a dim picture of Canada’s financial health. With minimal oil and gas production, Canada will be $30 billion in the red. There is no light at the end of the tunnel. No balanced budget in sight.

But what if Ottawa approves two big and one small LNG plant today?

An LNG industry in B.C. would create new markets for Canada’s natural gas, generating income and jobs for governments and citizens. It would also reduce global greenhouse gases (GHG) if used as a substitute for coal, bunker fuel and diesel, even if we consider the added GHG these LNG plants would generate.

What if Ottawa approves just three of the 21 proposals vying to be a part of Canada’s LNG industry?

What would be the impact on the economy and the labour market?

After all, these three LNG plants would require that Northeast B.C. produce an additional five billion cubic feet per day (bcf/d) of natural gas, approximately double the 2014

PIPELINE NEWS NORTH •

production.

To support an LNG industry, the majority of initial investment spending would occur here in the northeast, in the upstream sector of the natural gas value chain. We need to produce a sufficient quantity of natural gas to supply LNG terminals with feedstock and fuel.

According to a February 2016 Conference Board of Canada report on B.C.'s LNG industry, more than $26 billion will be invested over five years in the northeast. That is more than $5 billion per year to be spent in our backyard!

These expenditures will have a multiplier effect in the northeast.

Induced economic impacts, such as increased household spending, would also create employment opportunities in the wholesale and retail trade industry. This is just for the upstream industry.

If we add the annual spending across the upstream, midstream, and downstream sectors, this will average $7 billion, according to the Conference Board. Over the next

30 years, these investments would increase real Canadian GDP by an average of $7.4 billion per year, of which $5.3 billion would occur in British Columbia. Remember, this is just with three of the 21 proposed LNG facilities in B.C. The Conference Board estimates this increase in economic activity will also create 65,000 well-paying jobs in Canada, 46,800 of which will be in B.C. Most of these jobs will be in the north. An increase in labour income and corporate profits would result in indirect taxes of $808 million and $577 million in revenue annually to the B.C. government and federal government, respectively.

Global LNG trade will continue to grow with 80 per cent of the planned new capacity located in North America. We have seen how three LNG plants will benefit Northeast B.C., B.C. and Canada. A full LNG industry in Canada will lift our economy back to a balanced budget and beyond.

The economic and labor market benefits of an LNG industry are

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Tim Maryon Oil Matters

tionable data. For now there seems to be plenty of oil around—especially in North America. But the worldwide “balances” can change quickly.

The fundamental fact is that demand for oil follows population growth and economic development.

In the short-term, when pricing is volatile it discourages exploration and the development of new oil sources. But as demands continue to grow they will exceed this curtailed supply, and pricing will recover.

Oil matters, and will continue to matter for a long time.

Tim Maryon is vice-president of sales and business development at Peace Country Petroleum in Fort St. John.

Alan Yu FSJ FOR LNG

simply too big to set aside. We can balance our concern for the environment with our desire for a better Canadian economy with all the environmental reviews and regulations that Canada has put in place.

But, as Canadians, we need to educate ourselves with the facts about LNG. The economic and labour benefits are just too much that we have “environmentalists” taking advantage of Canada’s lack of accurate information about LNG to keep this promising industry away from Canada and solely that of the USA. Let us ask ourselves why the U.S. has one exporting LNG plant in Alaska, one in the U.S. mainland, with four more LNG plants waiting to go into operation in a few years.

Note: Information taken from The Conference Board of Canada’s “A Changing Tide, British Columbia’s Emerging Liquefied Natural Gas Industry” published in February 2016.

Alan Yu is a Fort St. John resident and founder of FSJ for LNG.

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PNN MISSION STATEMENT Our mission at Pipeline News North is to provide the most current, interesting, and relevant news and information about the oil and gas industry in Northeast B.C. and Northwest Alberta. Have an interesting story to share or a news lead? Email us at editor@ahnfsj.ca.

William Julian Regional Manager 250-785-5631 wjulian@ pipelinenewsnorth.ca

Oil and gas land sales recover with $1.9M March auction Jonny Wakefield Staff Writer

Oil and gas land sales are once again contributing to B.C. government coffers, after a dismal February auction where not a single lease or drilling licence sold.

The March 23 Crown petroleum and natural gas rights public tender netted $1.9 million, including three leases and seven drilling licences.

The sale is considered an indicator of future

oil and gas exploration, and makes up the majority of provincial petroleum revenues.

February's sale was the first time in history that not one parcel sold, as exploration contracts with a downturn in oil and gas prices.

The average price per hectare this month was $314, well below the 2008 high of $9,537.

However, the price recovered from January, when leases went for $76 per hectare.

The next sale will be held April 20. reporter@dcdn.ca

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B.C. oil and gas land sales, 2014-16

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veresen PHOTO

The site of Veresen’s Sunrise Gas plant. It is one of three (Tower, Sunrise and Saturn) major gas processing facilities now under construction as part of the Veresen Midstream infrastructure development. All combined, the projects represent $2.5 billion of new midstream capital investment in the South Peace under the agreement with the Cutbank Ridge Partnership.

APRIL 15, 2016

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outlook

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Ritchie Bros. auction sets records, most equipment will stay in Canada Jonny Wakefield Staff Writer

ritchie bros. PHOTO

Fifty-two per cent of sales from the Ritchie Bros. auction in March went to Canadian buyers from outside Alberta. Another 12 per cent sold to out-of-country buyers, with bidders registering from 39 countries.

“There’s lots of speculation about it,” she said.

“Some folks are saying these larger companies, not just oil and gas but larger construction companies, are going to hold that equipment.”

She said that while some companies invest in mergers and acquisitions during downturns, others put money into equipment and capital upgrades.

Saturn gas plant moves to next phase Mike Carter Staff Writer

Veresen Midstream has approved a $930-million expansion to its existing Saturn natural gas plant near Groundbirch.

The company made the announcement with the release of its fourth quarter 2015 results in March.

The expansion will add 200 million cubic feet per day of compression and 400 million cubic feet per day of gas processing.

Veresen Midstream says it plans to deliver the gas to both domestic and potential international markets via planned export facilities on the coast and the existing TransCanada NOVA Gas Transmission System.

