Pipeline News North: August 2015 by Pipeline News North

Election Report: Where do federal leaders stand on energy? AUGUST / SEPTEMBER 2015

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LNG legislation is passed. The election writ is dropped. Governments pour more pavement along Highway 97. New plants move forward, worker camps are proposed. Second quarter struggles were real, but conventional wisdom shows light is on the horizon.

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AUGUST 14, 2015

Fort St. John, B.C.

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PNN

NUMBERS

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

$13.18 million: The amount that Alberta’s oil and gas land tender pulled in for August. Story on Page 11. $1.34 million: The amount that B.C. pulled in at its July land tender Story on Page 11. 0: The number of environmental assessments need for Encana’s Saturn plant. Story on Page 17. $1 billion: How much AltaGas plans to spend in B.C. over the next two years. Story on Page 27.

37%: Amount energy consumption is forecasted to climb by 2040. Story on Page 30. 600: Number of workers that could be housed in a new work camp proposed for the Halfway River. Story on Page 16. $500,000: Combined value of a bulldozer, excavator, two trailers and a pair of pumps stolen from a laydown site near Tumbler Ridge. Story on Page 8. 20,000: Gallons of natural gas that would be chilled daily at AltaGas’s proposed Dawson Creek LNG plant. Story on Page 7.

4.4: The number of kilometres that will be twinned on the Alaska Highway between Braden and 288 roads. Story on Page 12. $196.8 million: How much Alberta has made through oil and gas land tenders year to date. Story on Page 11. 178: Number of gas wells completed in B.C. up to the end of July. Story on Page 24. 27: Number of active drilling rigs in B.C. in July. Story on Page 10.

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Stabilty ahead. Can you 5 wait 6 months? Staged development follows 6 passing of LNG legislation

PNN 09

AltaGas: LNG plant in DC 7 online by end of 2015

20 The second quarter results are in

September start for Pacific 8 NorthWest? Not likely.

Half million dollar heist of 8 heavy machinery FSJ Mayor schools Squamish 9 on resource management BC oil patch performance 10 ahead of its peers

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22 Support growing for pipelines in British Columbia 23 WOODFIBRE AGREES TO SQUAMISH CONDITIONS 24 PRODUCERS COMPLETING GREATER PERCENTAGE OF WELLS 26 BC doles out royalty credits

Alberta, B.C. tough out 11 tough land sales

ELECTION2015: The parties, 14 the policies, the pledges

17 Green light for Encana Saturn sweet gas plant 18 Swinging away summer: Oilmen’s Couples Golf tourney

Squamish Nation postpones 8 Woodfibre decision to fall

Big bucks to pour new 12 pavement along HWY 97

16 NEW CAMPS CONTINUING TO CROP UP

27 ALTAGAS PLANS LIQUEFIED PROPANE PLANT FOR COAST

29 Oil struggles will have only minor impact on BC 30 Fossil fuels will share landscape with renewables Look for PNN on Twitter @PipelineNN

Published monthly by Glacier Ventures International Corp. 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.

AUGUST 14, 2015

PIPELINE NEWS NORTH •

OPENING REMARKS

#oilsands

Conventional wisdom

will be wrong again T

hings will get better because they can’t get worse. We’re at or near the bottom. Better times ahead. But you’d never know based on oil prices or the news. WTI closed August 11 US$43.08 a barrel, a price unseen for more than six years since the dark days of 2009. The commentary is universally bearish. Everyone from analysts to oil company CEOs are saying what you see is what you get for the foreseeable future. Comparisons to the great price collapse of 1986 and the 15-year nuclear winter that followed are again making headlines. It’s not awful; it’s worse. Numerous challenges exist. Every day there’s yet another reason why oil prices will never increase. Iran. China. Greece. Global inventories. OPEC overproduction. Rising North American rig counts. Carbon taxes. Corporate tax increases. Royalty reviews. No pipelines. The news is so depressing more are saying this downturn is the worst ever, although there is significant evidence to the contrary. This is not new. What the industry has always done is extrapolate; whatever happened yesterday will continue. If things are good, they always will be. If things are bad they will remain so forever. After 36 years of writing about the always-volatile oilpatch, the only constant is the herd is usually wrong, regardless of the direction it is headed. First the bad news. The modern oil industry has never operated without Saudi Arabian or OPEC supply management. The possibility of Iran increasing production if its nuclear inspection agreement is ratified weighs heavily on market sentiment. This is new. Commodity prices as a group — oil, potash, iron ore, coffee, and copper — are at lows unseen since early this century. This is made worse by a strong U.S. dollar. Hedge funds specializing in commodities are losing money and shrinking as profits become more elusive. This too is new. Future oil demand is in doubt for three reasons, all new. China, the world’s second largest economy and commodity consumer, has serious financial problems with the long-term impact unknown. The latest blow was devaluating the Yuan. More governments unquestioningly link oil to climate change and are taking steps to ensure consumers use less. We’re told daily the future of mankind depends on using less oil. Near zero interest rates and quantitative easing no longer stimulate economic growth. This affects commodity demand and price. The replacement cost of tomorrow’s barrels seems unknown.

Current production is thought to be impervious to price. Lower prices have always reduced production. That low prices somehow won’t crimp future supply this downturn is also new. Hide the sharp objects. This is a big batch of misery. Now the positive. With the exception of oilsands mines, all reservoirs yield less oil tomorrow than today. Typical decline rates for the best conventional reservoirs is 3 per cent to 5 per cent per year and the output of most shale oil wells falls 50 per cent or more in the first year. At 4 per cent globally, this is a 3.8 million b/d decline in the next 12 months at current output of 96 million b/d. Without continued investment production will fall. The latest information is U.S. shale oil production peaked in April and will decline by 360,000 b/d by September. Global oil and supply demand curves simply must and will cross and they will. Comparisons of the current situation to the mid-1980s remain ludicrous. When oil prices collapsed in 1986 and remained low in real terms for 15 years, world oil supply exceeded demand by about 14 million b/d. This was nearly 25 per cent of world demand of 60 million b/d. The current surplus of supply over demand in Q2 was about 3 million b/d, or 3 per cent. This is shrinking. This is nothing like the situation in the mid-1980s and to suggest otherwise is uniformed and irresponsible. Rig counts are rising in the U.S. and Canada because they must. Oil companies must drill to survive. Efficiencies always emerge when they become essential. The rise is not meaningful. It is impossible for the reactivation of only 42 of 981 laid down drilling rigs in the U.S. to sustain or increase production. The next market turn will be dramatic and will be up because it can’t go down. The current mantra is for the first time in recent history and without supply management (see above) somehow crude oil is the only commodity that will trade in a narrow and predictable band when supply and demand achieves equilibrium. The futures curves are wrong. There is likely no good news in the short term, the next couple of months. Prices may even fall further. Keep the faith. In the medium term — the next six months — there will be growing stability and confidence if federal and provincial politicians don’t do anything really awful. But the long term looks good. The herd is wrong again and global oil supply and demand will prove it. David Yager is the National Leader of MNP’s Oilfield Services group. –Daily Oil Bulletin

Watch for the 2015-2016 edition of the

Oilfield Map

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LNG legislation passed...

B.C.’s LNG legislation has officially passed. The bill received Royal Assent on July 21 after the B.C. Legislature reconvened for a special summer legislative session to debate Bill 30, the Liquefied Natural Gas Project Agreements Act, which provides the legislative authority for the government to enter into LNG project agreements. The act allows for ratification of the first LNG project agreement, signed with Pacific NorthWest LNG, the planned Petronas project.

In June, Pacific NorthWest LNG announced it had reached an investment decision, subject to approval of the project agreement by the B.C. legislative assembly and a positive regulatory decision on the project’s environmental assessment by the federal government. The B.C. government publicly released the project development agreement it signed with Petronas earlier this month. Pacific NorthWest LNG issued a conditional final investment decision last in

June, but outlined a couple of conditions that still need to be met. The FID will be confirmed once two outstanding foundational conditions have been resolved. The first condition — which has ostensibly now been met — was approval of the project development agreement by the Legislative Assembly of British Columbia, and the second is a positive regulatory decision on the environmental assessment by the federal government. –Daily Oil Bulletin

... staged development anticipated Major greenfield LNG projects off British Columbia’s West Coast likely will proceed one at a time to avoid runaway cost escalation, although it’s still difficult to say which will be the first to be constructed, says a Wood Mackenzie vice-president. “I think this is really about managing the flow of projects,” said Gavin Thompson, vice-president, China and Northeast Asia gas research for the global energy consultancy. “Canadian project developers really don’t want to repeat the Australian experience of three projects [proceeding] simultaneously and seeing costs blow out as a result.” There currently is some competition among suppliers with Petronas recently announcing a conditional final investment decision, while Royal Dutch Shell has received environmental

assessment approvals. Two smaller niche projects, Woodfibre LNG and Douglas Channel LNG, likely will be the first to come into service in 2019-2020, according to Thompson. While Asian LNG demand remains strong, rising to 350 million tons in 2030 from 200 million tons in 2015, there is some risk in the pace of demand growth, especially around China, he said. Wood Mackenzie has reduced its Asia Pacific demand forecast for LNG through the long-term. The lower forecast is driven by weaker economic growth in key markets, a slower pace of power demand growth, more competition from coal and nuclear for power generation, the growth in hydro and other sources of renewable energy and China’s changing gas supply mix. –Daily Oil Bulletin

AUGUST 14, 2015

PIPELINE NEWS NORTH •

LNG plant could come online by the end of year Jonny Wakefield

Pipeline News North

While west coast export projects remain in limbo, a liquified natural gas plant could be up and running in Dawson Creek by the end of the year. An AltaGas Ltd. official told Alaska Highway News on Friday that the company aimed to begin operations at its Dawson Creek LNG plant by no later than the end of the year. The plant would be the hub of a $250-million network of LNG processing facilities spread across northern British Columbia. The AltaGas plant would produce around 20,000 gallons of chilled natural gas a day, most of it aimed at oil patch customers. The facility will consist of modules on skids that will be installed in an industrial area north of Highway 97. While the Dawson Creek facility is not B.C.’s first LNG plant, it would be the first to come online on Premier Christy Clark’s watch. Clark visited Dawson Creek last summer to sign a final investment decision with the company.

