Special Report: Regulators ponder future of natural gas /pg. 6 MAY / JUNE 2017
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The BC Liberals will continue to represent Northeast B.C. for the next four years, but whether the party will form government remains an open question following the May 9 election; 2017 drilling projections jump 74% in Alberta, 60% in B.C.; Trudeau moves to ban tankers on the north coast, rankling some First Nations leaders; and Enbridge launches open season on a proposed $1-billion expansion of its B.C. Mainline
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FORT ST. JOHN
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MAY 19, 2017
PIPELINE NEWS NORTH •
OUTLOOK
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MATT PREPROST PHOTO
Dan Davies delivers a speech at a campaign party in Fort St. John May 9 after being declared the MLA-elect for Peace River North.
Peace River sends BC Liberals to legislature Voters in Peace River have spoken, sending two BC Liberals to represent the region in Victoria over the next four years. Both Dan Davies and Mike Bernier handily won the ridings of Peace River North and South on May 9, but their party sits on a precarious edge pending the outcome of a final ballot count expected May 24. Based on the initial vote count, which includes advance and general ballots, the BC Liberals lead with 43 seats, the NDP hold 41 and the Greens have three. The question of which party will form the next government hangs on about 176,000 absentee ballots that won’t be counted until May 22 and recounts in the Courtenay-Comox (NDP) and Vancouver-False Creek (Liberal) ridings. Christy Clark has confirmed she will remain premier pending the final count of ballots, which will determine the party forms government and whether it will have majority or minority power in the legislature. Both Davies and Bernier were in Vancouver on May 16 for the first meeting of the new BC Liberal caucus. “It’s regrouping the BC Liberal caucus … to bring everyone together,” said Davies, who won the riding with 8,539 votes. “This is historical, really, with what we’re facing.” In Peace River North, independent candidate Bob Fedderly finished second in the riding with 2,489 votes. NDP candidate Rob Dempsey finished with 837 votes, independent Rob Fraser finished with 785, and independent Jeff Richert finished with 231. In Peace River South, Bernier won 6,180 votes, while NDP candidate Stephanie Goudie won 1,991. Davies said he’ll be a vocal MLA regardless of the party that forms government, saying he intends to present any government with solutions, not problems. “My number one role is to make sure that I am representing the entire region,” he said. CONTINUED ON PAGE 4
TRENT ERNST PHOTO
Mike Bernier watches the results roll in for Peace River South with supporters on May 9.
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PNN MISSION STATEMENT Our mission at Pipeline News North is to provide the most current, interesting, and relevant news and information about the oil and gas industry in Northeast B.C. and Northwest Alberta. Have an interesting story to share or a news lead? Email us at editor@ahnfsj.ca.
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“Voters want us to work together, they want us to work across party lines, and they want us to find a way to get along so that we can all work for the province that all of us love so very, very much,” Christy Clark told supporters.
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Greens could derail resource agenda CONTINUED FROM PAGE 3
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Most of the NDP seats are held in the urban areas of the province, while the Liberals have maintained their stronghold on the rural and Interior regions. This is a sign of the urban-rural divide facing B.C. politics, Bernier says. “We were hoping as a BC Liberal government to bridge that, because we try to represent all parts of the province, while other parties have focused just on the Lower Mainland,” Bernier said. Bernier, who served as education minister in the last government, was glad to see Davies elected. “We want to continue to make sure the Peace Region sticks together and our voices are heard together,” he said. With current balance of power, Green Leader Weaver slams LNG, Kinder Morgan, Site C In the meantime, industry advocates in the region are paying close attention to the final ballot count and how it will impact resource development for the next four years. Andrew Weaver and his Green Party currently hold the balance of power in a minority government. While that may change with the final count, it’s pause for concern for businesses and workers counting on an LNG industry taking off, as well as the continuation of Site C dam construction. Weaver is aware of his leverage, telling reporters May 17 he is in talks with both the Liberals and NDP. “It would be irresponsible for us to preclude negotiations with any political party simply because they have not said something in the past,” he told reporters. “Our position has always been that the B.C. Greens can collaborate and negotiate with anyone.
We understand what compromise means.” Nevertheless, Weaver has put his cards on the table: he wants official party status for the Greens, corporate and union political donations banned, and proportional representation in the legislature. He also upped his ante on resource development, noting the Site C dam and Kinder Morgan could be put on the table. “We believe Site C is reckless from an economic perspective. It’s essentially trying to deliver power to a non-existent LNG industry,” he told reporters. “We believe that having diluted bitumen in our coastal waters is not something we can support. “Our position on Kinder Morgan and Site C is not too dissimilar from the NDP’s position… but is quite dramatically far away from the Liberal position. So in negotiations you have to put it all on the table and see where things end up.” The Independent Contractors and Businesses Association, which recently expanded its operations and presence in Northeast B.C., endorsed Clark and her Liberals. Art Jarvis says the association could work with an NDP government, but stressed the Liberals must win two seats to comfortably secure the party’s majority vote and resource agenda, and be able to appoint a speaker of the house. “That’s what everybody is hanging on. I’m sure there’s a lot of business decisions not being made right now in anticipation of what happens,” he said. He added: “Business people in general would like to see a Liberal majority government and then you can bank on them continuing on their same plan. Right now, it’s a disaster because the Green party has got the deciding factor. It’s so close between the NDP and Liberals that anything that comes to the table, the Green party is going to be the balance.”