The Saturn Phase 2 expansion will be about 160 acres in size and will handle gas produced in the Montney shale play on properties owned by the Encana Corp. and Mitsubishi joint venture, known as the Cutbank Ridge Partnership. “(We’re) moving ahead with plans to ramp up production, even in this low commodity price environment due to the advancements in drilling and completion efficiency,” spokesperson Sarah Kenny

said in an emailed statement.

Veresen Midstream has already released its plans to build two processing facilities in the same area: the Sunrise facility, announced in October, and the Tower gas plant, announced last December.

Dawson Creek Mayor Dale Bumstead lauded the announcement of the expansion project.

“This brings secure long-term great jobs when the construction is completed,” Bumstead said.

“These construction projects also create terrific economic spinoff for our community. A great sign for our local economy.”

The company was not immediately clear on how many jobs would result from the project.

“There will be incremental employment during both the construction and operation phase,” Kenny wrote. “We do not have a total number as of yet due to the early nature of the construction planning.”

When construction is complete, Veresen Midstream will have more than one billion cubic feet of gas processing infrastructure in the area, making it the second largest midstream gas processor in British Columbia, next to Spectra. dcreporter@dcdn.ca

“They may not even turn a tire, but when the market comes back, they either have more equipment, or they can sell it at a profit,” she said.

The sales set Grande Prairie records for auction proceeds, amount sold to online bidders, and total registered buyers. reporter@dcdn.ca

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Heavy equipment auctions held in Grande Prairie in March set records, with more than $62 million changing hands.

More than 2,500 excavators, dozers, dump trucks and other pieces of heavy equipment sold at Ritchie Bros. auctions March 14 and 15.

Despite fears the equipment could go to outof-country buyers, 88 per cent sold to Canadian companies.

Ritchie Bros. typically holds its first spring sale in April, but scheduled an extra event to handle complete sell-offs of equipment from Pinnacle Services and Continental Pipelines and Facilities, which closed its Fort St. John office in January.

Kathleen Connolly, executive director of the Dawson Creek Chamber of Commerce, was pleased to hear that most of the equipment will stay in Western Canada.

Earlier, she worried the strong American dollar would lead to a large percentage of equipment being sold south.

"The results from the Edmonton auction were much the same," she said, referring to another auction held in February. "A lot of the equipment stayed in Canada."

Fifty-two per cent of sales went to Canadian buyers from outside Alberta. Another 12 per cent sold to out-of-country buyers, with bidders registering from 39 countries.

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lng

Woodfibre LNG wins federal gov’t approval Jonny Wakefield Staff Writer

Final investment decision possible by year’s end

While Pacific NorthWest LNG sits in limbo, another project that would source gas from the Peace Region has been granted federal environmental approval.

On March 18, Environment and Climate Change Minister Catherine McKenna announced her decision on the $1.7-billion Woodfibre LNG export facility, saying the Squamish-based project was "not likely" to cause significant adverse effects on the environment.

"The Woodfibre LNG project underwent a thorough, sciencebased environmental assessment that considered public and Indigenous input and views," McKenna said in a statement. "The process benefited from scientific and technical expertise, Indigenous traditional knowledge and constructive feedback that

helped to inform my decision."

Byng Giraud, Woodfibre’s vice president of corporate affairs, said there is still a lot of work to do before the company behind the project—Pacific Oil and Gas—makes a final investment decision.

The company’s engineers will have to look at the conditions set out by B.C., the federal government and Squamish First Nation to finalize a design that meets all the conditions.

And while they’re at it, the company plans to take advantage of a slowdown in the oil and gas sectors to tweak the engineering in the hope of shaving a few dollars off the $1.7-billion project.

“We’re reviewing the entire project and looking for optimization,” Giraud said. “And it’s a good time to do it."

“With the engineering firms in the yards—and the suppliers— there’s a lot more availability right now because of the way the market is, so it’s a good time to optimize,” Giraud said.

The company also still needs to hammer out final offtake agreements. The company has memorandums of understanding signed with two customers in China. But the deals are not finalized, in part because of the volatility in oil and gas prices.

“They’re MOUs, they’re not final offers,” Giraud said. “With prices bouncing around on a daily basis, that takes a bit of effort, so our team in Asia has to nail down those offtake agreements.”

Giraud said the company hopes to make a final investment decision this year.

Woodfibre one of four LNG projects in B.C. most likely to proceed: World Gas Intelligence Meanwhile, a World Gas Intelligence report released March 31 named the Woodfibre proposal as one of four LNG facilities planned for B.C. most likely to proceed.

Others that made the list include Pacific NorthWest LNG, LNG Canada, and WCC LNG. World Gas Intelligence noted the projects may not proceed until global LNG prices and demand return, according to a report in the Globe and Mail.

— with files from Business in Vancouver, Matt Preprost reporter@dcdn.ca

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lng BC officials press feds on Pacific NorthWest LNG

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PEOPLE POWER RALLY

Matt Preprost Staff Writer

Provincial and local government officials in B.C. have had a busy month as they try to get their federal counterparts back on track in making a swift decision on Pacific NorthWest LNG. On March 19, the Canadian Environmental Assessment Agency (CEAA) said it would need an additional three months to evaluate the project, which received 34,000 submissions during a recent public comment period. The agency requested more information on the project’s environmental and Aboriginal land use impacts.

The delay means a federal decision on the project likely won’t happen until the summer, which prompted swift action from the province, who had officials in Ottawa just two days after CEAA’s announcement.

Natural Gas Development Minister Rich Coleman said March 21 that senior officials from the province were in the capital to “reach a positive final outcome that helps our economy, protects the environment, and respects First Nations.”

“I’m confident that any remaining questions can be answered completely and quickly. They have to be. Jobs for British Columbians should not be held by unnecessary delays,” Coleman said. “After all, this just isn’t any project. At $36 billion and 18,600 jobs, PNW LNG would be the largest private sector investment ever in Canadian history.”

MAYOR OFF TO OTTAWA TO TALK UP LNG Fort St. John Mayor Lori Ackerman, meanwhile, will be in Ottawa the week of April 18 to meet with the Minister of Environment, the Minister of Finance and others to promote the development of a liquefied natural gas industry.