Unlike the roughly 20 facilities proposed for B.C.’s west coast, the AltaGas project in Dawson Creek is aimed at domestic customers, chief among them the oil and gas industry. Even if it ramps up to its potential 500,000 gallons, it would still be much smaller than the export projects. AltaGas Chief Financial Officer Deborah Stein told the Alaska Highway News the company sees regional LNG as a pilot project. As such, the company decided to try to move forward without a firm list of customers. “Because it was a pilot project we were prepared to take that financial risk,” Stein said. “It was relatively small. We made the decision to move forward with the pilot and go out and provide the service to the community without major long-term contracts underpinning the investment opportunity.” LNG produces fewer greenhouse gas emissions than diesel, which many drilling companies use to power their oil patch

operations, Stein said. However, the oil price downturn has made dirtier alternatives even cheaper, while gas drilling in the Peace was down around 30 per cent in July over last year. That’s made it more difficult to find customers. “The ability for LNG on a price basis to be competitive with things like propane and diesel has become a little bit more challenging,” Stein said. “We may have lost some ground on pure economics...but, if you look at the upside for the environment, there is a significant incentive for end users.” She added that if the Dawson Creek project is a success, similar facilities could be built in Alberta to provide gas for oil sands upgrading. At its peak, the northern LNG network would include facilities in Fort Nelson, Port Edward and Terrace, connected by rail and the PNG pipeline. The Dawson Creek facility is the only part of the network currently under construction.

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LNG/COMMUNITY Troyer �inalist for entrepreneurship award

Squamish First Nation postpones Woodfibre decision A vote by the Squamish Nation chiefs and council on the export facility proposal slated for Squamish has been delayed until fall because the Nation and the proponents could not come to an agreement. “The vote has been postponed until sometime this fall, as there has been no agreement between Squamish Nation and the proponents – Woodfibre LNG, FortisBC, B.C. government – on the 25 conditions,” Chief Ian Campbell told The Squamish Chief July 27. Campbell declined to say what the key sticking points were or to comment further on the negotiations. The Nation issued 25

conditions last month that would have to be met by the proponents in order for the Squamish Nation to support the facility. Some of the conditions included: The FortisBC pipeline avoiding the Skwelwil’em Wildlife Management Area, insurance coverage or a bond to cover risks of personal loss and injury costs for Squamish Nation members, and no fueling of LNG tankers in Squamish territory. If the first 24 conditions are met, the 25th condition is: entering into an economic benefits agreement with the Nation that will be reflective of the Squamish Nation’s aboriginal rights and title interests. –Squamish Chief

September start for Petronas? Not likely. B.C.'s finance ministry is throwing cold water on a report that Malaysian energy company Petronas could begin construction of its west coast liquified natural gas terminal this September. A report in the Malaysian newspaper the Star attributed a September construction start to finance minister Michael de Jong, who is visiting the country in hopes of closing a deal with Petronas on its Pacific NorthWest LNG project. The $36 billion natural gas terminal, potentially the largest foreign investment in the province's history, still requires approval from the Canadian Envi-

ronmental Assessment Agency (CEAA) and area First Nations. CEAA approval is expected this fall, ministry spokesperson Jamie Edwardson said, adding the government isn't in a position to say when construction might begin. "The minister, through his conversations, understands the company is interested in starting work as quickly as possible after [environmental approval]," he said. "At that point it would be in a position to start construction on its own timelines." He said de Jong's remarks were taken "out of context." –PNN

A local businessman was recently named as a finalist for a major accounting firm’s entrepreneurship award. Steve Troyer, of Troyer Ventures, was named as a finalist for the 2015 Ernst and Young Business Services Entrepreneur of the Year award for Pacific Canada. Troyer will find out if his company, which hauls fluid for oil and gas producers, will win on Sept. 24. “It is an honor to be acknowledged by the business community on this level,” Troyer said.

Troyer was not sure why he was nominated, but figured it was the years of his company’s growth that caught the evaluators’ eyes. Troyer is competing with two other companies in his category. If his company wins the Pacific award in his category, he could be selected to compete with winners from other regions to become the Canadian Entrepreneur of the Year. Once that done, his company could potentially compete globally with more than 50 countries for the title of EY World Entrepreneur of the Year in June 2016. –PNN

$500K in machinery stolen in Tumbler Ridge

Tumbler Ridge RCMP are asking for the public’s assistance in solving a major theft in the Peace Region. On July 15, a bulldozer, excavator, two storage trailers and two pumps were stolen from a lay-down site on the South Grizzly Forest Service Road used by a drilling company operating in the area. The estimated worth of the stolen equipment is about $500,000. The site has been used for storage by the company since September 2014 when they put a hold on their Tumbler Ridge operations, according to RCMP. The company is not being named at this time. Anyone who has information about this crime is asked to contact the Tumbler Ridge detachment at 250-242-5252 or call Crimestoppers at 1-800-222-8477.

Orca LNG licenced for export The National Energy Board (NEB) has approved Cypress, Texas-based Orca LNG Ltd.’s application for a 25-year natural gas export licence. The operation will be relatively small-scale compared to the two giant export terminals of Shell’s LNG Canada and Petronas’ Pacific NorthWest LNG. Orca will use only one vessel to export gas drilled in the Western Canadian Sedimentary Basin from a port near Prince Rupert. Orca hopes to be fully operational in 2019. The licence was granted, the NEB says, be-

cause the quantity of gas proposed to be exported is surplus to Canadian needs. The licence ties the company to a maximum annual export quantity of 38.06 billion cubic metres. The licence will begin the date of the first export. If the project is not up and running within ten years, the licence will expire. Orca LNG Ltd. said it is in discussions with several pipeline companies to use their existing infrastructure to feed a dedicated pipeline for the project. –PNN

AUGUST 14, 2015

PIPELINE NEWS NORTH •

COMMUNITY

“

rather than slamming the door in their face, I have said to them: ‘You want to come in, this is how it is going to work.’

”

Fort St. John Mayor Lori Ackerman schools Squamish on resource management Jennifer Thuncher Squamish Chief

If proponents are coming to town regardless of what a municipality might want, the community should get something out of it. That was the main message of visiting City of Fort St. John Mayor Lori Ackerman on Tuesday. Ackerman spoke to a packed house at a Squamish Chamber of Commerce breakfast meeting, sponsored by Woodfibre LNG, at the Squamish Adventure Centre. Ackerman said local governments, especially in B.C., are not at the table to make decisions on major projects. “For us it is not a yes or no decision. We aren’t part of decision making when it comes to a proponent coming to talk to us,” she said. What communities can do is have a strong official community plan, she said. “It is the policy that is going to drive you forward as a community.” “The approach that we took… Noah wasn’t in favour of the flood, but he built an arc and that is the responsibility of local government,” she said. A strong community plan lets the proponents know what the community will and will not accept, she said. “It gave us a foundation… that we could take to that proponent, and since then every other proponent, and say, ‘This is our community, this is where we are going and this is how you’re going to keep us on track.’” Foundations of Fort St. John’s community plan are: economic prosperity, environmental sustainability, social inclusion and cultural diversity. Proponents are usually fine with community demands, Ackerman said, because they want to be part of the community. “So rather than slamming the door in their face, I have said to them, ‘You

want to come in, this is how it is going to work.’” She said if money is to be made from a project, from property taxes for example, it can be put towards community assets, such as a sports complex, a new recreation or a community foundation, as Fort St. John has done. She said in her city’s community measures agreements are put in place, including for BC Hydro’s Site C – a dam and generating station slated for seven kilometres from Fort St. John’s downtown. In the agreements are amenity contributions. The Fort St. John council has also said in a community measures agreement it will accept temporary workers flying in and out only for the construction of projects, but for the operation of the facility, the workers have to live within the community, Ackerman said. Asked by Squamish chamber director Chris Pettingill about the needs of the environment and about transitioning away from fossil fuels, Ackerman said that was something global consumers have to do first. “When we quit relying on fossil fuels then we can start getting off them. The reality is, unless you are sitting in front of me wearing hand-woven cotton or hand-woven silk and you got here riding a hand-carved wooden bicycle, we are fossil fuel,” she said. “When we quit as consumers then there won’t be a demand… but local government can’t do that.” Ackerman said that Fort St. John is light years ahead of other communities in terms of its community and corporate initiatives for climate action. Hours after her talk, the provincial government authorized construction to begin on the Site C dam near Fort St. John in spite of numerous legal challenges currently underway attempting to stop the project.

SQUAMISH CHIEF PHOTO

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RIGS

More rigs drilling in July than previous months

2015 JANUARY Drilling

Down

Total

Utilization

72 per cent

FEBRUARY

Jonny Wakefield

Pipeline News North

The number of drilling rigs operating in B.C. in July was down 30 per cent compared to this time last year, according to new data from an industry group. The weak July follows on depressed drilling rates in 2015 as the industry copes with the oil price collapse that began late last year. However, the data suggest that B.C.'s oil patch is faring better than the rest of Western Canada. In July, 27 of the 83 drilling rigs in B.C. were actively drilling, or 32.5 per centâ&#x20AC;&#x201D;down from a utilization rate of 62.3 per cent in July 2014, according to the Canadian Association of Oilwell Drilling Con-

tractors (CAODC). This time last year, 48 of the 77 rigs in B.C. were actively drilling. The overall number of rigs in B.C. has fluctuated from a low of 72 in January to a high of 83 in May and July. The rig count peaked at 80 last year. The CAODC estimates one active drilling rig creates around 135 jobs. Drilling rates were also down during the first quarter of 2015, typically the most active time for drilling. The first three months of 2015 saw rig utilization rates of 72, 64.8 and 53 per cent, respectively, compared to rates of 79.2, 82.8 and 82.5 per cent during those same months in 2014. See RIGS Page 22