MAY 19, 2017
PIPELINE NEWS NORTH •
OUTLOOK
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Upgraded forecast projects more drilling across Western Canada The Petroleum Services Association of Canada (PSAC) has released a second update to its 2017 Canadian Drilling Activity Forecast, which increases the forecasted The number of wells forecast to be The number of wells forecast to be number of wells drilled across drilled in Alberta in 2017, up from drilled in B.C. in 2017, up from initial Canada for 2017 to 6,680 wells. This represents an increase initial projections of 1,900. projections of 280. of 2,505 wells and a 60 per cent increase from PSAC’s original 2017 Drilling Activity Forecast released in early November 2016 of 4,175 wells The drilling seasons of 2015 and 2016 were difficult to say the very least and the rig released. PSAC based its updated sector is still making adjustments to manage costs and meet growing expectations 2017 forecast on average natural gas of their customers. But with some degree of confidence in $50 oil and the dramatic prices of $3.00 CDN/mcf (AECO), lowering of costs by the service sector, we are seeing increased activity levels. crude oil prices of US$52.50/barrel —Mark Salkeld, PSAC (WTI) and the Canada-US exchange rate averaging $0.74. “Never under-estimate the are recognizing that the cost class services our customers, the tenacity or efficiency of the reductions delivered by the service producers, need and rely on.” Canadian oilfield services sector,” sector over the last three years are On a provincial basis for 2017, PSAC President and CEO Mark not sustainable, especially now PSAC now estimates 3,320 wells to Salkeld said. that there are indications of an be drilled in Alberta, up from 1,900 “The drilling seasons of 2015 and uptick in industry. The leading edge wells in the original forecast. 2016 were difficult to say the very innovation, safety and efficiencies Approximately sixty per cent least and the sector is still making for drilling and completing oil and more wells are also expected to be adjustments to manage costs and gas wells in Canada come from drilled in British Columbia, with meet growing expectations of modern certified equipment and PSAC’s revised forecast now at 449 their customers, but with some highly trained workers which are wells for the province up from 280 in degree of confidence in $50 oil and difficult to deliver with razor thin the original forecast. the dramatic lowering of costs by margins. Rate increases for oilfield The revised forecast for the service sector, we are seeing services are being realized slowly Saskatchewan now sits at 2,670 increased activity levels.” which will help this sector get wells compared to 1,940 wells in the Salkeld added, “The producers back to work delivering the best in original forecast, and Manitoba is
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forecasted to see 221 wells or a jump of 171 in well count for 2017 “Two pressures on our sector remain in that Canada desperately needs pipelines actually built to move oil to tidewater, and secondly, Canada needs LNG train approvals,” Salkeld says. “We are among the best in the world at getting oil and gas out of the ground for domestic use across Canada and so it also makes sense to provide our responsibly developed Canadian oil and gas to parts of the world that want and need oil and natural gas. The days of relying on one customer purchasing our oil and gas at a discount must end. The sooner we expand our customer base the better off Canada and all of its citizens will be. “The oilfield services sector has proven once again that they are resilient in tough times, because they have to be in order to compete and survive. We have seen some member companies fail, but we have seen others grow, consolidate and expand. There are certainly fewer oilfield service companies today than there were just few short years ago but those that remain are the leaders that will continue to succeed in this sector going forward.”
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MAY 19, 2017
OUTLOOK
Painted Pony confident in B.C. oil and gas despite political uncertainty While there is some uncertainty following last week’s provincial election in B.C., Painted Pony’s CEO is still fairly confident in the continued business-friendly nature of the government even in light of its minority status, with the New Democrats having almost as many seats as the Liberals. “I have worked in B.C. for 40 years, and I have worked under NDP governments before, and they have been fine,” said Pat Ward, following the company’s recent annual meeting May 11. “They were making some noise during this election, but they appreciate what the oil and gas industry does for their province.” Following an extremely tight race, the B.C. Liberals—which had ruled with a majority for 16 years—won 43 seats in the 87-seat B.C. Legislature to form a minority government, while the NDP won 41 seats and the Green Party won three. “It’s always nice to go with the government you know, and so it would be nice if the Liberals had received a majority, but we can work with [the government] either way,” Ward said. However, he said, neither the Liberals nor NDP would work against the energy sector, and are likely to pursue initiatives such as LNG development or solar and wind farms. “The NDP are backed by unions, and the union workers...a lot of them work on projects that we have.” Ward is not too worried about the influence of the Green Party either, given its so-called “balance of power” only consists of three seats in the Legislature. Where Painted Pony operates in B.C., he told the AGM, the company enjoys what is perhaps the best royalty structure in North America, and potentially the world. —JWN ENERGY
ROB KRUYT PHOTO
From left, Doug Stout, FortisBC’s vice-president of marketing, development and external relations; Meghan Harris-Ngae, EY’s energy market leader; and Paul Cheliak, Canadian Gas Association’s vice-president of government and regulatory affairs, discuss the future of natural gas.