“MP (Bob) Zimmer’s staff has got three meetings lined up so far, and we’re asking for meetings with about seven different ministers,” Ackerman said at

matt preprost Photo

The FSJ for LNG group will hold a “People Power” rally along 100th Street on Saturday, April 23. The rally will assemble at Centennial Park around 10:30 a.m., and organizers are hoping to fill the sidewalk with supporters. For more, visit fsjforlng.ca.

an April 11 council meeting.

Northern Rockies Mayor Bill Streeper, Taylor Mayor Rob Fraser and Tumbler Ridge Mayor Don McPherson will also attend.

DELAYS TAKING A TOLL The CEAA wants more information about the plant’s effects on fish and fish habitat including the Flora Bank, effects on marine mammals, effects of construction noise and light on human health, and effects on current Aboriginal use of lands and resources for traditional purposes.

In an interview with the Financial Post April 13, Pacific NorthWest and Progress Energy President Michael Culbert said he expects to respond to CEAA’s information request “within the next two weeks.”

At the same time, he revealed Progress would be trimming down its capital spending plan significantly in the wake of the delay—down from $3 billion over three years to just $500 million over two years.

“The plan with the final investment decision

moving forward was another $5 billion in the next three years moving into the development phase,” Culbert told the Post. “We are going to drop that (figure) down to somewhere around $500 million over the next two years—so a significant drop.”

Progress had spent about $3 billion over the last three years as it proved up its reserves in Northeast B.C. in anticipation for the project to begin, Culbert said.

Culbert said the cut is part of an $11.4-billion reduction in capital expenditures parent company Petronas is expected to make across its portfolio over the next four years.

The regulatory delay has also meant Pacific NorthWest will need “new engineering, procurement, construction and commissioning bids” for the project and the associated Prince Rupert Gas Transmission pipeline, Culbert told the Post.

The company submitted its project description to the CEAA in February 2013, and its environmental impact statement in February 2014. editor@ahnfsj.ca

Jordan Cove LNG lands sales agreement for gas Jordan Cove LNG, a natural gas export facility proposed on the Oregon coast, has signed a 20-year sales agreement with world’s largest liquefied natural gas buyer.

The deal appears to put the project, which could take gas from the B.C. Montney formation, back on track after running into a roadblock with U.S. regulators.

JERA Co. Inc, a joint venture of the Tokyo Electric Power Company and Chubu Electric Power Co., Inc., signed on to buy 25 per cent of the project’s proposed six million tonnes per year output in a deal announced March 22.

The company is owned by Veresen Inc., a major midstream natural gas player with assets in the

Dawson Creek area.

“This is an important milestone for the project and further demonstrates the market demand for Jordan Cove LNG,” spokesperson Dorreen Miller wrote in an emailed statement.

Michael Hinrichs, another project spokesperson, said March 15 that gas for the project could come from B.C., but stressed that those details are still up in the air.

“We have an export licence from Canada and an import licence from the U.S., so we would be able to take gas from the Colorado Rockies, the Canadian Rockies, Alaska gas,” he said. “The project, as it stands right now, is pretty much open access.”

Miller said Jordan Cove is is negotiations with

other large LNG buyers from the Asia-Pacific region.

The project hit a stumbling block on March 11, when the U.S. Federal Energy Regulatory Commission (FERC) ruled the benefits from the $5.3 billion export terminal and associated pipeline did not outweigh “adverse effects” on landowners facing potential expropriation. FERC also noted that it was rejecting the application in part, because Versen did not have sales contracts signed.

The company filed a request for rehearing with FERC on April 11. FERC has 30 days to grant or deny the request for rehearing.

— Mike Carter, with files from Daily Oil Bulletin

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statistics

Liard reserves four times larger than previously thought Mike Carter

Staff Writer

Natural gas reserves in the Liard Basin are four times larger than previously thought, according to a new assessment released March 16.

The basin's potential had never been evaluated in detail before this study.

The study evaluates the unconventional natural gas inventory of the Liard Basin, a relatively unexplored region that straddles the Northwest Territories (NWT), Yukon and B.C. It was jointly released by the National Energy Board (NEB), the B.C. Oil and Gas Commission and the NWT and Yukon Geological Surveys.

The report shows the ultimate potential for unconventional natural gas in the Liard Basin is expected to be 848 trillion cubic feet (TCF), up from a previous estimate of 210 TCF. Mike Johnson, technical leader of hydrocrabon resources with the NEB, said it's likely only 219 TCF of that 848 TCF will be accessible.

"We've always known the gas is there. The difficulty has been extracting it," Johnson said. "Even with today's technology you can really only get about 20 per cent of the gas out of the rock and so when you end up with an in-place number of something like 800 TCF, you can really only extract

about 200 TCF out of it."

The study determined the amount of gas by using data from existing wells in the region.

Most of the gas in the Liard Basin is located in B.C., though the NWT and Yukon's potential are still larger, the study notes.

For comparison, the Montney formation beneath Dawson Creek, Fort St. John and Northern Alberta has a marketable reserve of 449 TCF of natural gas, while the Horn River Basin in the Fort Nelson area contains an estimated 78 TCF. Total Canadian natural gas demand in 2014 was 3.2 TCF, making the Liard gas resource equal to 68 years of consumption.

However, the study adds that "it is too early to know whether the Liard Basin will significantly contribute to the Canadian gas production in the near term because gas prices are expected to remain low for the next several years, deterring development."

Rich Coleman, minister of natural gas development, said B.C.'s resource potential is at a competitive advantage over many other parts of the world.

"This report shows our long-term prospects are stronger than before," he said, "and that the Liard Basin can create economic activity and jobs in our province for a very long time to come."

Johnson said the study will likely draw attention

to the area from natural gas developers.

"It provides a baseline," he said, "so that if an explorer was looking for somewhere to move they have a bit more information to go on rather than it just being a black hole where there is not any geological information."

Part of the NEB's mandate is to ensure that Canadian gas supply is met before any natural gas is exported.

"By having a study like this it shows that there is lots of natural gas supply available," Johnson added. "It makes our job easier when we end up examining applications to export gas. We know the conditions of the market, we know Canadians are well-supplied so it makes the ability to determine exports that are surplus to Canadian requirement a lot easier."

Drilling in the basin has been traditionally lower than in other regions.