Drilling

Down

Total

Utilization

64.84 per cent

Drilling

Down

Total

Utilization

53.22 per cent

Drilling

Down

Total

Utilization

30.18 per cent

Drilling

Down

Total

Utilization

20.48 per cent

Drilling

Down

Total

Utilization

18.34

Drilling

Down

Total

Utilization

32.53 per cent

MARCH

APRIL

MAY

JUNE

JULY

SOURCE: CANADIAN ASSOCIATION OF OILWELL DRILLING CONTRACTORS

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LAND SALES B.C.’s weak land sales continue B.C. continued its weak run of land sales in 2015 with a $1.34 million July auction, as the industry maintains its tight spending with respect to Crown sales this year. The industry acquired 5,232 hectares at an average of $256.87 per hectare. After seven sales so far this year, the government has collected $8.11 million on 29,435 hectares at an average price of $275.63. To the same point of 2014, the province had collected $92.94 million on 62,233 hectares at an average price of $1,493.48 per hectare. The 2015 spending trend puts B.C. on track to possibly hit an over 30-year low in bonus revenue for a calendar year. The 2010 to 2014 five-year bonus average is $362.77 million, the 10-year average (2005 to 2014) is $758.01 million and the 15-year (2000 to 2014) average is $629.02

million. It’s also been a bleak start to the province’s 2015/2016 fiscal year, which started in April 2015. After four sales, B.C. has collected $3.59 million on 17,321 hectares at an average price of $207.22 per hectare. There is still prospectivity in B.C., but there are few if any companies starting up or expanding operations in B.C. Those that are there already generally have land positions. The highest bid at the July 2015 sale was placed on a 1,420-hectare drilling licence in the Buick Creek area by Contiguous Resources Ltd., about 55 kilometres northwest of Fort St. John at 94-A-11 and 94-A14. The parcel earned $761,105 in tender bonus at an average price of $535.99. Results of the province’s Aug. 12 sale were not available by press time. —Daily Oil Bulletin

Alta. land sale draws $13.18M The Alberta government generated $13.18 million in bonus bids for August, with some higher bids submitted when compared to the dismal July 22 sale, and weaker auctions held during May and June. Industry acquired 61,791 hectares at an average price of $213.29. Year-to-date, the province has collected $196.86 million on 1.22 million hectares at an average price of $161.61 per hectare. To the same point of 2014, $303.2 million had been paid for 630,165 hectares at an average price of $481.14. Highlights of the Aug. 5 sale included a pair of leases that combined for $1.62 million in bonus bids. Plunkett Resources Ltd. picked up one of these parcels for $808,445 at an average price of $3,157.99. Stomp Energy Ltd. acquired the other parcel for $814,077 at an average price of $3,179.99. These two single-section parcels in the Michichi Field are located in an area of active Mississippian Banff oil development, where Husky Energy Inc. is completing horizontal wells with multi-stage fracturing to the north and Marquee Energy Inc. is employing the same tactics to the east and south. A further two parcels in the area produced average prices of $1,379.99 and $1,305.88, respectively. Also, Northend Resources Ltd. acquired a 768-hectare lease for $1.27 million at an average price of $1,651.14. —Daily Oil Bulletin

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INVESTMENTS $4.5M for passing lane will prepare area for LNG investments William Stodalka

Pipeline News North

WILLIAM STODALKA PHOTO

More money for Highway 97 improvements Mike Carter

Pipeline News North

With work on twinning the Alaska Highway and its descent down the dreaded South Taylor Hill progressing, upgrades to more sections of Highway 97 between Dawson Creek and Fort St. John are in the works. Minister of Transportation and Infrastructure Todd Stone was in Taylor on July 31 to announce that 4.4 kilometres of the highway will be twinned between the Braden and 228 roads. The project will also include upgrades to sections of the highway at the 228 and Gibbs road intersections, adding east and westbound left turn lanes and intersection lighting. A westbound left turn lane will also be added at 226 Road. The total cost of the project is $17 million. Work will begin in August and is expected to finish by the fall of 2016. The highway has seen an increase in oil and gas related traffic

in recent years, and that’s expected to rise steadily. “These improvements will make a significant difference to the residents and commercial drivers who drive this part of Highway 97 every day,” Stone said. The majority of the work contract — $11.7 million — has been awarded to Dawson Creek-based Brocor Construction Ltd. The remaining $5.3 million will go towards the realignment of hydro poles, lines and other communication lines along the highway. “Four-laning this section of Highway 97 is going to make a significant difference for anyone who travels this route,” South Peace MLA Mike Bernier said. The project is part of $1 billion the ministry will be spending over the next three years on highways throughout the province as part of its 10-year B.C. on the Move transportation plan.

Highway 97 upgrades in Chetwynd underway Before arriving in Taylor Friday morning, Stone was in Chetwynd July 30 to highlight two Highway 97 upgrades with a $6.9 million price tag that are already underway. That includes the Wildmare Bridge replacement project, south of Chetwynd toward Prince George, which includes a new, wider bridge to accommodate heavy equipment and large infrastructure as it moves from the south of the province to the north. That work is being done by North Vancouver’s CEWE Infrastructure Ltd. It is expected to be complete this November. Sections of the highway in front of the Chetwynd and District Recreation Centre, which have been a perennial pain for motorists as a result of frost heaves, are also under repair. That work began earlier this summer and is expected to be completed in September. dcreporter@dcdn.ca

The provincial and federal governments announced on Friday $4.5 million will be spent to pave two kilometres of new passing lanes near Mile 58 of the Alaska Highway north of Charlie Lake. The project is currently in design, and will be tendered next year for completion by fall 2016. The announcement was made near the Stoddard Creek Road intersection of the Alaska Highway July 31. The federal government will put forward $2.2 million from its New Building Canada Fund, while the province will fork over the remaining cost. “We have heard from local communities that the congestion at Mile 58 is not allowing the people and goods to move through the area with ease,” provincial Transportation Minister Todd Stone said. Stone went on to say that these road improvements will help make sure that the province is ready for LNG investment decisions to come, and that federal funding partners are “absolutely critical” to making sure these roads get built. Peace River North MLA Pat Pimm called news of the upgrade “fantastic.” “This is something folks in the Peace Country have been asking for in a big way,” he said. Pimm noted that drivers are currently forced to slow down to 75 kilometres an hour behind some bigger trucks, and that about 8,000 vehicles pass through that section every day. Prince George-Peace RiverNorthern Rockies MP Bob Zimmer was on hand, and noted this was the last in a line of funding announcements. “(The new passing lane) helps my hometown of Fort St. John,” he said. reporter@ahnfsj.ca

AUGUST 14, 2015

PIPELINE NEWS NORTH •

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AUGUST 14, 2015

FEDERAL ELECTION

the PARTY // the POLICY // the PLEDGE

Conservatives

New Democrats

Conservative Leader and incumbent Prime Minister Stephen Harper may not be able to control the swings of global commodity prices, but he certainly can make the climate for resource development more favourable. Harper’s re-election would mean several things, perhaps most importantly that oil and gas exploration and pipeline development in Western Canada would remain on course. His re-election would also give him another term to push for Keystone XL, while moving the Energy East, Trans Mountain, Line 9 and Northern Gateway pipelines through the remaining regulatory channels. Another mandate would also allow him to bolster resource development in the Arctic. Many of these projects face stiff opposition, and could be tied up in the courts. While Harper has yet to make any definitive energy pledges in this election campaign, Conservative policies generally favour easier trade and movement of energy products between borders, provincial or otherwise. Harper will likely never introduce a carbon tax, and Conservative policy documents states the party believes tax incentives would improve energy efficiency for a cleaner environment. If Harper is re-elected, his ability to accomplish these things hinge on two factors: first, whether he will have another majority government to push through legislation and regulations as easily as he’s been able to do since 2011; and second, his diplomacy in working with the provinces, or even a minority government, to continue building his national energy plans.

NDP Leader Thomas Mulcair would bring a complete redesign to energy policy in Canada. He opposes Northern Gateway, has not taken a firm position on Keystone XL, but appears willing to support Energy East running from Alberta to Atlantic Canada. Indeed, Mulcair has hinted at support for expanding Alberta’s oilsands. However, the support comes with a price. If elected, one could certainly expect Mulcair to develop and implement a more stringent and vigorous environmental regulatory process focused on a project’s impacts on carbon emissions. Mulcair has spared few words in opposing regulatory changes made under Stephen Harper, and would likely reverse many of them, including taking power out of the government’s hand on deciding the fate of environmental assessments. Mulcair has also committed to a two per cent reduction in the small business tax, from 11 to 9 to per cent, which would likely help out smaller, independent operators working in Canada’s oil and gas patches. He has also expressed his desire to expand Canada’s refining abilities to keep raw resources in the country as opposed to exporting them out and buying them back.

Sittin’ On The Fringe Libertarian Party Todd Keller is leading the Libertarian Party in Prince George-Peace River-Northern Rockies. The party’s platform does not specifically delve into energy issues and development, however, the party does support strengthened property rights and say it would ensure individuals retain full ownership of the natural resources above and below their land.

Pirate Party Pirates propose utility corporations should meet, dollar-for-dollar, all public subsidies with private investment, and believe taxpayers should see returns for their subsidies before private investors are paid dividends. The party would encourage Alberta to use oil royalties for research into energy alternatives to move away from fossil fuels. This, they party says, would provide contingency against the boom and bust of oil. There are no candidates in northern B.C.

AUGUST 14, 2015

PIPELINE NEWS NORTH •

The writ has been dropped and the race is on for your vote on Oct. 19. There have been more broad statements than policy pledges so far, but we take a look at where the parties stand on the future of energy in Canada.

Liberals

greens

The young son of former Prime Minister Pierre Elliot Trudeau, Justin Trudeau has already pledged to kill Northern Gateway, while throwing his support behind Keystone and Trans Mountain. He has yet made a public stand on Energy East. While the Liberal platform includes a national carbon reduction plan with co-operation from the provinces, along with the phasing out of subsidies to the oil, gas, and other fossil fuel industries, he has thrown his support behind West Coast LNG development. He opposes Northern Gateway because the project crosses paths with sensitive ecosystems, including the Great Bear Rainforest. Trudeau has said he supports increased oil tanker traffic in Lower Mainland ports, namely Vancouver. Still, Trudeau faced sharp words from northern B.C. politicians in fall 2014, after calling for more scientific study on hydraulic fracturing before expanding exploration and drilling of natural gas. Like Mulcair, Trudeau has also pledged to revamp the National Energy Board, blaming the Conservatives for growing public distrust for energy projects. Trudeau believes including more meaningful participation into environmental assessments will restore trust in the system.