Regulators ponder future of natural gas If British Columbians think their power bills are high now, and that $8.8 billion is a lot to pay for the new Site C dam, consider this: natural gas meets 35% of Canada’s energy needs, and phasing it out will require a 200% increase in electricity generation, according to Paul Cheliak, vice-president of government and regulatory affairs for the Canadian Gas Association. And the cost of that new power? About eight to 12 times higher than natural gas, per unit of energy, if wind power is used, 15 times higher for solar power, and four to nine times higher for renewable natural gas such as landfill gas. Cheliak was among the speakers at a panel discussion on the future of natural gas at a Canadian Association of Members of Public Utility
Tribunals conference. There was perhaps no better city in which to ask that question than Vancouver, where the provincial government has been trying to develop an export market for B.C.’s gas in the form of LNG while the City of Vancouver has been moving to ban it in new developments. “Natural gas has been— you’ve probably seen this quoted—the bridging fuel to a low-carbon future,” said Meghan Harris-Ngae, energy market leader for EY. If used to replace coal power or even Russian pipeline gas in China, North American LNG exports would have a net benefit in terms of reduced greenhouse gases, according to a study published in Environmental Science & Technology in 2015. It would also have a net benefit when used to backstop
new renewable energy, or to displace transportation fuels like diesel, bunker fuel and gasoline. But as a source for heating, it is fast becoming a pariah fuel, which poses a challenge for natural gas utility companies like FortisBC. There have already been moves in Canada, including Ontario, to phase it out as a heating source. The City of Vancouver is the latest jurisdiction to enact policies that would phase it out. At the beginning of May, the city passed a new zoning bylaw that places emissions limits on new buildings during rezoning. By 2050, the city wants to have 100 percent of the energy used in Vancouver to be renewable.
CONTINUED ON PAGE 11
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MAY 19, 2017
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WESTERN CANADA LAND SALE HIGHLIGHTS
FORT ST. JOHN CAMPUS
ALBERTA Alberta attracted $18.76 million in bonus bids at its May 10 sale, as it continues to add to its yearly total, which is already just under $10 million off the entire haul collected for 2016. Industry acquired 32,816 hectares this week at an average of $571.78. Highlights included a land sale high bid of $3.21 million by The Land Group Inc. The April 26 land sale produced $26.57 million in bonus bids. Industry picked up 43,667 hectares at an average price of $608.44. Year-to-date, Alberta has sold 372,373 hectares at an average price of $323.42. The higher priced parcels were bought for Duvernay potential. Coles Bay Resources Ltd. paid the land sale bonus high of $15.11 million. Year-to-date, Alberta has brought in $139.2 million on the sale of 405,189 hectares at an average price of $343.53.
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BRITISH COLUMBIA British Columbia’s natural gas and petroleum rights sale for April resulted in $14.92 million in bonus bids. On April 19, eight parcels sold covering 4,759 hectares at an average price of $3,135.74 per hectare. Year-to-date, the government has attracted $63.06 million in bonus bids on 28,901 hectares at an average price of $2,181.96. For the same period last year, the government had collected only $2.47 million on the sale of 13,881 hectares at $178.22 per hectare. The highest value parcel in April’s sale was a 1,056-hectare lease in the heart of the B.C. Montney play fairway, immediately adjacent to Shell Canada Limited’s Groundbirch development. This four-section, picked up by Scott Land & Lease Ltd., earned $14.12 million in bonus at a price of $13,367.98 per hectare.
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SASKATCHEWAN Saskatchewan’s first public offering of Crown petroleum and natural gas rights (P&NG) for the 2017/2018 fiscal year raised $1.37 million. Industry picked up 5,973 hectares at an average price of $229.71. So far after two sales for calendar year 2017, the province has brought in $3.1 million on 11,606 hectares at an average price of $267.35. To the same point of 2016, it had collected $8.13 million on the sale of 20,114 hectares at an average price of $404.
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MANITOBA Manitoba’s May land sale attracted $64,175 in bonus bids. Industry picked up 189.14 hectares at an average price of $339.30. Year-to-date, the province has attracted $214,095 on 365.14 hectares at an average price of $586.34. To the same point of 2016 it had brought in $141,859 on the sale of 1,413.62 hectares at an average price of $100.35. Plunkett Resources Ltd. paid the highest price per hectare for a parcel located in the Virden area. The firm paid $653.73 per hectare, a bonus of $39,969.