"There are really only a handful of wells that are producing shale gas (there) right now," Johnson said. "It's just because it's remote and it's really still in the exploration phase."

Two Canadian shale gas basins rank among the 20 largest marketable gas reserves in the world. The Montney ranks third, while the Liard ranks ninth. dcreporter@dcdn.ca

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investments

11

Investors betting big on natural gas liquids Investment in new gas processing plants in Northeast B.C. adding up to the billions Nelson Bennett

Business in Vancouver

Most British Columbians by now know what LNG stands for—liquefied natural gas.

But perhaps they should become more familiar with a couple of other acronyms: NGL (natural gas liquids) and LPG (liquid petroleum gas).

After all, it is NGL, not LNG, that appears to have been driving billions of dollars of investments in new gas processing plants in British Columbia recently.

Construction has yet to start on a single LNG plant in B.C. Meanwhile, companies like Veresen Inc. and AltaGas Ltd. have been investing billions of dollars in new gas processing plants in the Dawson Creek and Fort St. John region.

AltaGas and its partners recently shelved their Douglas Channel LNG project in Kitimat, and on March 11 Veresen’s Jordan Cove LNG project in Oregon was denied a permit, in part because the company had no firm buyers.

So why are both companies still moving ahead with multibillion-dollar investments in new gas processing plants in Northeast B.C.?

The answer is that the Montney Formation in Northeast B.C. is so rich in both gas and natural gas liquids (light oil, condensate, butane and propane) that it makes natural gas production there more economically viable than in most other producing regions, despite falling gas prices and increasing competition from the U.S. “While Canadian production has been decreasing and exports have been decreasing, B.C. has actually been growing,” said Geoff Morrison, manager of B.C. operations for the Canadian Association of Petroleum Producers.

“If you look at LNG prices globally, they’ve really come off a lot, challenging economics for any of the projects, whereas liquids … maintain a fairly healthy spread, compared to North America,” said Jess Nieukerk, AltaGas’ director of finance and communications.

As part of an agreement with the Cutbank Ridge Partnership (Encana and Mitsubishi), Veresen is currently building two new gas processing plants in the Dawson Creek area—the Sunrise and Tower plants—at a capital cost of

Construction on the new $325-million Townsend gas plant as of April 2.

painted pony petroleum PHOTO

“If you look at LNG prices globally, they’ve really come off a lot, challenging economics for any of the projects, whereas liquids … maintain a fairly healthy spread, compared to North America”

$1.5 billion.

Earlier this month, Veresen and Cutbank Ridge approved the construction of a third plant, the $930 million Saturn 2, bringing the total investment to about $2.5 billion.

“These are going to be some of the biggest gas plants in Western Canada,” said Steven Paget, an analyst with FirstEnergy Capital Corp.

Meanwhile, AltaGas plans to begin operations at its $325 million Townsend gas processing plant near Fort St. John about the middle of this year.

The Townsend plant is part of about $1 billion worth of investments AltaGas is planning to make in B.C. The company is planning a new propane export facility at the Ridley Island terminal in Prince Rupert, at a cost of $400 million to $500 million. AltaGas expects to make a final investment decision later this year.

The company also has plans to build a new liquids separation facility near Fort St. John, at a cost of $100 million to $150 million. That plant would process natural liquids into products like propane and condensate. (The biggest market for condensate is Alberta, where it is used to dilute oilsands bitumen.)

Although a new market for gas from an LNG industry would increase demand and prices for natural gas producers, it appears the investments being made in the Montney are not necessarily dependent on it.

“I think what we’re seeing sanctioned is not dependent on LNG,” Paget said.

Earlier this month, Dulles Wang, a gas analyst for Wood Mackenzie, told a Canadian Energy Research Institute conference that he thought Petronas’ Pacific NorthWest LNG will proceed and be producing by 2022.

“But even without Petronas’ project, we still think the WCSB [Western Canadian Sedimentary Basin] production will grow because you still have a lot of low-cost gas in the Montney,” Wang said.

Western Canadian gas production has been falling, due to competition from the U.S., but Wang predicts that by 2025, a “second wave” of North American LNG projects will drive up the demand for western Canadian gas.

— with files from Daily Oil Bulletin

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Oilmen champs crowned Cabre Oilfield took home the title at the annual Fort St. John Petroleum Association 4-on-4 hockey tournament April 7 to 9. Cabre won the final 9-5 against Fort Motors.

More than 100 hockey players were on hand for the tournament to wrap up the hockey season at North Peace Arena. The tournament also featured a celebrity visit from former NHLers Rob Brown and Fernando Pisani.

Distribution Now won the B-final 8-5 over TCL; Complete Pumpjack pulled out a 10-7 win over Tom’s Construction in the C-final; Baker Hughes won 8-7 over Ditmarsia in the D-final; And Northern Vac topped Magnum 8-6 in the E-final. byron hackett photos

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Westcoast satisfies First Nations concerns about proposed pipeline expansions Two local First Nations have withdrawn their requests to federal Environment Minister Catherine McKenna that proposed Westcoast Energy Inc. natural gas pipelines in the region be subject to public hearings under the Canadian Environmental Assessment Act. West Moberly First Nations and Saulteau First Nations had raised concerns about the High Pine and Jackfish expansion projects, while Saulteau had asked that the proposed Wyndwood expansion project also be considered a “designated project.”

However, in letter to McKenna and to the National Energy Board, West Moberly Chief Roland Willson said his First Nation is now prepared to support the High Pine and Jackfish projects on the ba-

sis of the improved understanding reached by it and Westcoast, which does business as Spectra Energy Transmission.

Willson said West Moberly is withdrawing its request for public hearings for the pipeline expansions as it is confident that any effects can be appropriately addressed by Spectra in collaboration with West Moberly and relevant third parties.

In its letter to McKenna, Saulteau First Nations said that it and Westcoast have had productive discussions and that the company has addressed its concerns regarding the projects.

The NEB has yet to rule on the projects.

—Daily Oil Bulletin

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'The million-tonne question':

Will emissions trip up Petronas LNG project?

Jonny Wakefield Staff Writer

It's the million-tonne question: will Justin Trudeau's plan to cut Canada's contributions to climate change trip up Pacific NorthWest LNG? As the $36-billion liquefied natural gas (LNG) project awaits a yes or no from the Trudeau cabinet, new debate is raging over whether the project's hefty greenhouse gas emissions can be justified.