Love her or hate her, but Green Party Leader Elizabeth May, as lonely as she is as the Greens only MP in the House, has been making her voice louder when it comes to energy debate in the country. May opposes the Trans Mountain expansion. She believes public opposition to Northern Gateway is its harbinger of death, and believes most Canadians do not want Keystone to be built. She is skeptical about the Energy East proposal. She doesn’t think fracking is good technology. Much of the Green Party’s platform focus on shifting to more clean energy products, from wind, solar, and hydro, to create more jobs than the oil and gas industries. May has been critical of Canada’s failure to meet international greenhouse gas reductions it has committed to doing. May would implement a revenue-neutral carbon fee and dividend program, with Canadians getting a yearly cheque in return. Under the Green plan, the fees would be collected at the well head or coal mine, and paid out on a per capita basis. The party also calls for the end of subsidies to fossil fuel industries.

Information gleaned from party policy documents and media reports. –PNN

Christian Heritage This party does not believe in man-made climate change, and believes carbon taxes/credit exchanges would diminish industrial capacity. The party would promote renewable energy alternatives, and that it would spend resources currently used to fight climate change to clean up air, water, and soil pollution. The party has a candidate running in Cariboo-Prince George.

Communist Party This party would nationalize Canada’s natural resources, assuming public control of extraction, production, and distributions. It does not support the Northern Gateway, TransCanada, Keystone, Line 9 and Energy East pipelines and would put a moratorium on shale gas development. It would also shut down Alberta oilsands, and say it would guarantee jobs for impacted workers in other industries and equivalent wages.

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AUGUST 14, 2015

INVESTMENTS

Murphy Oil may consider Montney midstream sale Pat Roche

Daily Oil Bulletin

Murphy Oil Corporation may consider a possible sale of its Montney midstream assets in northeast British Columbia, an executive hinted during a conference call on Thursday. “We’re currently reviewing the value of our midstream assets — in the Canada Montney, the Eagle Ford shale and in the Gulf of Mexico,” Roger Jenkins, president and chief executive officer, said in prepared remarks before taking analysts’ questions on the company’s second quarter results. Asked how Murphy’s Montney acreage currently competes in terms of gas-price break-evens, Jenkins described it as “a tough business,” citing AECO prices in the C$2.40-$2.50 range. “And that’s why this sale of a midstream would add return on capital employed,” he said. The company didn’t offer any details such as how long the midstream review might take or what options were being considered. Murphy’s natural gas production began at Tupper in 2008 and Tupper West in 2011. In the second quarter the company’s Montney gas production averaged 192 mmcf a day. “Our new completion designs continue to deliver strong well performance with EURs [estimated ultimate recoveries] now in the eight [bcf] to 10 bcf range, well ahead of the original Montney sanction [estimates] that called for four bcf per well,” Jenkins told analysts. A slide in his presentation indicated Murphy’s Tupper West new well completions use 100 tonnes of slick water and 50 tonnes of nitrogen/carbon dioxide foam. Re-frac pilot at Tupper “We have a re-frac pilot underway in some of the older wells at Tupper,” the CEO told the call. He said Murphy has an inventory of nine previously drilled wells, five of which are currently being completed to maintain production rates and keep operating expenses low.

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Pipeline News North

Seal heavy oil According to Jenkins’ PowerPoint, a multilateral pilot at Seal North averaged 750 bbls of oil a day over six months on primary production. Development would include more than 30 multilaterals. At Seal Central, a regulatory application was submitted in the first quarter of this year for a horizontal cyclic steam stimulation project. “We recently sanctioned FEED [front-end engineering and design] work for the project,” Jenkins said. A project sanction decision on the 12,500-bbl-a-day project is slated for the first half of next year. First oil is tentatively scheduled for 2019. Alberta tax writedown Murphy Oil Company Ltd., the company’s Canadian subsidiary, reported higher Canadian production in the second quarter, helped by strong Montney production. Murphy reported a net loss of $73.8 million (42 cents per diluted share) in the 2015 second quarter, down from net income of $129.4 million (72 cents per diluted share) in the second quarter a year ago. The company had a second quarter net loss from continuing operations of $89 million (51 cents per diluted share) compared to a profit of $142.7 million (79 cents per diluted share) earned in the second quarter a year ago. Second quarter results from continuing operations included a $23.8 million charge against Alberta’s corporate tax rate, which will rise to 12 per cent from 10 per cent in 2016, said John Eckart, Murphy’s chief financial officer.

Worker camps continue to crop up in the Peace Region despite drilling slowdowns in B.C.'s oil patch. Nomodic Modular Structures has been contracted to build a 68-person work camp for Canbriam Energy, a company drilling and developing natural gas processing facilities in the Upper Montney. Located northwest of Fort St. John, the camp would join the dozens of other installations built to house workers in the oil field. "We are aware of the economic challenges the oil and gas community is facing and believe

Nomodic can deliver world-class remote living and work spaces that align with the constraints being felt throughout the industry," Canbriam's CEO wrote in a release. Two-thirds of Canbriam's $340 to $360 million in 2015 capital spending is going into its Montney holdings, according to a report. The company plans to drill 20 wells in the region in 2015, saying its northeast B.C. wells are "economically robust in low commodity prices." Drilling in the Montney was down around 30 per cent in July compared to 2014, according to the Canadian Association of Oilwell Drilling Contractors.

... while 600-man camp eyed for Halfway River... A 600-person oil and gas worker camp could soon be built on the banks of Halfway River. Proposed by Massachusettsbased Clean Harbors Lodging Services, the camp would be located 41 kilometres from Highway 97 in the Wonowon area. At its peak, the camp would house 624 oil and gas workers. An application to the Peace River Regional District does not make clear whether the camp is being built for a specific company, though Progress Energy is

one of the most active drillers in the area. According to the application, the camp would be "closed," patrolled by 24-hour security, and will not serve alcohol. Operators also plan to have a full-time medic on site. The camp will increase traffic on Upper Halfway Road, but may reduce the number of total trips by shortening the distance workers must travel, the application states. reporter@dcdn.ca

AUGUST 14, 2015

PIPELINE NEWS NORTH •

Encana Saturn plant given green light to proceed Mike Carter

Pipeline News North

A large natural gas processing plant planned for a section of land about 25 kilometres northwest of Dawson Creek has been given the green light to proceed without an environmental assessment. Encana Corp.’s Saturn 15-27 Sweet Gas Plant will be located next to an existing Encana compressor station and adjacent well site, on an 18.43-hectare plot located just off 243 Road. The proposed project will include a natural gas processing facility, natural gas storage and power transmission line. Upgrades to the sites access road may also be required. Kevin Jardine, Executive Director of the B.C. Environmental Assessment Office, signed the release last Wednesday, granting the exemption from the Environmental Assessment Act on the basis that the project will not result in significant adverse environmental, economic, social, heritage or health effects. Jardine is satisfied that the com-

pany has taken into account practical measures of preventing any potential adverse effects, or reducing them to an acceptable level. The letter giving the go-ahead on the project was signed July 29. The plant will use a shallow-cut refrigeration process to remove water and natural gas liquids from the inlet gas. The facility will be fed by existing BC Hydro infrastructure, rather than burning natural gas to produce its own power. Processed water and hydrocarbon condensate separated in the process will be pipelined to Encana’s Farmington Water Resource Hub for further processing. The sales gas will be sent to TransCanada Pipeline’s existing NOVA Gas Transmission Groundbirch pipeline, where it will continue on its way to Pembina Pipeline’s Peace Pipeline in Alberta. dcreporter@dcdn.ca

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Increased Focus Will Be On Canada, Says Arsenal

Arsenal Energy Inc. has upped forecast capital expenditures for 2015 to approximately $27 million, slightly higher than its initial capital budget of $26.8 million. Approximately $17 million will be spent in Canada and $10 million in the United States in 2015. The company said that in the current low priced commodity environment it plans to focus more of its capital budget in Canada at Princess and Provost in Alberta due to the ability to obtain better margins. In May, Arsenal earlier reduced its capital program to $23.5 million from $31.5 million due to changes in project scope as well as lower service costs after increasing it in February to include costs related to the drilling intentions of a joint venture partner. In January, Arsenal’s board had approved a $26.8 million capital program for 2015. In Canada, expenditures are expected to include drilling and completing three gross and net wells at Princess, two gross and net wells at Provost and one gross and net well at Cessford, while in the United States expenditures are being spent to complete production facilities at Lindahl, N.D. Arsenal reported lower cash flow and revenue along with a loss and reduced production for the three and six months ended June 30, 2015. The company recorded a net loss of $3.4 million (19 cents per share basic and diluted) versus a loss of $375,824 (two cents per share basic and diluted) in the 2014 quarter. The figure included a loss on the sale of properties of $1.4 million. —Daily Oil Bulletin

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AUGUST 14, 2015

OILMEN’S

Oilmen’s Couples Golf Tournament

The 6th Annual Oilmen’s Couples Golf Tournament was held on Aug. 8, 2015 at Lakepoint Golf & Country Club. Normally held at the end of May before the annual Oilmen’s Golf Tournament, this year it was moved to August due to bad weather conditions. Twenty-two couples enjoyed great weather, a fun day of golf, followed by dinner and prizes for all participants. This tournament is sponsored by the F.S.J. Petroleum Association and is a great way to give back to its members and their partners.