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OPERATIONS
Enbridge launches open season on proposed $1B B.C. Mainline expansion A $1 billion expansion on Enbridge Inc.’s recently-acquired British Columbia natural gas Mainline system could come into service by late 2020, assuming a successful open season, the company said in announcing first quarter 2017 financial results. Enbridge on April 25, 2017 launched the binding open season on its T-South system for delivery of an incremental 190 mmcf per day of natural gas into the Huntington/ Sumas market at the Canada/United States border. The project would include looping of T-South and upgrades at compressor stations along the pipeline system. “Through our early open season process on our western Canadian system we are expecting strong demand for the expansion of our T-South gas pipeline given the attractive fundamentals supporting natural gas production growth from the Montney and the Duvernay,” Al Monaco, president and CEO, said in a news release. The system is currently fully contracted and an expansion is necessary to meet increasing customer demand as a result of rapidly growing production in the prolific Montney and Duvernay regions, said the company. During the first quarter of 2017, Enbridge completed the stock-for-stock transaction to acquire Spectra Energy Corp., becoming the largest energy infrastructure company in North America. “We brought together what we believe are the highest-quality infrastructure franchises in North America under one roof,” Monaco said in a conference call this morning. “This provides us with unparalleled low risk commercial profile and an industry-leading growth program across six platforms.” He added that Enbridge is very pleased with the way the companies came together. “We had a seamless Day 1 transition and integration-wise, we are on track.” First quarter earnings attributable to common shareholders were $638 million or 54 cents per common share, including the impact of a number of unusual, nonrecurring or non-operating factors. The results reflect approximately one month of financial contribution from the assets acquired in the Spectra Energy merger transaction which closed Feb. 27, 2017. First quarter adjusted earnings were $675 million or 57 cents per common share (2016 - $663 million) while adjusted earnings before interest and income taxes (EBIT) were $1.52 billion (2016 - $1.37 billion). —DAILY OIL BULLETIN
REFINERY UPGRADES—Alberta’s Parkland Fuel Corp. is planning for a $100-million upgrade of the Chevron
refinery in Burnaby, seen here, next year. In April it was announced the company was purchasing the refinery and 129 gas stations in B.C. for $1.5 billion. According to Business in Vancouver, Parkland plans to spend $100 million on a “material” upgrade in the first quarter of 2018 on the Burnaby refinery. The refinery currently processes 55,000 barrels of oil per day to produce gasoline, diesel and jet fuel. The refinery supplies 20% to 25% of B.C.’s gasoline and diesel.
AltaGas makes progress on NEBC strategy The expected commercial onstream date for AltaGas Ltd.’s North Pine separation project and North Pine pipelines in has been moved up to the first quarter of 2018. Logging, clearing and mulching activities have been completed and civil construction activities will start in the second quarter of 2017, the company said in its first quarter 2017 results. The North Pine Facility, 40 kilometres northwest of Fort St. John, will be connected to existing AltaGas infrastructure in the region. It will have access to the Canadian National Railway Company network, allowing for the transportation of propane from the facility to the Ridley Island propane export terminal. The capital cost of the first train and associated pipelines is estimated to be approximately $125 to $135 million. The investment will be backstopped by long-term supply agreements with Painted Pony Petroleum Ltd. for a portion of the total capacity and will include dedication of all of Painted Pony’s natural gas liquids produced at the Townsend and Blair Creek facilities. Construction of the Ridley terminal is expected to begin
in the second quarter of 2017 following site preparation and pre-construction activities which currently are underway. The project will proceed under the self-perform model successfully used by AltaGas to build its other projects on time and on budget and is expected to be in service by the first quarter of 2019. Other company updates: Townsend Phase 2 Granted a positive final investment decision in February 2017, construction has commenced on the first train of Townsend Phase 2, a 99 mmcf/d shallow-cut gas processing facility adjacent to the currently operating Townsend Facility in northeast British Columbia. Estimated to cost $80 million, the addition of incremental field compression equipment to move raw gas production from the Blair Creek area to Townsend, would bump that to between $120 to $140 million. Fabrication is underway on several components of the project, as well as on the incremental field compression equipment, AltaGas says. Commercial operation for Townsend Phase 2 is expected to begin in October 2017. AltaGas and Painted Pony
Petroleum Ltd. have signed 20year take-or-pay agreements for this facility and the incremental field compression equipment. Montney facilities In January 2017, AltaGas entered into a non-binding letter of intent with “a significant Montney producer” to construct a 120 Mmcf/d deep-cut natural gas processing facility and a NGL separation train (10,000 Bbls/d of NGL mix processing capacity), and a rail terminal. Negotiation of definitive agreements is currently on hold while AltaGas continues to have discussions with other producers in the Montney. Deep Basin NGL facility AltaGas says it is in the early stages of development of Deep Basin NGL facilities worth between $30 and $80 million. The NGL facilities will have access to existing rail and can be connected to the Ridley terminal. Discussions with producers to contractually underpin the facility are continuing and engagement with First Nations and key stakeholders is underway. —JWN ENERGY/DAILY OIL BULLETIN
MAY 19, 2017
PIPELINE NEWS NORTH •
OPERATIONS
9
ARC UPDATE—These
ARC Resources workhorses were spotted pumping in full swing in Tower Lake earlier this month. First quarter 2017 crude oil and liquids production for the company was 32,427 barrels per day, while natural gas production was 496 MMcf per day. ARC drilled 46 operated wells (29 crude oil wells, 15 liquids-rich natural gas wells, and two natural gas wells) in the first quarter of 2017, many of which will be brought on production late in the second quarter of 2017.