Opponents say green-lighting the Prince Rupert-based plant will make it impossible for B.C. and Canada to meet emissions reduction targets.

But supporters say "clean burning" B.C. gas will offset oil and coal in Asian nations, making Pacific NorthWest a benefit for the global climate.

A Canadian Environmental Assessment Agency (CEAA) review of the proposal, released in February, has also put new focus on what can be done to reduce emissions from drilling, processing and transporting natural gas.

Running the plant itself would add another 5.28 million tonnes of carbon dioxide (CO2) per year to the atmosphere—an 8.5 per cent increase in total provincial emissions. The majority of Pacific NorthWest's B.C.-based emissions—between 6.5 and 8.7 million tonnes of CO2 per year, or 10 to 14 per cent of the provincial total—would happen in Northeast B.C., where the gas will be sourced. B.C. and federal government reviews of the project have cited emissions as a "significant adverse environmental effect."

Warren Brazier, an energy lawyer with the firm Watson Goepel, says those emissions could be brought down significantly if upstream drilling and processing can be brought onto the BC Hydro grid.

"For B.C., it's unique, and the opportunity is there," he said. "The availability of clean electricity compared to other places around the world is second-to-none for this industry.

File Photo

Warren Brazier, an energy lawyer with the firm Watson Goepel, says emissions from Pacific NorthWest LNG could be brought down significantly if upstream drilling and processing can be brought onto the BC Hydro grid.

I think electrifying is a wise way to reduce you emissions. To what extent (they will) is the million-tonne question."

With a few exceptions, gas drilling operations in B.C. burn either their own product or diesel fuel to power their operations, contributing to 17 per cent of the province's overall emissions. The BC Hydro grid, on the other hand, is more than 93 per cent clean or renewable energy.

Brazier, who remains critical of the Site C dam, said electrifying upstream natural gas can be a smart choice for producers. But getting the power to remote drilling sites remains a challenge, and it's not clear whether B.C.'s LNG export window will still be open by the time power lines can be built.

BC Hydro has already completed a power line for drillers and processing plants in the South Peace—the Dawson Creek and Chetwynd Area Transmission line (DCAT), and plans to add to that system within the decade.

Progress Energy, the upstream company supplying gas for Pacific NorthWest LNG, hopes to get on the grid via a 140-kilometre line to its drilling operations north of Fort St. John.

Progress spokesperson Stacie Dley said the company is in "high level" talks with ATCO Power on whether it's feasible to build the line, adding it has not received final approval.

She added that CEAA emissions figures do not take into account possible electrification.

According to ATCO, the project could cut up to a third of emissions from Progress Energy upstream operations—currently pegged at 400,000 tonnes of carbon dioxide a year.

However, Brazier said that without a grid hookup for the plant itself, the ATCO project would be a "drop in the bucket" towards reducing overall emissions.

"It's not enough to have a huge impact on the emissions of the Pacific NorthWest LNG project. I'm not saying they shouldn't do it.

But if you're ignoring the downstream and not electrifying as much as you can, there's still a huge amount of emissions that are going to occur at the plant itself."

Other projects, like Woodfibre LNG in Squamish, already have plans to plug into the BC Hydro grid, he added.

The B.C. Liberal government argues LNG will be a net-benefit for the climate, helping Asian nations that rely on coal transition to cleaner burning natural gas. But there are no guarantees LNG will go to offset coal, and it remains to be seen whether the federal government will be swayed by this logic. reporter@dcdn.ca

Industry, province must work together to reduce emissions: PRRD Mike Carter

Staff Writer

Connecting upstream oil and gas producers to the BC Hydro grid and ensuring “carbon tax equity” are two things the province and industry need to work together on in regulating greenhouse gas emissions, the Peace River Regional District says.

In a letter addressed to the Ministry of Environment, the PRRD wants the province to work closely with industry to meet its goal of reducing methane emissions by 40 per cent over the next five years.

Most of this, the province and

regional district agree, could be done by connecting gas wells, plants, compressor stations and associated infrastructure to the BC Hydro grid.

Taking a line from the B.C. head of the Canadian Association of Petroleum Producers (CAPP), the PRRD also recommended the province work to protect what CAPP calls “emission-intense, trade-exposed industries,” including B.C. natural gas, until “other jurisdictions impose similar carbon tax rates.”

CAPP’s Geoff Morrison told the PRRD earlier this month that any climate action must not stifle oil and gas investment projects.

Oil and gas production currently accounts for roughly 17 per cent of B.C.’s overall emissions, without anticipated development.

Both the PRRD and CAPP propose a “carbon tax equity that industries operating in Northeast B.C. are above to remain competitive with other jurisdictions.”

This would also apply to the greenhouse gases emitted by travelling the large geographic areas that make up the Peace Region.

For an industry that’s hemmed by increased competition from the United States and the low price of natural gas, jobs and investments are in the mix when it comes to the

goals of meeting greenhouse gas reductions.

“The board supports the goal of working towards reducing greenhouse gas emissions while ensuring that jobs are created and maintained to support families and communities here in the northeast,” the PRRD wrote.

“Given our proximity to industries that serve as the key economic drivers for the province, (the PRRD) firmly believes that an ‘upstream perspective’ on the new Climate Leadership Plan is integral to the consultation and engagement process.” dcreporter@dcdn.ca

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CORE SAMPLE Sung-Eun Kim with the BC Oil & Gas Commission holds a piece of Montney shale from the Jedney area that was on display for attendees at the 44th annual CKNL Trade Show April 8 to 10.

Coalition clobbers calls for carbon tax hike Bronwyn Scott Staff Writer

Claiming the support of 2,000 businesses in Northeast B.C., a coalition of local governments and business groups is firing back at calls to raise the province’s carbon tax from its rate of $30 per tonne.

After 130 businesses from across the province signed onto an open letter asking Premier Christy Clark to raise the tax, the Northeast BC Resource Municipalities Coalition is arguing the rate should stay where it is—while claiming more than 15 times the support.

“It’s really about making sure that our economy is remaining competitive,” Fort St. John Mayor Lori Ackerman said.