AUGUST 14, 2015

PIPELINE NEWS NORTH •

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FINANCIALS

$$ second quarter

summaries Crew Energy While Crew Energy Inc.’s second quarter results were affected by asset sales and low commodity prices, the company has taken measures to reduce the impact of low natural gas prices in its Montney area. Cash costs per boe in the quarter were 33 per cent lower than in the same period of 2014, highlighted by a 74 per cent drop in royalties and an 18 per cent drop in operating costs. Crew’s second quarter operating costs were $8.81 per boe, five per cent lower than the first quarter 2015. During the latter part of 2014 and so far in 2015, gas pricing in northeast B.C. and northwest Alberta has been significantly affected by increased supply coupled with multiple, overlapping pipeline service outages and transportation bottlenecks which have hurt realized pricing in the region. However, Crew said it can partially mitigate the impact of such market conditions due to the dual connectivity of the Septimus gas plant, which can simultaneously access both the Spectra and Alliance pipeline systems. In July, Crew completed an innovative oil and gas rights exchange with the B.C. government, adding 53 net sections of new Montney land contiguous to its Groundbirch property in exchange for surrendering 66 net sections of undeveloped land that had been subject to restricted development since 2004

STRAD ENERGY Reporting second-quarter 2015 results that featured a net loss and lower cash flow and revenue than in the same period a year prior, Strad Energy Services Ltd. says that were it not for its first-quarter cost-cutting, its results could have been worse. During the second quarter of 2015, Strad’s loss deepened to $1.89 million from $4.76, cash flow fell to $4.03 million from $12.27 million and revenue dropped to $29.91 million from

$53.69 million in 2014. The company had anticipated activity declines during the first half of 2015 and prepared for it by being proactive in taking steps to manage its cost structure, said CEO Andy Pernal. Strad’s Canadian operations reported lower revenue and adjusted EBITDA during the three months ended June 30, 2015, compared to the same period in 2014. Decreased revenue was a result of lower pricing and utilization of the surface equipment fleet as a result of a 51 per cent decline in the average drilling rig count to 96 rigs during second-quarter 2015 compared to 197 for the same period in 2014. Strad’s Canadian operations were also impacted by an early spring breakup.

CNRL CNRL reported a $405 million net loss and slightly lower production (see tables) in the second quarter. The net loss was attributed mainly to the increase in the Alberta’s corporate income tax rate to 12 per cent from 10 per cent, increasing Canadian Natural’s deferred income tax liability by $579 million. Without that $579 million charge, CNRL’s second quarter earnings would have been $174 million, the company said. It said this charge means lower future cash flows and hence it lowers reinvestment in the business. Including project deferrals and cost reductions, the company has cut its 2015 budget by $3.1 billion.

DEVON Devon Energy Corp. says if cost savings achieved in the second quarter of 2015 continue, spending in Canada next year could be reduced by about US$500 million. Oklahoma City-based Devon reported a 2015 second-quarter loss of $2.79 billion ver-

sus net earnings of $700 million in the same quarter a year prior, and a first-half 2015 loss of $6.38 billion compared to earnings of $1.03 billion in 2014. The company announced core earnings of $320 million, or 78 cents per diluted share, for the second quarter of 2015. Since the beginning of the year, Devon has reduced projected 2015 capital spending by approximately $350 million. In total, Devon’s production averaged 674,000 boe per day during the second quarter of 2015 — a nine per cent increase compared to the second quarter of 2014, with liquids accounting for 60 per cent of the company’s production mix. Given the strong year-to-date production performance, the company is well positioned to deliver on its 2015 oil growth target of 25 to 35 per cent

CANYON SERVICES Executives at Canyon Services Group Inc. reaffirmed their intent to stand firm on pricing during the current downturn, despite competitors determined to work at unprofitable rates. Like other Canadian pressure-pumping contractors, Canyon took it on the nose in the second quarter, as revenue dropped 28 per cent, due to lower industry activity and depressed pricing. In a second-quarter report, management said lower pressure-pumping activity led to swiftly-dropping pricing starting in January 2015, resulting in current pricing that’s well below levels seen in last year’s fourth quarter. Canyon’s net loss in the second quarter widened to $21.86 million or 32 cents per share from $15.26 million or 24 cents per share in last year’s comparable period. Nonetheless, once activity resumed in June after an extended spring breakup, Canyon was able to remain relatively busy with a core group of customers in both its pressure pumping and fluid management divisions.

AUGUST 14, 2015

SECURE ENERGY An extended spring breakup and sliding oil and gas prices muted activity for Secure Energy Services Inc. in the second quarter, trimming revenue by 28 per cent. Of Secure’s three operating divisions — processing, recovery and disposal (PRD); drilling services (DS); and OnSite (OS) — the downturn and weak commodity prices had the most impacted on the DS division, whose work is tied to drilling. In the PRD division, however, where revenues are more focused on production services, the addition of new facilities since 2014 alleviated some of the negative impact on results, the company said. Secure was active in the second quarter, evaluating acquisition opportunities that complement its existing service offerings and will expand its geographic presence to locations

where customers are continuing with active drilling programs, the company added.

CONOCOPHILLIPS Second quarter production was 306,000 boe per day for ConocoPhillips in Canada, an increase of 22,000 boe per day compared with the second quarter of 2014. The increase was primarily driven by strong well performance in Western Canada and the oilsands, as well as ramp-up at Foster Creek Phase F, partially offset by impacts from forest fires near Foster Creek. Bitumen production increased eight per cent compared with the second quarter of 2014. The company reported a second quarter 2015 net loss of US$179 million, compared with second quarter 2014 earnings of $2.1 billion.

Tourmaline anticipates $1.35B in E & P spending for 2016

Elsie Ross

Daily Oil Bulletin

Tourmaline Oil Corp. says it has set a preliminary exploration and production capital budget for 2016 of $1.35 billion. Approximately 80 per cent of the 2016 capital program will be directed towards drilling and completions activity. The company reported second quarter 2015 cash flow from operating activities of $151.03 million before changes in non-cash working capital, down from $231.76 million in the comparable 2014 quarter. Cash flow reflected an average realized natural gas price of $3.17 per mcf and a 31 per cent increase in production over the second quarter of 2014. “Tourmaline had very strong cash flows in the second quarter and we have made great progress on the cost reduction front both yearover-year and quarter-over-quarter and we are proud of our ability to continue to generate earnings in this difficult commodity cost environment,” President and CEO Mike Rose said in the conference call Thursday. Second quarter 2015 pre-tax earnings were $35.6 million, reflecting the underlying profitability of its low cost natural gas business, even in a very difficult commodity price environment, said Tourmaline. Second quarter production averaged 143,634 bbls of oil equivalent per day, up 31 per cent from 109,953 boe per day in the second quarter of 2014. Full-year E&P capital spending has been increased to $1.4 billion, reflecting the full im-

pact of the increased second-half, 18-drillingrig program. However, spending is still $200 million lower than the originally planned $1.6 billion 2015 budget. Tourmaline expects to drill 120 wells during the second half of the year. Tourmaline will operate 18 drilling rigs in the second half of 2015 with 11 rigs active in the Alberta Deep Basin, three rigs in the Montney complex and four rigs on the Peace River High. The company said it is drilling Current production in the B.C Montney complex ranges between 42,000 and 44,000 boe per day, with the existing facility network essentially at full capacity. New facility projects at Doe and Sundown will add a total of 100 mmcf per day plus liquids of new production capacity during 2016. It is expected these facilities will also be full upon start-up. An additional six lower Montney turbidite horizontals were drilled and completed in the second quarter with stable condensate rates of 75–100 bbls per mmcf, consistent with results from the initial 10 turbidite wells in 2013/2014. Tourmaline is currently operating four drilling rigs in the Peace River High Charlie Lake complex, and expects to drill, complete and tie in an additional 40 wells during the second half. With its second half drilling program, Tourmaline is testing several new large-scope opportunities in addition to the Charlie Lake focus, all of which, if successful, could access its existing infrastructure.

PIPELINE NEWS NORTH •

Excluding special items, second quarter 2015 adjusted earnings were $81 million, compared with second quarter 2014 adjusted earnings of $2 billion. Special items for the current quarter primarily related to a deferred tax charge from a change in Canada’s tax law and non-cash impairments.

CENOVUS Cenovus Energy Inc. has sliced its quarterly dividend by 40 per cent and will cut another 300 to 400 more jobs as it continues its cost reduction efforts in light of deflated crude prices. In February, Cenovus announced initial plans to reduce its workforce by approximately 800 positions to align with capital budget reductions for the year. The company has since identified 300 to 400 positions at its Calgary offices that are expected to be eliminated before the end of 2015. Cenovus reported second quarter earnings of $126 million, down from $615 million during the comparable period in 2014. The decline was in part related to higher unrealized risk management losses of $151 million, compared with $11 million in losses a year prior, and lower non-operating unrealized foreign exchange gains of $99 million, compared with $177 million in gains in the previous year’s period. After investing $357 million in the second quarter, Cenovus had free cash flow of $120 million, down from $503 million in the same period a year earlier.

CALFRAC Lower demand for fracturing on both sides of the Canada-United States border drove falling revenue in the second quarter at Calfrac Well Services Ltd. Revenue from Canadian operations in the second quarter fell 30 per cent to $66.89 million from $96.21 million in last year’s period, which management attributed to lower fracturing activity and pricing. Revenue per fracturing job fell nine per cent from the 2014 period, also due to “significant” pricing cuts, offset partly by the impact of greater service intensity. –Compiled from the Daily Oil Bulletin

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AUGUST 14, 2015

PIPELINES

Support up for pipelines, poll shows FILE PHOTO

Patrick Blennerhassett

Business in Vancouver

Support for two of Western Canada’s most controversial pipeline projects has risen over the past two and a half years, according to a new poll by Insights West. In January of 2013, 61 per cent of respondents said they opposed the Enbridge Northern Gateway Pipelines project, which was given federal approval subject to 209 conditions recommended by the National Energy Board last year. The twin pipeline would run from central Alberta to Kitimat, totalling more than 1,100 kilometres. By July of this year, the percentage

of respondents who said they oppose the pipeline dropped to 52 per cent. Support for the Enbridge pipeline has also risen over the same period of time, as 35 per cent of respondents said they supported the project in January of 2013, to 41 per cent in July of this year. Concerning the proposed expansion of Kinder Morgan’s Trans Mountain Pipeline, which currently runs from Edmonton to Burnaby, support has risen from 38 per cent in January of 2013 to 42 per cent in July of this year. Opposition also dropped amongst respondents, from 57 per cent in January of 2013 to 46 per cent in

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that was discussed at length during the last B.C. election, it’s been almost two and a half years since that election and we really haven’t heard a lot about where the government wants to go with this.” Canseco added the issue is also split when it comes to sex and age. “The demographic analysis tells the story of how the province currently feels about these two pipeline projects," he said. "Women and the youngest residents are decidedly more forceful in their opposition, while men and those over the age of 55 tend to be more in favour, although their support is mostly moderate.”