11 things to know about the blockbuster $9.7-billion Pembina-Veresen deal In a major midstream transaction announced May 1, Pembina Pipeline Corporation says it will acquire Veresen Inc. in a friendly $9.7-billion deal combined of stock and cash. The combination creates one of the largest infrastructure companies in Canada, with enterprise value of approximately $33 billion. The companies say their assets are already highly integrated, while the deal extends geographic reach and will enable future growth. Here are 11 highlights of the deal. 1. Pembina’s assets, primarily located in the prolific Deep Basin, Duvernay and Alberta Montney, are “well complemented” by Veresen’s position in the B.C. Montney. 2. Pembina’s existing assets are primarily focused on NGL, condensate, crude oil and heavy oil, while Veresen’s assets “provide size and scale” in natural gas midstream infrastructure. 3. The majority of the combined asset base is already physically connected or presents the opportunity to be connected with relative ease in the future, which allows for operational
integration, the potential to realize significant synergies and overall enhancements to customer service, Pembina says. 4. Veresen’s current 1.5 billion bcf/d of gas processing infrastructure that is currently under construction is “very complementary” to Pembina’s approximately 1.7 bcf/d of field gas processing capacity in the Deep Basin, Duvernay and Alberta Montney, as well as its previously announced pipeline expansion and lateral development in the B.C. Montney. 5. The deal brings together the ownership that both companies hold in the Alliance Pipeline, which transports natural gas from the WCSB and U.S. Bakken to the Chicago market. Veresen’s Aux Sable natural gas extraction and fractionation facility is located at the terminus of the Alliance Pipeline. 6. Pembina says opportunities to integrate its gas processing infrastructure in the WCSB with the Alliance Pipeline and Aux Sable will be explored, with the aim of increasing market access for its customers. 7. The combined entity
will also have exposure to key producing basins in the U.S. Rockies, where Pembina does not currently have a position, by way of the Ruby Pipeline. 8. The combined company will be “ideally positioned” to execute on Pembina’s and Veresen’s aggregate secured growth portfolio totaling approximately $6 billion through 2018. 9. Pembina is nearing the completion of over $4 billion in growth projects this year, while Veresen has approximately $1.5 billion in secured growth projects—the entirety of which are directly connected into Pembina’s conventional pipeline infrastructure. 10. The combined entity will continue to “build upon the momentum” of Veresen’s proposed Jordan Cove LNG project as it progresses toward key regulatory and commercial milestones. 11. The combined company anticipates realizing significant near-term synergies through the transaction including that are expected to average $75 to $100 million annually. —JWN ENERGY
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MAY 19, 2017
REGULATION
First Nations oil export backers speak out against Trudeau’s B.C. tanker ban
Feds move to ban tankers B.C.’s north coast EAGLE SPIRIT ENERGY PHOTO
Calvin Helin is chairman and president of Eagle Spirit Energy Holdings.
The leaders of a First Nations-backed oil pipeline and tanker export proposal off the B.C. coast are speaking out against legislation introduced last week by the federal government to implement an oil tanker ban off B.C.’s north coast. “To be clear; there has been insufficient consultation for the proposed tanker moratorium and it does not have our consent,” read a statement issued by Eagle Spirit Energy, an initiative of elected and hereditary chiefs from B.C., with elected co-chairs from B.C. and Alberta. “As Indigenous peoples, we want to preserve the right to determine the types of activities that take place in our territories and do not accept that the federal government should tell us how to preserve, protect, and work within our traditional territories.” Eagle Spirit says the Government of Canada should accept the analysis of affected coastal First Nations rather than put in place a blanket tanker moratorium, especially for First Nations led projects. “We believe a First Nations process should be implemented to help determine what resource projects can be developed on our lands and what products can be shipped off of our coast lines,” said the statement. “We will not support projects that endanger our communities and the environment; however, we do believe environmental protection and responsible economic development is possible. This ill-conceived legislation puts the prosperity and the future of our people, particularly our youth, in jeopardy.” Eagle Spirit says its chief’s council will continue to study this legislation and its options and will have more to say in the days to come. —JWN ENERGY
On May 12, the Government of Canada introduced C-48, the Oil Tanker Moratorium Act in Parliament to formalize an oil tanker moratorium on British Columbia’s north coast. The proposed Act would prohibit oil tankers carrying more than 12,500 metric tonnes of crude or persistent oils as cargo from stopping, loading or unloading any of these oils at ports or marine installations in northern British Columbia. The proposed moratorium area extends from the Canada/ United States border in the north down to the point on British Columbia’s mainland adjacent to the northern tip
of Vancouver Island, and also includes Haida Gwaii. Oil products named in the act range include partially upgraded bitumen, synthetic crude oil, petroleum pitch, slack wax, and bunker C fuel oil. It does not include liquefied natural gas, gasoline, naphtha , jet fuel, and propane. The legislation proposes strong penalty provisions for contravention that could reach up to $5 million. The legislation also proposes flexibility for amendments. Further refined petroleum products can be removed from the list on the basis of science and environmental safety.
Products may also be added on this basis. “The Government of Canada is committed to demonstrating a clean environment and a strong economy can go handin-hand,” Transport Minister Marc Garneau said. “Tabling this legislation is another step towards fulfilling our promise to formalize the tanker moratorium on British Columbia’s north coast. This, and other actions we are taking to improve marine safety through the Oceans Protection Plan, will protect the coasts and waterways that Canadians depend on for generations to come.”