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The province is currently reviewing its Climate Leadership Plan, which will lay the groundwork to help the province meet its 2050 emissions reduction targets. One of the plan’s 32 recommendations is to raise the tax by $10 per year starting in 2018, and to include protections for so-called emissions-intensive, trade-exposed industries, such as oil and gas.

The coalition—which includes Fort St. John, Taylor, the Northern Rockies and a handful of local industry groups including the Fort St. John, Fort Nelson, and Dawson Creek chambers of commerce—has filed a formal submission urging the province to maintain the tax freeze. The chambers claimed their entire memberships to arrive at the 2,000 businesses figure.

As a resource-rich area, the Peace Region

would be greatly affected by a carbon tax hike, Ackerman said, adding the ramifications of an increase would have far reaching consequences.

“This would impact any resource industry, and when I say any resource industry, I am talking about farming, forestry, or mining, oil and gas, any resource industry, because they are reliant on machinery to extract and produce their commodity,” she said.

“It’s not just Northeast B.C., it’s those of us who live outside of the urban areas that are working each and every day to get commodities to market, to bring new dollars into our jurisdiction.”

The province says it will not make changes to the carbon tax before 2018. peacereporter@ahnfsj.ca

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Climate plan must not stifle oil and gas investment: CAPP Jonny Wakefield

Staff Writer

The B.C. head of Canada's oil and gas lobby says the industry supports reducing the emissions that come with getting resources out of the ground—but not if that means sending investment dollars out of the province.

Geoff Morrison, the Canadian Association of Petroleum Producer's (CAPP) manager for B.C. operations, was invited to give the organization's thoughts on the province’s Climate Leadership Plan at the March 10 Peace River Regional District meeting.

The plan lays out how B.C. will meet its greenhouse gas (GHG) reduction targets, initially set in 2008.

In November 2015, the government rolled out 32 recommendations aimed at cutting emissions while preserving economic growth.

Among those recommendations: cutting methane emissions from upstream oil and gas by 40 per cent, and taking new steps to connect drillers to the low-emissions BC Hydro grid.

“We can contribute to reductions, for the ones we have control over,” Morrison tsaid.

“But the vast majority of emissions in this province are from other sources.”

JONNY WAKEFIELD photo

CAPP's Geoff Morrison: “You can’t get 100 per cent of your reductions from 17 per cent of the problem.”

Oil and gas production accounts for around 17 per cent of B.C.’s overall emissions, and while that can be reduced, those measures shouldn’t discourage investment, Morrison said.

“You can’t get 100 per cent of your reductions from 17 per cent of the problem.”

Talk of new taxes on emissions at both the

federal and provincial level come at a time when the oilpatch is hemmed in on multiple fronts, Morrison said.

Natural gas exports have fallen 29 per cent since 2007 as Canada’s main customer, the U.S., inches closer to becoming a net exporter of gas.

While production in Canada is up 13 per cent since 2005, U.S. shale gas production jumped 42 per cent in the same period. Morrison noted the Marcellus Shale in the Northeast U.S. produces more natural gas than all of Canada.

Prices have taken a beating, too. The spot price for natural gas at the AECO sales hub in Alberta, a major indicator, was down 64 per cent over 2014. Meanwhile, upstream investment in B.C. was down 63 per cent, and the number of wells drilled in 2016 is expected to be about half of what it was two years ago.

Morrison argued that B.C. has the highest price on carbon of the jurisdictions it competes with, saying further increases would be a drain on investment.

“We’re looking at how we can collectively reduce emissions in difficult economic times,” he said.

Continued on Page 20

B.C. mayors group, DC councillor support carbon tax bump Jonny Wakefield Staff Writer

A Dawson Creek city councillor says she’s likely the only elected official in Northeast B.C. to support an increase in the province’s carbon tax.

On April 7, the BC Mayors Climate Leadership Council announced support for a plan to bump the tax by as much as $15 per tonne annually.

The leadership council includes mayors and councillors from eight B.C. communities, including Dawson Creek Coun. Cheryl Shuman, who stressed that the plan does not have the endorsement of Dawson Creek city council.

“If I was to bring something like that to coun-

cil, you know darn well that would not pass,” she said. “I’m probably the only elected official in the Northeast who is in support of this.”

B.C. was the first jurisdiction in North America to bring in a price on carbon in 2008.

“This is not something new. When (the carbon tax) first came in when Gordon Campbell was premier, I was absolutely supportive of it and out there promoting the benefits of putting a price on carbon,” Shuman said. “In my first campaign (for council) in 2008, I basically ran on the platform of this kind of stuff.”

The mayors’ council announced its submissions to the Climate Leadership Plan April 7, the same day the Northeast B.C. Resource Munici-

palities Coalition, a regional business and local government group, issued a press release saying carbon tax increases would stifle investment in B.C.’s oil and gas sector.

Shuman felt there was “misinformation” around the carbon tax, noting increases in carbon prices are offset by decreases in other provincial taxes.

Shuman said the mayors council favours “predictable annual increases” between $6 and $15 per tonne. “Absolutely (I’m) in favour of that.

Dawson Creek council? I don’t speak for them,” she said. reporter@dcdn.ca R001697755

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Plans for skilled immigrant project 'dead,' city says Matt Preprost

Staff Writer

A controversial plan to recruit skilled immigrants to Fort St. John has been quietly scrapped.

City officials confirmed in March that they met with staff from the Ministry of Jobs, Tourism and Skills Training on Nov. 6 to review the proposal. However, the ministry said it wouldn't approve the city's Immigration Pilot Project.

City council voted down the project in a closed council meeting three days later on Nov. 9.

"It's dead," said Moira Green, the city's economic development officer who was in charge of the project. "What's next? I honestly don't know."

The province put the city to work last summer to draft the project in conjunction with the Provincial Nominee Program to address labour shortages in the region. At the time, the city

was bracing for 57 major industrial projects in the region that was reported to need more than 5,000 permanent resident workers and up to 18,000 provisional workers.

The project was being modelled off a similar one in Winkler and Morden, Man., which had recruited around 70 skilled workers for Morden, a manufacturing town.

However, ministry staff told the city that changes to federal immigration rules and a years-long backlog in the Provincial Nominee Program made the project unfeasible, Green said.

Questions sent to the ministry were not answered.