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July of this year. Mario Canseco, vice-president of Public Affairs for Insights West said they noticed the change in opinion lined up with the increased attention towards another project. “The fact that government has really shifted all of its energy into LNG has left these two projects without a champion in the government who’s actively discussing and actively talking about what they want to see happen," Canseco said. "There is something going on as far as the government isn’t really discussing this as prominently as they did. And, for something

While down from last year, those rates are well above Western Canada as a whole. Utilization rates peaked at 48.4 per cent in January, and only 24 per cent of rigs in Western Canada were drilling this month. Progress Energy, the upstream subsidiary of Petronas, has been the most active driller in northeast B.C., as it gears up to supply the Malaysian company’s proposed Pacific NorthWest LNG terminal on B.C.’s west coast. The potential for new Asian markets has shored up drilling in B.C. to some extent, the CAODC’s John Bayko wrote in an email to the Alaska Highway News. “The development of LNG facilities in BC are longer term initiatives and therefore less subject to the current price volatility of oil which is

decreasing utilization levels in [Western Canada],” he said. “In the event, however, that any of the proposed LNG projects move forward with actual physical development, the impact on drilling in B.C. would likely be a positive one.” The CAODC released a bleak forecast in June, noting that total operating days have fallen to 50 per cent of 2014 levels, threatening nearly 25,000 jobs. Since September, the price of a barrel of industry benchmark Brent crude fell from over $105 to $53.52. Natural gas prices are typically indexed to oil prices. The CAODC expects to release its 2016 drilling forecast in November. —with files from Daily Oil Bulletin reporter@dcdn.ca

AUGUST 14, 2015

PIPELINE NEWS NORTH •

LNG

FILE PHOTO

Wood�ibre LNG agrees to all Squamish Nation conditions Squamish Chief

The environmental review is back on for Woodfibre LNG after the company agreed to all Squamish Nation conditions. Woodfibre LNG announced Aug. 11 it had requested an end to the pause in the Environmental Assessment Office (EAO) review process its representatives were granted June 30 following the Squamish Nation’s release of its 25 conditions. The resumption of the EA process is effective August 10, on day 168 of the 180-day review period, a news release from Woodfibre LNG stated. “Woodfibre LNG Limited has formally notified Squamish Nation that it has accepted all of the conditions of its environmental review and is committed to reaching a formal agreement,” said Byng Giraud, vice-president of corporate affairs for Woodfibre LNG. Thirteen of the 25 Squamish Nation conditions applied to Woodfibre LNG, according to a company news release. The conditions include, among others, providing insurance coverage for loss and injury costs of Squamish Nation members affected “by an explosion caused by an accident or malfunction of project,” conducting fur-

ther studies on the proposed sea water cooling and funding a Squamish Nation marine use plan. Another condition was to enter into an economic agreement with the Squamish Nation that reflects Squamish Nation’s aboriginal rights and title. “We entered into this process knowing that if you enter into the process, you have to live with the outcome of the process, so there are additional costs and additional responsibilities that are required to go along with the conditions, but again we entered into this process voluntarily, eyes wide open,” said Giraud. He said there are still some details around conditions that are being worked out, but he declined to elaborate further. The proposed liquefied natural gas facility is located on the traditional territory of Squamish Nation on Howe Sound near Squamish. The Nation is running its own independent environmental review, and chiefs and council is set to hold a vote on the project in the fall. The FortisBC EAO process has not resumed. “Our application is still paused. Right now we are still doing all the work that we need to do to address the conditions that the Nation laid out,” said Trevor Boudreau, spokesman for FortisBC. “The big two being construction underneath

the estuary to make sure that we can minimize or eliminate any surface disturbances in the [Wildlife Management Area] and then the location for the Squamish compressor station, so we are still working through that.” Boudreau said he hoped the company would have an update for the public regarding its EA process in September. After the EAO makes its recommendations, the Woodfibre LNG and FortisBC proposals will be sent to provincial and federal ministers for a final decision.

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AUGUST 14, 2015

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Guts. Glory. Ram.

Producers completing greater percentage of gas wells

Gas well completions in Western Canada — for both development and exploratory wells — declined to 829 to the end of July from 1,045 in the comparable period last year, but as a percentage of the total (oil, gas or dry wells) it represents 30.4 per cent versus 20.4 per cent a year ago. Operators working in Alberta completed 651 gas wells to the end of July (excluding experimental wells), down from last year’s 691 gas well completions. In B.C., producers have completed 178 gas wells compared to 354 in the January-July period a year ago. There were 823 oil well completions in Alberta to the end of July (excluding experimental wells) compared to 2,307 a year ago. In Saskatchewan, there were 848 oil well completions in the January-July period, off from 1,481 in the comparable 2014 period. Including service wells, there were a total of 3,054 well completions booked across the country in the first seven months of 2015. The number of wells completed (assigned a final status of oil, gas, dry or service) is down from 5,615 last year. The tally for total metres completed declined to 7.48 million metres in January-July 2015 compared to 12.56 million metres a year ago. Overall, industry reported 2,465 development completions and 258 exploratory well completions in Western Canada (excluding experimental wells) in the first seven months of 2015, compared to 4,696 and 417, respectively, for the year-prior period. — Daily Oil Bulletin

AUGUST 14, 2015

PIPELINE NEWS NORTH •

R E A L E S TAT E F O R S A L E

the station fort st. john

Fort St. John’s Newest Master Planned Community

DUPLEX LOTS SINGLE FAMILY LOTS (WITH LEGAL BASEMENT SUITE)

20400m2

N 134 133 132 131 130 129 128 127 126 125 124 123 122 121 120 119 118 117 116 115 114 113 112

561m2

550m2

561m2

142

16146m2 173799ft2

79A STREET

551m2

550m2

100 101 102 103

550m2

551m2

80 STREET 61

551m2

550m2

104 105

551m2

550m2

106 107

550m2

108 109 110

550m2

111

550m2

141

81ST STREET

85TH STREET

551m2

82ND STREET

OVER 85% SOLD! 143

PHASE 1 BOUNDARY

11196m 120513ft2 2

550m2

12436m2 133857ft2

140

12256m2 131925ft2

Join Eli Chi and Mitch Collins for an informative evening on Fort St. John’s newest Residential, Commercial and Retail Development.

550m2

551m2

550m2

81 STREET 27

551m2

550m2

139

550m2

11172m2 120250ft2

550m2

551m2

144

726m2

550m2

135

4529m2

551m2

136

4785m2 51510ft2

137

4793m2 51587ft2

138

12573m2 13533ft2

81A STREET 1

704m2

652m2

583m2

552m2

551m2

628m2

2490m2

564m2

551m2

628m

Find out how you can be involved.

BUILDING LOTS AVAILABLE IN PHASE 1 STARTING AT $159,000

Northern Grand Hotel

9830 100th Avenue, Fort St John, BC

Tuesday, August 25 5pm to 8pm

Come and meet the developers and get introduced to the new exciting plans for the remaining lands at the Station.

Mitch Collins

Your Personal Investment Realtor P 250-785-8051 / M 250-262-9338 mitchcollins.com

To keep updated on the project, please register at

thestationfsj.com R0011090059

• PIPELINE NEWS NORTH

AUGUST 14, 2015

IN BRIEF $115M in royalty credits for northeast infrastructure

Aboriginal business conference coming to FSJ

Riddell to be inducted into Petroleum Hall Of Fame

British Columbia has approved $115 million in royalty deductions that will create jobs and support the construction of 14 infrastructure projects in northeastern B.C. For the 14th time since its inception, royalty deductions will be provided under B.C.’s Infrastructure Royalty Credit Program (IRCP), designed to facilitate the construction of new resource roads and pipelines. The 14 projects will be built across a wide region of northeastern B.C., from areas north of Fort Nelson, to the northern parts of Fort St. John and the southern landscape of Dawson Creek. The companies receiving credits are: Black Swan Energy Ltd., Chinook Energy Inc., Chevron Canada Corporation, Canadian Natural Resources Limited, Cutbank Ridge Partnership, Endurance Energy Ltd., Kanata Energy Group, Progress Energy Canada Ltd., Storm Resources Ltd., Tourmaline Oil Corp., UGR Blair Creek Ltd. and Woodside Petroleum Limited.

A conference designed to connect Aboriginal entrepreneurs and communities with private sector opportunities is hitting Fort St. John Sept. 21 to 23 at the curling club. Aboriginal Business Match (ABM) offers a chance for Aboriginal employment and training coordinators to connect with companies offering employment opportunities and business partnerships. Delegates who pre-register can create profiles that will be fully searchable on the ABM website, and are used to set up one-on-one prescheduled appointments for when the event comes to town. ABM claims their model “levels the playing field to allow business connections to be made,” according to a release. Preference is given to companies that provide business opportunities extending beyond a customer/supplier relationship, including training, employment and partnerships. For more info, call 1-604-483-3532 or email info@ravenevents.ca. -PNN

Clayton Howard Riddell has been involved in the oil and gas industry for more than 55 years and has created a business empire that currently incorporates three public companies with a combined value of $6 billion. A graduate of the University of Manitoba with a B.Sc. in geology, Riddell began his career as an exploration geologist with The Standard Oil Company of California in 1959 but left after 10 years to start his own business, C.H. Riddell Geological Consultants Ltd. In 1971, he incorporated Paramount Oil & Gas Ltd. as a private oil and gas company and took that company’s assets public in 1978, as Paramount Resources Ltd. Riddell’s early exploration success was centred around shallow gas in northeastern Alberta, which was born of Clay’s recognition of the hydrocarbon potential of the Devonian Formation. He mapped the subcrop edges of at least five different reservoir members within the Grosmont, as well as the Niskuequivalent subcrop edge and the Leduc Formation. —Daily Oil Bulletin

—Daily Oil Bulletin

ns ociatio SEPTEMBER 2014 & um ass AUGUST petrole n o ls e Fort N ce and a e P th s: Sou Profile

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• Distributed to the community in general through these ﬁne publications, Alaska Highway News, Dawson Creek Daily and Fort Nelson News. • Distribution by mail and direct drop-off to Oil & Gas companies,and related businesses and organizations, in the following communities: BRITISH COLUMBIA – Arras, Baldonnel, Cecil Lake, Charlie Lake, CHETWYND, Clayhurst, DAWSON CREEK, Farmington, FORT NELSON, FORT ST. JOHN, Goodlow, Groundbirch, HUDSON HOPE, Moberley Lake, Pink Mountain, Pouce Coupe, Progress, Rolla, Rose Prairie, Sunset Prairie, Taylor, Tomslake, TUMBLER RIDGE, and Wonowon. ALBERTA – Baytree, Bear Canyon, BEAVERLODGE, Berwyn, Bezanson, Bonanza, CLAIRMONT, Eaglesham, FAIRVIEW, Falher, Girouxville, GRANDE PRAIRIE, Grimshaw, Grovedale, HIGH PRAIRIE, Hines Creek, Hythe, LaGlace, MANNING, McLennan, PEACE RIVER, Rycroft, SEXSMITH, Silver Valley, Spirit River, VALLEYVIEW, Wembley, and Worsley, Zama City.