Moratorium too broad, could impact Montney: CAPP The Canadian Association of Petroleum Producers (CAPP) says the ban on tanker traffic on the north coast of British Columbia is not necessary and will damage their business. The proposed legislation also broader than originally expected, the organizations ays. Prime Minster Justin Trudeau announced his government’s plan for the ban in November along with the federal approval for the Trans Mountain Pipeline expansion and Enbridge’s Line 3 project as well as rejection of the Northern Gateway Pipeline. Environmental groups commended Ottawa for following through on its promise, but CAPP says the ban will challenge an industry already facing significant market access challenges. “The proposed moratorium could significantly impair Canada’s oil and natural gas
resources from reaching new markets and ensuring Canadians receive fair market value for its resources,” CAPP said in a statement. “Access to tidewater and the ability to export from Canada’s West Coast fulfills the government’s national commitment to get our resources to tidewater, increasing the longterm prosperity of Canadians.” The moratorium was expected to ban crude oil tankers from Canada’s Pacific North coast. But the legislation tabled may go farther than that, according to CAPP. The legislation bans both crude oil and “persistent oils” which CAPP believes could also include condensate, which has become the single most important oil product being produced in B.C.’s Montney play. Condensate is a type of lighter oil that is used to dilute the heavier bitumen produced in
Alberta’s oilsands. It may be that most of that condensate would be sold to Alberta anyway. But CAPP fears that the new moratorium now shuts the door to any future exports of condensate, or light oil for that matter—which some oil and gas producers in northeastern B.C. are also now producing. “Export of emerging light, tight oil resources off the West Coast could be at risk, going beyond the original intent of the federal government when it first announced the moratorium,” CAPP said. CAPP says the government has not identified or provided industry with science-based gaps in safety or environmental protection that justifies a moratorium.
—JWN ENERGY/BIV
MAY 19, 2017
PIPELINE NEWS NORTH •
REGULATION
11
Public pipeline portal launched
NEB seeks public input on Energy East
The National Energy Board has launched a new interactive online tool that provides Canadians with information on what products are moving through NEB-regulated pipelines. The Pipeline Portal provides easy-to-use information on what has been shipped on most large NEB-pipelines since 2006. Where available, data is provided at key points, including every international export/import point. Some companies are exempt from filing pipeline traffic data. The NEB is currently reviewing all exemptions to these filing requirements with the goal of maximizing data transparency. As an example of some of the information available on the Pipeline Portal, did you know that: • Over the last 10 years, Keystone Pipeline has been moving less domestic light oil and more domestic heavy oil? • Westcoast’s BC System delivers
The National Energy Board wants public input on what topics should be considered in the review of the Energy East and Eastern Mainline pipeline projects. The public has until May 31 to provide comments. Energy East is a 4,500-kilometre pipeline proposed to carry 1.1 million barrels of crude oil per day from Alberta and Saskatchewan to refineries in Eastern Canada and a marine terminal in New Brunswick. The Eastern Mainline Pipeline is a proposal to build approximately 279 kilometres of new gas pipeline and related components, beginning near Markham, Ontario and finishing near Brouseville, Ontario. The hearing panel assigned to the Energy East and Eastern Mainline Projects issued two draft lists of issues May 10: one for Energy East and one that is specific to the Eastern Mainline Project. The Lists of Issues identify the topics the Hearing Panel will consider during the hearing. All of the evidence and
gas into Nova Gas Transmission Ltd. at Sunset Creek and natural gas moves between the two systems at the NOVA/Gordondale point? “Canada is a vast nation with a diverse energy mix. A better understanding of what energy is produced, as well as how, when and where it’s transported will lead to a more informed energy dialogue across the country,” said NEB Chair and CEO Peter Watson. Users of the portal can view the type of products (e.g. heavy oil, natural gas) that is moving through the pipeline, the amount of product moving at key points on the line (based on physical movements, not just contractual exchanges of energy), the approximate capacity of each pipeline, as well as daily data for natural gas pipelines, and monthly data for oil pipelines. Log on to the portal via the NEB’s website at neb-one.gc.ca.
questions raised by participants during the hearing should relate to at least one of the topics identified on the final lists of issues. One of the notable additions to the draft lists is a proposal to consider the upstream and downstream greenhouse gas emissions of the projects. The NEB is accepting comments via mail or courier, fax, and through its online participation portal. When filing documents, please refer to File No. OF-FacOil-E266-2014-01 02 and address your documents to: Ms. Sheri Young Secretary of the Board National Energy Board Suite 210, 517 Tenth Avenue SW Calgary, AB T2R 0A8 Via fax: 403-292-5503 or online at neb-one.gc.ca. The panel expects to release the final Lists of Issues by early summer.
Federal ‘electrification’ agenda CONTINUED FROM PAGE 6
The new policy is considered a de facto ban on natural gas, because the amount of available renewable natural gas (methane captured from landfills and dairy farms) is so minuscule it is virtually non-existent. The move highlights a wide gulf between various levels of government and regulators. The BC Utilities Commission had no say on the city’s policy, even though it has the potential to affect homeowners’ heating costs. Those attending the conference heard that there is also a disconnect between federal, provincial and municipal governments on energy and climate change policies that could leave utility companies like FortisBC with stranded assets. Cheliak said that, after it was elected, the new federal Liberal government came out with a de facto energy plan as part of its climate change strategy that is effectively an “electrification agenda.” “That was done well in advance of the consultation even starting,” he said. “Our issue is it’s hard to have a consultation that’s fruitful when, in our view, you have already
published the results of your consultation.” Asked if natural gas will soon be considered in the same light as coal, Doug Stout, vice-president of marketing, development and external relations for FortisBC, said it already is in some quarters. “In Canada I think there is a target on gas—that it is the new coal,” Stout said. There are uses for natural gas other than heating, including as a transportation fuel—a market FortisBC is already pursuing. But its main business is supplying Canadians with natural gas for heating. Cheliak said he thinks a transition away from natural gas for heating is something that is still some way off. He said coal’s demise in North America is not just the result of government policies on climate change, but has also been brought about by competition from natural gas, which not only is lower in carbon content but—in North America at least—is also plentiful and cheap.