Mayor Lori Ackerman announced early details of the project in August during the opening of STEP Energy Services new office in the city.

Opposition from local residents was swift, however, with many pointing to rising unemploy-

ment in the region.

One Alberta woman even started a petition with more than 3,300 signatures calling for the program to be scrapped.

Green said there's no plan to revive the project. However, she added the estimates for the number of skilled workers needed in the region remain accurate if any two large liquefied natural gas projects proceed.

"That being said, it would be a really good opportunity for Canadian migration," Green said.

"But, we are looking for people who want to live in our communities and work in our communities. It's not just a great place to work, it's a great place to live."

The city continues to work on its downtown revitalization, transportation and recreation plans, which will help to build a "recruitable community," Green said. editor@ahnfsj.ca

Canadian gas production to grow next decade even without LNG Pat Roche

Daily Oil Bulletin

Western Canadian natural gas production will resume growth in 2021 or 2022 with or without LNG exports from the West Coast, a Wood Mackenzie analyst predicts.

A widening gap between Henry Hub and AECO prices and affordable transportation to the Chicago area, coupled with growth in U.S. domestic demand and U.S. LNG exports, will combine to restart western Canadian growth, said Dulles Wang, the consultancy’s principal analyst for Americas gas research.

Wood Mackenzie expects the Petronas-led Pacific NorthWest LNG project, proposed for Lelu Island, near Prince Rupert, B.C., to proceed and come onstream in 2022, Wang told a Canadian Energy Research Institute (CERI) conference on March 14.

“But even without Petronas’s project, we still think the WCSB production will grow because you still have a lot of low-cost gas in the Montney,” Wang said.

Wood Mackenzie expects western Canadian production, which has been declining, to stabilize next year and remain flat till 2021 or 2022 when it expects growth to resume.

Asked by a member of the audience why he expects this to happen even without West Coast LNG exports, Wang cited the low cost of gas in Continued from Page 17 Chief among those is tying upstream oil and gas to the BC Hydro grid, which “remains the foremost opportunity for significant GHG mitigation in B.C.” One of those projects, BC Hydro’s Dawson Creek and Chetwynd Area Transmission Line,

northeast British Columbia, the “manageable” cost of pipeline transportation to the U.S. Midwest and expected growth in U.S. gas demand.

Also, if U.S. carbon policy leads to more coalfired power plant retirements in the Midwest, this could add to gas demand in that market, he added.

Wang’s view differs from the more conventional outlook that western Canadian gas output will fall without LNG exports.

He expects gas demand growth in the U.S. Gulf of Mexico region—including from petrochemical and other industrial consumers as well as future LNG export projects—will pull gas from plays such as the Marcellus and the Eagle Ford, strengthening Henry Hub prices.

“We think ... by 2024, 2025, there could be a second wave of North American LNG projects coming online. So that would drive growth” in gas demand, he added.

Wood Mackenzie expects that by 2021-22, the Henry Hub prices will exceed about $3 per mmBtu (in 2015 dollars).

“So by that time, a lot of the gas in the Montney will clear the break-evens,” he said, adding that if Canadian gas isn’t exported via any of the proposed West Coast LNG projects, it could still be competitively pipelined to U.S. Midwest markets in particular.

In that market, he said, gas from plays such as the Montney could compete with supplies from the U.S. Rocky Mountain region and the

mid-continent.

The consultancy’s bullish outlook for LNG exports from North America by the mid 2020s contrasts the current state of global gas demand. Wang said Wood Mackenzie’s view is based on the long-term outlook for Asian demand. He acknowledged that a Canadian LNG project isn’t an easy sell amid current global gas markets.

“But at the same time, it’s probably the best time to do [an LNG] project in Canada,” he said. “You’ve got some looseness in the labour market, the steel prices are coming down, and you’re able to negotiate better EPC [engineering, procurement and construction] contracts right now in Western Canada.”

No western Canadian LNG export project is likely to come online till early next decade, he said, adding that these projects will target the Asia Pacific market.

“They are not necessarily competing with a lot of these U.S. projects coming online right now in this decade, because a lot of [the latter’s exports are] going to the European markets,” Wang said.

“But for Asian demand, the opportunity will open up by early next decade when you see a lot of these long-term existing contracts rolling off and you’re seeing Asian buyers looking at new sources of supply. And that opens up the opportunity for the western Canadian projects.”

is expected to significantly reduce emissions in the South Peace. Progress Energy, the largest driller in the province, is seeking to plug its Pink Mountain operations into a privately funded transmission line, but the proposal has yet to be approved.

Upstream methane emissions—a greenhouse gas more potent than carbon dioxide—

can be cut through new controls leaks and venting, Morrison said, calling it the secondbest option behind electrification.

He added that landfills are the single-largest emitter of methane in B.C. reporter@dcdn.ca

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Local government convention to feature oilsands tour

Jonny Wakefield Staff Writer

Mayors and councillors from across Northern B.C. will have a chance to tour the oilsands during a convention in Dawson Creek this May. As part of the upcoming North Central Local Government Association (NCLGA) annual general meeting in the Mile Zero City, the Canadian Association of Petroleum Producers is chartering a plane to whisk delegates from Dawson Creek to Fort McMurray, where they'll have a chance to grill companies with projects impacting Northern B.C. The towns lie 560 kilometres apart, as the crow flies.

"They'll be flying people literally from the front doors of the Encana Events Centre to the oilsands, where they'll land and do a tour," said Oliver Ray, NCLGA executive director. "Then they'll fly them back to the doors of the Encana Events Centre.

"Well, they're not landing at the doors of the Encana Events Centre," he corrected himself.

"It's not a big sell on 'rah-rah go oilsands,'" he added. "It's an information-gathering tour. Obviously people feel very differently about these projects. It's an opportunity for people to ask those tough questions and give their feedback to any industry players that are involved."

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The oilsands production process at a Syncrude Canada Ltd. mine in Alberta. Dawson Creek Coun.

Shaely Wilbur, one of the organizers of NCLGA conference, says Northern B.C. and the Alberta oilsands will continue to be closely linked. "We definitely understand natural gas better than we do oil production in our particular neck of the woods," she says.

100 Mile House to the Yukon border, many of which would be directly impacted by heavy oil export schemes like Enbridge’s Northern Gateway.