AUGUST 14, 2015

PIPELINE NEWS NORTH •

IN BRIEF

AltaGas plans new liquefied propane plant in B.C. Nelson Bennett

Business In Vancouver

AltaGas Ltd. (TSX:ALA), the Alberta company that has already invested $2 billion in B.C. in recent years, is planning to spend another $1 billion over the next two years. AltaGas already is advancing its plans to build the Douglas Channel LNG plant in Kitimat. The company announced July 31 that it is now planning to also build a liquefied propane plant as well. The company has been capitalizing on its assets in the Montney in Northeastern B.C., which is rich in natural gas liquids. These so-called “wet” gas products include liquid natural gas (used as condensate in the oil sands), butane and propane — all of which are much more valuable than dry gas. In a news release from July 30, AltaGas revealed that, in addition to the $500 million LNG plant it plans to build in Kitimat, it is

also planning to build a new propane liquefaction plant on the B.C. coast, but has not yet identified the proposed site. In recent years, AltaGa has been investing in its Montney infrastructure, building gas processing plants and related infrastructure. That includes the $350 million Townsend gas processing plant. The company is also developing a gas liquids hub in Fort St. John. The company said the proposed propane plant would have an initial shipping capacity of 25,000 barrels per day of liquefied propane. In addition to its gas business, AltaGas is also in the renewable energy business. It built B.C.’s largest run of river power station — the $725-million Forrest Kerr project, as well as two smaller ROR projects.

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• PIPELINE NEWS NORTH

AUGUST 14, 2015

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AUGUST 14, 2015

LAST WORDS

PIPELINE NEWS NORTH •

Oil to have minor effect on B.C. employment Bryan Yu

Business In Vancouver

The sharp decline in oil prices in recent quarters and cuts to Alberta oilsands capital investment have led to questions about their potential effect on the B.C. labour market. In particular, what exposure does B.C. have due to B.C. residents working in Alberta, and which regions are more at risk? Our view is that the effect will be small on B.C.’s overall economy and labour market, and geographically concentrated. A recent study from Statistics Canada on Canadian interprovincial employment supports our expectation that any associated job losses will have only minor effects on B.C.’s growth. However, additional data obtained by Central 1 Credit Union points to higher potential risks in the Thompson Okanagan and Kootenay regions. For the most part, the data supports the anecdotal information we have seen on flows of interprovincial employees (IPE). There were approximately 64,180 IPEs residing in B.C. in 2011, with the majority earning income from Alberta sources. IPEs are individuals who received at least some employment income from another province in a given tax year. Income-by-source data suggests 60 per cent of total interprovincial employment income was earned from Alberta employers during the year, with a further 21 per cent from Ontario. Given this high share, it’s not surprising that labour market conditions in Alberta and the number of interprovincial workers from B.C. are positively correlated. Stronger labour market conditions in Alberta increase employment flows from B.C. owing to more job opportunities and higher wages – even if not for permanent work. The interprovincial workforce grew rapidly from 2004 through 2008, before receding temporarily following the recession. It’s likely that B.C.’s IPE resident workforce continued to rise since 2011, given declining unemployment rates and stronger job growth in Al-

berta. Unemployment in Alberta fell to 4.7 per cent last year compared to 6.1 per cent in B.C., while employment growth reached 2.2 per cent compared to only 0.6 per cent in B.C. From these trends, it’s safe to say that expected cuts to Alberta oil and gas capital expenditures will weigh on B.C. interprovincial employment. The overall effect on B.C.’s economy of IPE losses is anticipated to be small given that interprovincial workers make up a relatively small share of total B.C. paid employment. Based on 2011 data, the ratio in B.C. was 3.6 per cent. In comparison, the effect on Saskatchewan and Atlantic Canada is expected to be deeper. The proportion of interprovincial workers among total employed individuals in Saskatchewan was close to 7 per cent. Meanwhile, 10 per cent of Newfoundland and Labrador’s paid employees worked outside the province. Within B.C., our estimate of IPEto-total employment for 2009-11 was highest in the Kootenay (6.2 per cent) and Northeast (7.0 per cent) development regions, despite representing a small share of total interprovincial employees. IPEs also represent a high share of the regional employment base in the Thompson Okanagan at 5.2 per cent, while the ratio was lowest in the Lower Mainland-Southwest at 1.9 per cent. These figures aren’t surprising and align well with anecdotal information from local discussions and media reports, and reflect economic and demographic factors. High ratios in northeast B.C. reflect the area’s proximity to similar energy-driven markets in northwestern Alberta. Labour is able to shift between markets depending on where opportunities and wage growth are stronger. The effect of any losses due to cuts in Alberta will be limited by recent cuts to interest rates and related declines in the Canadian dollar, which will more than offset these IPE-related effects through increased local opportunities. Bryan Yu is senior economist at Central 1 Credit Union.

r0011090157

• PIPELINE NEWS NORTH

AUGUST 14, 2015

Renewables, fossil fuels will share energy landscape Jock Finlayson

Business In Vancouver

FILE PHOTO

R003184226

Is the world in the midst of an accelerating migration away from fossil fuels toward much greater reliance on carbon-free energy? If one takes seriously the speeches of many politicians or the content found on the websites of environmental advocacy organizations, the temptation is to answer “yes.” The reality, however, is more complex. Important shifts in energy production and use are underway, but the magnitude and timing of any overall global “energy transition” are apt to be less dramatic than many believe. Growing energy demand, the vast scale of the world’s existing energy system, and the tens of trillions of dollars of embedded capital that underpin it all stand in the way of rapid change. That said, there is evidence of an incremental move away from fossil fuels as a primary energy source, in favour of low/no-carbon forms of energy. However, because energy demand will be increasing and natural gas use is expected to double by 2040, this does not necessarily equate to an absolute reduction in the quantity of fossil fuels in the global energy system in the short to medium term. Supply and demand forecasts The latest projections from the International Energy Agency (IEA) and the United States Energy Information Administration paint a similar picture of the energy landscape to 2040. • Global energy demand continues to increase, despite the diminishing “energy-intensity” of each dollar of economic output in the advanced economies. In the IEA’s baseline forecast, total energy consumption climbs by 37% to 2040. • On the supply side, by the late 2030s the world’s primary energy system is expected to consist of four roughly equal-sized components: oil, natural gas, coal and low/nocarbon sources. Renewables occupy a progressively larger place in the mix. But the IEA estimates that in 2035 fossil fuels still satisfy three-quarters of the world’s energy needs. • Energy demand ﬂatlines or falls in many advanced economies, while consumption marches steadily higher in the emerging economies.

Effect of technology Technological innovation has always influenced energy markets, and it has proven to be especially disruptive over the past few years. Three important developments are the shale oil and gas revolution, technical advances in distributed power generation and falling costs for solar energy. These trends are reshaping the competitive landscape for certain forms of energy. An often overlooked point is that if technological innovations cause the prices for oil and natural gas to remain low, this should stimulate demand, offsetting some of the efforts being directed at reducing carbon-based energy use to address concerns over climate change. The prospect of lower-for-longer fossil fuel prices also complicates the economics surrounding other forms of energy, such as nuclear, wind and biomass. Slumping prices for oil and thermal coal already seem to be fostering a rise in the use of these fuels in parts of Europe and in some emerging economies. In the electricity sector, technological innovations have led to plunging prices for solar power and promising advances in distributed generation, which in turn are supporting the speedy adoption of photovoltaic installations in a number of jurisdictions. Technology offers the promise of a smaller carbon footprint. Government policies to put a “price” on carbon emissions, improve energy efficiency and foster fuel-switching can also help. But if the global-level energy supply/ demand projections from the IEA and the U.S. government turn out to be even approximately accurate, it is problematic to speak of a rapid “energy transition” – certainly if the term is taken to imply the near-replacement of the existing world energy system with a different system, within the span of two or three decades. Instead, it makes more sense to think of a future in which more fuel-switching occurs and a rising share of global energy demand growth is met through renewables and other lower-carbon sources. Jock Finlayson is executive vicepresident and chief policy officer of the Business Council of British Columbia.

AUGUST 14, 2015

PIPELINE NEWS NORTH •

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CAREERS R0011079139

We are currently recruiting for

Gas Safety Officers in Northern BC, including Fort St John and/or Dawson Creek

Great West Equipment, a privately owned British Columbia based company is growing. Due to this, we are looking to fill the following position: • HEAVY DUTY FIELD TECHNICIAN We offer competitive wages and benefits packages. Experience an asset Please Submit Resume by means of: Fax 250-785-4237 or E-Mail: Greg Hansen, Branch Manager ghansen@gwequipment.com PHONE: 250-785-4223 We thank you in advance for your interest, only those selected for interviews will be contacted.

Visit our Careers page for all of our openings: www.safetyauthority.ca/careers/opportunities Safe technical systems. Everywhere.

LaPrairie Works Oilfield Services Inc. Dawson Creek, BC LaPrairie Works Oilfield Services is a diversified and growing full service contractor. Our core business includes on and off highway hauling, oilfield services, mine contracting and site services.