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LNG
WOODFIBRE LNG PHOTO
SITE REMEDIATION—Woodfibre LNG is one month into a multi-million dollar, multi-phase cleanup at the former Woodfibre pulp mill site in Howe Sound. Crews have
demolished an old staircase and several old storage tanks and collected other equipment in preparation for safe disposal. The company also been busy testing abandoned industrial equipment and infrastructure for hazardous materials to ensure safe disposal.
The good news and bad news for Canadian LNG Thanks in no small part to a shift from coal, the long-term outlook for LNG in China and Southeast Asia is bright, creating a window of opportunity for Canadian exports, according to experts speaking over Canadian Energy Research Institute’s two-day 2017 Oil & Gas Symposium. China burns approximately four billion tonnes/year of coal. If even four per cent of that was replaced with natural gas, it could generate an extra 100 million tonnes of LNG demand, said Geoffrey Cann, a consulting partner at Deloitte Canada. “All it takes are very small adjustments to national government policies and programs related to carbon on a global level, and the natural gas industry has a very, very bright future,” he said. In mainland China, that shift might already be underway. But it might not be as great for LNG as some hope, according to Cecilia Tam, a special adviser at the Asia Pacific Energy Research Centre. “I think this is already quite clear in terms of government policy, such as targets for gas consumption. Now, whether new gas supply will be in the form of LNG, domestic production or piped gas, I think you’re going to see a mixed bag,” she said.
“There are definitely already clear signs today that market is going to be happening, but being able to quantify it is tough. Everyone is trying to figure out that question.” Cann also acknowledged the market is changing. “There are whole new business models opening up,” he said. “Canada may be caught in…thinking about LNG a bit too narrowly.” The Canadian advantage But Cann and Tam both suggested that Canadian LNG has some advantages over its competitors, particularly the U.S. For one, Canada is closer to Asia. Despite the Panama Canal opening for large-scale LNG tankers, U.S. exporters still need to pay to pass. “Canada has an inherent, permanent, longterm shipping advantage until geologic plates move the United States closer to Asia, which won’t happen in my lifetime,” Cann said. Canada also has abundant gas resources in B.C. and Alberta. “Montney gas is rich and appeals to LNG buyers,” said Robert Dakers, the commercial director for LNG Canada. But the biggest issue for Canadian suppliers happens before the LNG even has a chance to
leave the country. Pipeline and plant costs are higher in western Canada than in the U.S. Gulf Coast, Dakers said. Tam also said Canada’s stricter regulatory environment plus a carbon price at both federal and provincial levels means competition in prices alone may not be the best arena for Canadian LNG developers. “I think that’s going to be the main challenge for Canada. I think Canada also needs to be able to compete in providing additional security, which a lot of Asian customers are looking for.” LNG projects must learn how to compete at current low prices, according to Yuji Kakimi, president of JERA, in an interview before his presentation at the CERAWeek conference. “Last year’s sport prices ranged from around $5 to $10/mmBtu, and we have to have projects that are economical even at the low end of those prices. “Otherwise the expected golden age of LNG in the mid-2020s may not come because it is questionable whether developing and emerging nations would significantly increase LNG purchase if the prices keeps rising,” he said.
—JWN ENERGY/BUSINESS IN VANCOUVER
MAY 19, 2017
PIPELINE NEWS NORTH •
COMMENT
13
Suzuki Foundation researchers impressed by B.C.’s gas emissions though the researchers took steps to ensure their data was solid, this is a possibility they could not rule out. They also observed that maintenance work, as well as current drilling operations, might have skewed the measurements. Despite the potential flaws, it’s good to know that research of this type is being done. It can help draw attention to the regulations that are in place to improve British Columbia’s already impressive environmental performance, as well as flag areas that do need closer attention. Even though the Suzuki Foundation is widely seen as dedicated to opposing most types of resource infrastructure, its research paper took pains to acknowledge how successful BC has been in protecting the environment, especially when compared to the United States, a jurisdiction that remains gridlocked on the climate leadership issue. The researchers went out of their way to praise British Columbia practices. Wrote the St. Francis Xavier University researchers in their paper: “The less-permeable, natural-gas hosting portion of the Montney formation is located in BC, a province that has generally been very progressive on many issues of environmental stewardship, so there is a broad interest in emissions quantification and environmental performance.” Thanks to the Suzuki Foundation’s work, we have fresh verification that companies are working hard to meet federal and provincial environmental standards, and succeeding. These players know it pays to innovate and exceed standards and be a world leader. There is evidently some ageing equipment out there that might need attention, and BC’s proud history of environmentalism provides assurances that that will happen. Groups such as the BC Oil and Gas Research and Innovation Society have a job to do in ensuring that findings on these issues are shared and interpreted with the public. Let’s not forget that natural gas in BC provides the foundation for responsible resource development, including the progress of an LNG export industry based on development of the Montney shale resource. By succeeding with this, the province can take pride in helping other countries reduce their unhealthy practices that damage the global environment. STEWART MUIR IS EXECUTIVE DIRECTOR OF RESOURCE WORKS.