“It hits 80 per cent of the communities within the NCLGA’s membership,” Ray said of the pipeline.

While that project is on life support—its National Energy Board permit will expire in June if substantial construction does not begin—the oilsands will continue to have direct impacts on Northern B.C., organizers say.

Dawson Creek Coun. Shaely Wilbur, who is organizing the conference alongside Tumbler Ridge, Chetwynd, Pouce Coupe and the regional district, said she has plenty of questions for oil producers.

“I think it’s important to be in-the-know, given how close we are in Dawson Creek,” she said, adding Premier Christy Clark has set five conditions for heavy oil exports through B.C. “We definitely understand natural gas better than we do oil production in our particular neck of the woods.”

Also on the agenda is an “energy tour” of the Peace Region, including the Bear Mountain Wind Park, Dawson Creek’s reclaimed water facility and the Site C dam.

The NCLGA votes on policy proposals from member cities and towns, some of which become lobbying priorities of the Union of B.C. Municipalities. Among the more controversial at this year’s conference: a proposal from Williams Lake to require GPS monitoring of sexual offenders.

The conference will be held in Dawson Creek from May 4-6. reporter@dcdn.ca

Northern British Columbia and Alberta’s Oil and Gas Industry

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Provincial support for LNG waning, poll finds Jonny Wakefield Staff Writer

British Columbians’ views on hydraulic fracturing have “hardened,” with 61 per cent saying they don’t support the industry.

That’s according to a new poll on liquefied natural gas (LNG) development from Insights West, released March 24.

The poll found support for LNG has waned since a study conducted in August 2013, while opposition to fracking has grown.

The pollster carried out an online study between March 16 and 18, taking a random sample of 802 respondents—including 57 from Northern B.C. Of those, 43 per cent supported the provincial government’s goal of establishing an export LNG industry—a decrease of seven points from the last poll, taken shortly after the 2013 provincial election.

Opposition to fracking, mean-

file PHOTO

“Fewer British Columbians in 2016 believe that the LNG industry will be auspicious for every resident of the province”: pollster while, grew by 14 points in the 30 months between studies, to 61 per cent. Only 23 per cent said they said they support the process, while just over half (55 per cent) were aware fracking takes place in British Columbia.

Three-in-five respondents had specific concerns about the

fracking process, including possible water contamination (62 per cent), its impacts on landscapes (62 per cent), and its potential to cause earthquakes (57 per cent).

On the benefits of fracking, 54 per cent believed it would lead to more jobs in B.C., 51 per cent thought it would drive foreign in-

vestment, and another 54 per cent saw LNG as a cleaner alternative to coal.

“It’s an emotional issue,” said pollster Mario Canseco, saying LNG was an “essential component” of the 2013 election. “I think everybody expected that because of how this was framed, we’d be enjoying the benefits of (LNG) already.”

He pointed out that not one of 20 coastal LNG plants has entered the construction phase.

Canseco added the issue appears to have become regionalized, with 42 per cent saying LNG will “exclusively benefit” only some communities.

“Fewer British Columbians in 2016 believe that the LNG industry will be auspicious for every resident in the province,” he said in a release.

The study has a 3.5 per cent margin of error. reporter@dcdn.ca

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APRIL 15, 2016

Retreat to the Country Executive Home in Pacific Properties $799,000 • 3754 sq ft fully finished home on 4 acres • High end finishings, 3 bedrooms on main level with spa ensuite • Lower level set up w/second kitchen, 2 bedrooms, den/media room • Country setting close to town • More info at www.century21.ca/101108174

160 Acres with House and Shop! $749,000

• 4 acres with updated home, 15 min to town • 5 bdrm, 2 bth, fully finished basement • Large attached garage, fenced property for horses • More info at www.century21.ca/101136367

Beautiful Country Estate

New Listing! 54 Acres, Bordering Crown Land

Hobby Farm with Log Home & Shop $479,000

$595,000

• Updated 1700 sq ft Log Home on 19.76 Acres • Outdoor wood boiler heats house and 32 X 40 Shop • Guest cabin, Hot tub, gazebos, storage shed, firepit • Set up for Hobby farm with corrals, pastures, dugout and ponds!

• Call for more info at www.century21.a/101132388

• Fully updated 3 bdrm, 2 bth home, with large tiered deck • 54 acres, bordering crown land offering ample privacy • Road access from the front and south side of the property • Property features a dugout for your livestock • More info at www.century21.ca/101130920

REDUCED! Put Your Mobile Here $199,000

Last Lot in Pacific Properties!

$734,900

$279,900

• Beautiful 2009 built custom home in Country Meadow Estates • 5 bedrooms, 3 bath, fully finished basement • Situated on 4.5 Acres in area of fine homes • Motivated Seller, bring offers!

• More info at www.century21.ca/101098779

• 4 acres in Prestigious Pacific Properties • Build your dream home and shop • Percolation test completed, and lagoons approved • Great location on the edge of town, with valley views • More info at www.century21.ca/Property/101086649

• Fantastic 4.97 acre property, 10 minutes to Fort St. John • Perfect place to sit a mobile home, or build your dream house • Close to all recreational amenities Charlie Lake has to offer • Easy commute to town • www.century21.ca/101079794

R0011228184

• 1365 Sq Ft 3 bdrm updated home, with concrete basement • Impressive 1920 Sq Ft heated and insulated, wired shop with 16” doors • Barn, round pen, 2 shelters for animals • Oil lease with $5850.00 revenue/yr. Only 15 minutes to town • More info at www.century21.ca/101111679

New Listing! 4 Acres in Baldonnel $469,000

2 Bedroom & 2 Bathroom Condos (some with Den) Prices Starting From $284,900 Price Includes: • GST • 2 Parking Stalls with Power • Modern Gym • Games Room with Pool Table, TV & Lounge Area • Storage Lockers

Show Home Hours

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Quartz Countertops In-floor Heating 9’ Ceilings Views of Country Hills Across from Man-made Lake & Walking Trails

Kevin Pearson | 250.787.6737 Elizabeth Chi | 778.256.2888

Thursday & Friday 4pm - 7pm Saturday & Sunday 2pm - 4pm #101, 11205 105th Ave., Fort St. John, BC

Visit our virtual tour at www.signaturepointe.ca