WE HAVE IMMEDIATE POSITIONS AVAILABLE FOR: Experienced Heavy Duty Truck Mechanics • Journeyman or Red Seal Heavy Duty Mechanic Certification • Demonstrated initiative with sound computer skills • Flexibility to accommodate after hours call outs when necessary • Valid driver’s licence and clean drivers abstract

Dispatchers

• Must be able to work shift rotations which will

include days/nights – 12.5 hours per day

experience will be considered an asset

Class 1 Truck Drivers

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• Daily directing and supervision of drivers/truck to specified locations • Monitor trucks through Shaw Tracking computerized systems • Must have strong computer and organizational skills • Previous dispatching/oilfield/supervisory

Administrative Assistant/Accounts Payable Cabre Oilfield Inc. is currently looking for an experienced office person, full-time maternity leave position. Responsibilities include reception, general clerical duties and clerical support for controller and management, Accounts Payable, updating databases and filing. Prior experience with Sage 50, proficiency with MS Office, and a Valid Class 5 Driver’s License is an asset. The successful candidate will have excellent verbal and written skills, strong organizational skills, be able to multi-task with exceptional attention to detail.

• Valid Class 1 License and current abstract in good standing • Tri-Tri (Air Cans), B-Train, Super B experience an asset • Flexibility to accommodate extended work hours and after hour work callouts • Proficiency and accuracy filling out all required paperwork • Must pass pre-employment Alcohol and Drug testing • First Aid and H2S

LaPrairie Works Oilfield Services offers a highly competitive remuneration package plus a range of benefits and genuine opportunities for advancement. Human Resources Department Email: careers@laprairegroup.com Fax: 250-784-0524 You may also drop a resume off in person: 2149 – Imperial Access Road Dawson Creek, BC

Employment Opportunity - Fort St. John, BC North Peace Savings & Credit Union (NPSCU) is a full-service financial organization offering retail and business banking, investment and insurance products. Located in Northeast British Columbia, NPSCU has proudly served the north for over 65 years. With 12,000 members amongst its four branches, NPSCU remains committed to the social and economic well-being within the communities it serves. NPSCU is the recipient of the National Credit Union Innovation Award, Canada and runner up for the Innovation Award through the Credit Union Executive Society. Manager, Service Experience The Manager, Service Experience is responsible for providing leadership, direction and coaching to retail service leaders (Team Leads) focused on the day to day transactional member service and member experience, both in branch and through virtual channels. The goal of the role is to provide customized solutions and enhance our ability to provide superior member experiences through omni-channels including, but not limited to, in branch service, Face 2 Face Video Banking (Personal Teller Machines), online and mobile technologies. Regional Manager, Sales and Service The Regional Manager, Sales and Service leads and manages assigned sales and service employees located across service centers including Financial Consultants, who are responsible for relationship building and the sales of a full range of personal deposit and lending products and services Through managing, coaching and inspiring employees, the Regional Manager meets team objectives by engaging in activities to achieve superior member experiences, optimal business retention, growth and productivity. Are you ready to take your career to the next level as a leader who is passionate about building lasting relationship, leadership and innovative solutions? You are creative, energetic, and have proven abilities business development and strong financial acumen. To apply, please provide a cover letter and résumé in confidence to:

This is a full time position, Monday to Friday, 8am to 5pm. Please apply with references and wage expectation to Fax: (250)785-8300, or Email: theresa@cabre.ca Only qualified candidates selected for an interview will be contacted. R0011089727

Employment Opportunity Mortgage Specialist Location - Fort St. John Are you a results oriented individual who thrives on seeking out opportunities, and providing innovative financing solutions, to build and strengthen long term client relationship? North Peace Savings is recruiting for a dynamic lending services professional to join our team of retail banking professionals. The Mortgage Specialist is a residential lending expert with proven sales and service experience within the financial industry generating their own leads for the sale of mortgages and related mortgage life and disability insurance. You will be responsible to build and maintain a solid referral network from your community, Realtors, Brokers, Builders, Lawyers and Financial Planners. You will be a highly motivated, dynamic individual that is results orientated with expert follow up skills and the ability to work through various unique applications. If you are a proven business developer with excellent sales, service and marketing skills, have an expert knowledge of mortgage underwriting including proven expertise in construction mortgage financing, excel in relationship building and negotiations and have the ability to work independently with confidence, we are interested in hearing from you. Please provide a cover letter and résumé in confidence to: Olivia Young, Human Resources Specialist North Peace Savings and Credit Union 10344-100th St Fort St. John, BC, V1J 3Z1 Fax: 250-787-9191 or E-mail: careers@npscu.ca For a complete role description, visit: www.npscu.ca

Olivia Young, Human Resources Specialist North Peace Savings and Credit Union 10344-100th St Fort St. John, BC, V1J 3Z1 Fax: 250-787-9191 or E-mail: careers@npscu.ca For a complete role description, visit: www.npscu.ca North Peace Savings thanks all applicants for their interest; however, only those selected for an interview will be contacted.

R0011088438

It’s your life. Build it here.

North Peace Savings thanks all applicants for their interest; however, only those selected for an interview will be contacted.

R0011086928

It’s your life. Build it here.

• PIPELINE NEWS NORTH

AUGUST 14, 2015 R0011085963

Amazing 5 acre property that has it all

• 2 homes, 5 acres, zoned for B & B • Each home feature attached heated garages • RV pad, 30 x 50 shop, wash bay area • Manmade pond, party shed and fire pit • For more info www.century21.ca/Property/101074379

$995,000

Beautiful 116 acres bordering Hwy 97

• 4 bdrm home, 2 newly renovated baths • 116 acre property set up for hobby farm with riding arena • Several outbuildings including double heated garage, power & wood shed • Barn in place, plus 36 x 36 steel pilings in place for new barn • For more info www.century21.ca/Property/101072762

$549,000

Living off the grid

Great Spot to watch wildlife

• 640 Acres surrounded by Crown Land, perfect for hunters & Outdoorsman • Ideal recreational retreat for companies, group investment or your own home • Powered by solar panels, windmills and propane • 3 bdrm + loft log home, with three covered decks. • For more info www.century21.ca/Property/101041529

• Fully updated 3 bdrm, 2 bth, 1800 sq ft home, with large tiered deck & garage • 54 acres, bordering crown land offering ample privacy, 15 mins to town • Road access from the front and back side of the property • Potential to subdivide in future • For more info www.century21.ca/Property/101074812

Build your Mansion here

$565,000

$629,900

Exceptional 11 acre property

Country paradise on 1/4 section

Perfect Recreational Property

• 4 bedroom, 3 bath home, mins to town • 28 x 40 heated shop, plus attached 3 car garage • Manmade lake stocked with fish, with sundeck and swim platform • Property borders creek & is set up for horses with large pasture, dugout and fencing • For more info www.century21.ca/Property/101077022

• 3000 sq ft home on 159 acres with views of Peace Valley • Custom landscaping including water paths, walking bridge, perennials and arbours • Fully fenced and x-fenced and feature 6 stall barn, and set up for cattle • Heated shop (200V), 60 x 32 storage shelter, and rustic log guest cottage • For more info www.century21.ca/Property/101057686

• 158 acres of rural land in Cecil Lake area • Perfect spot to build your dream getaway/recreation home • Mostly cleared with fields • Adjoining 39.9 acre property also for sale offered at $69,900 • For more info www.century21.ca/Property/101064955

$829,900

$169,000

Great views in Sunset Ridge

Empty nesters or starting out

New Home with Lowest Price around

Amazing New Duplex

• Charming 2 bdrm, 1 bath home in Sunset Ridge • Full unfinished basement, south facing backyard • Room to build detached garage • Close to manmade lake, paths and future developments • For more info www.century21.ca/Property/101023500

• 1350 sq ft 3 bdrm, 2 bth home • High end finishes, including hardwood floors, multi tiered entrance, and covered deck • Heated garage, concrete driveway and stainless steel appliances incl • Builder wants SOLD make your offer • For more info www.century21.ca/Property/101064883

• 1600 sq ft 1/2 duplex with 3 bdrms, 2.5 baths • Open concept main floor, with gas fire place • Fully fenced south facing yard, and landscaped • Heated garage, concrete driveway & appliance package • For more info www.century21.ca/Property/101023567

Dawson Creek Shop

Custom Home in Sunset Ridge

Family home in great neighbourhood

• 1815 sq ft steel frame shop in Airport District • Reception area, office space, and a 3 piece washroom • 2 bay shop area suitable for aircraft and 1400 sq ft landing pad • Zoned aviation and priced to sell • For more info www.century21.ca/Property/101026189

• Brand new 3 bdrm, 2 bth home with full unfinished basement • Master retreat with spa like ensuite • Transcending west facing deck, with access from living and master rooms • Custom finishes including neo-classical ceilings, gas f/p and feature rock wall • For more info www.century21.ca/Property/101078910

$1,075,000

• 3 bdrm, 2 bath 1480 sq ft open concept home • Vaulted ceilings, gas f/p, unique fixtures and finishes • Full unfinished basement with room for 2 bdrm + bath builder can finish • Boarders walking path, and west facing • For more info www.century21.ca/Property/101039571

$599,000

Starter home or rental

• 3 bdrm, 1 bth home, 984 sq ft • Walking distance to town core and amenities • Fenced yard with lane access • Perfect revenue, starter or investment home • For more info www.century21.ca/Property/101075599

$439,000

$259,000

$289,000

Two Industrial Zoned lots

Downtown commercial lot

• 2 vancant M1 zoned lots, light industrial • Perfect for Auto body, Oil and Gas sales, storage & more • For more info www.century21.ca/Property/100973389

$79,000 each

• Great central location, close to downtown core • C2 zoned, 100 x 122, allows buiness or mixed use/live work • Level lot with lane access • Building plans available • For more info www.century21.ca/Property/100889983

$350,000

$559,000

• 1/4 section of land, only 5 minutes to town • 60 acres of field & great views of the valley • New road access to property and many building sites • Lease revenue • For more info www.century21.ca/Property/101039068

$749,000

$409,900

• Fully updated 4 bdrm, 2 bath home • Finished basement, with rec room • Large, fenced yard, with entertainment deck • Close to schools, parks and on bus route • For more info www.century21.ca/Property/101074380

$599,000

$419,900

5 Acres in Charlie Lake

Commercial Space for Lease

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

• Brand new building with approx. 4700 sq ft available for lease • Impeccable exposure along 100 Ave, main road through town • Ample parking for business and customer needs • Dual access from front and back of bulding • For more info www.century21.ca/Property/101064369

$205,000

$20/ sq ft