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The David Suzuki Foundation, in a recent report produced in collaboration with St. Xavier University of Nova Scotia, claims methane emissions from B.C.’s natural-gas emissions are higher than reported. The Toronto Star was among news outlets that promptly carried a story flagging the finding. While a Suzuki spokesperson described the findings as “staggering”, it turns out on closer examination that the actual report portrays a much more nuanced situation. The problems with methane escape are from dated, in some cases no longer in service, gas infrastructure, and not from the current generation. Based on the study, the role of natural gas as a much cleaner fossil fuel that can aid in the global fight against climate change is reinforced, rather than blunted. Of the newer well infrastructure in British Columbia’s Montney region, “relatively little of it emits — presumably because of improved modern practice, integrity, and better design of new valves, seals and flange gaskets etc.” With hundreds of new wells being drilled and other modern infrastructure being put into place in 2017, it’s clear that the methane issue does not lie in current or future natural gas production. The Suzuki Foundation should be encouraged to use this study as further evidence for supporting continued development of the Montney shale. The study also confirms the high quality of natural gas regulation in British Columbia compared with the United States. The researchers who drove around the Peace River district measuring emissions found that “in comparison to studies at select U.S. natural-gas sites our results suggest that natural-gas activity in the Montney formation may emit both less-frequently and less-severely than U.S. comparators.” The Suzuki Foundation also did not address another matter the researchers disclosed. The Peace River district is ranch country and the researchers were unable to say definitively that the methane gas they were measuring came from natural gas extraction, or whether it also included methane issuing from cattle. Wrote the researchers: “No unique thermogenic tracer was used in this package of surveys to discriminate biogenic CH4 sources, such as cattle that may have been present on the well sites at the time of surveying.” So this whole story might be based on bovine flatus and burps? Even
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IN BRIEF
United Steelworkers applaud Kinder Morgan steel deal Kinder Morgan Canada has struck a deal to have the steel pipeline needed for the Trans Mountain pipeline expansion made in Canada—the bulk of it in Saskatchewan. It’s a deal that suddenly puts NDP Leader John Horgan in the uncomfortable position of being opposed to a project that is now supported by the United Steelworkers (USW ) union—his party’s biggest donor. Kinder Morgan Canada has struck a deal with EVRAZ North America to cut 250,000 metric tonnes of steel pipe for the project. Most of that work—75%—will be done in EVRAZ’s plant in Regina. “It has been our commitment from day one to deliver benefits from this project to Canadians,
and we are pleased to announce the single largest potential procurement contract to a Canadian plant and Canadian workers,” Kinder Morgan Canada
president Ian Anderson said in a news release. The agreement is being applauded by the United Steelworkers (USW ).
“The men and women of the United Steelworkers 5890 in Regina will be proud to produce the vast majority of the pipe for the Trans Mountain Expansion in Canada, for Canada,” Stephen Hunt, USW Western Canadian director, said in a news release. “Making this pipe means preserving and creating highly skilled, well-paying, middle-class Canadian jobs.” The USW has contributed more than $670,000 to the NDP, which is officially pledged to stopping the pipeline expansion. The project is expected to create 15,000 jobs annually during peak construction (a period of about two years).
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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.
MAY 19, 2017
PIPELINE NEWS NORTH •
IN BRIEF
15
Public comments wanted on NEB modernization report The expert panel reviewing Canada’s National Energy Board has submitted its report to Natural Resources Minister Jim Carr. “I would like to thank the expert panel members for their time and energy, both in engaging people across the country and in compiling the report,” said Carr in a statement. The report include 26 pieces of recommendations and advice, and the public has until June 14 to submit feedback to the government. Among the recommendations: • Publish and update on a reasonable schedule a formal Canadian energy strategy that plots a course for the future of energy in Canada, balancing environmental, social, and economic objectives; • Establish an independent Canadian Energy Information
Agency, whose mandate would include collection and dissemination of energy data, as well as the production of an annual public report on Canada’s energy system; • That a more complete definition of national interest, inclusive of Indigenous Consultation, environmental, economic, and social factors, be enshrined in regulation and updated on a reasonable schedule to keep pace with societal change; • That enabling legislation of the Canadian Energy Transmission Commission should establish it as an independent, quasi-judicial body, with full authority to approve or deny major projects and that the Canadian Energy Transmission Commission have the mandate
and authority for the licensing of transboundary pipeline and transmission line projects, including the imposition of specific conditions on project proponents; • The government fund an Indigenous Major Projects Office, under the governance of Indigenous peoples; • That CETC and the Minister of Natural Resources move to produce guidelines for early engagement that allow industry and Indigenous peoples to communicate more freely and without prejudice to outstanding claims of right, or subsequent project reviews; • That the government enter into formal agreements with Indigenous nations who wish to participate, in order to deliver local Indigenous energy infrastructure monitoring
programs; • Establishment of an Elders External Advisory Council, in consultationw ith Indigenous peoples, charged with advising the Board, CEO, and Hearing Commissioners on Indigenous issues, as well as reviewing CETC practices; • Establish a Landowners Ombudsman to review and make recommendations on improving relationships with landowners, provide advice and best practices on how to navigate processes, enable better mediation, and potentially administer a fund so that landowners can access relevant legal advice. To view the report and submit feedback: neb-modernization.ca.
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