Pacific NorthWest LNG: The news, the reaction, and the path ahead / 8-10 AUGUST / SEPTEMBER 2017
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With oil supplies forecast to grow, BC’s new NDP government looks to join Trans Mountain legal challenges; $77-million drilling licence sold in July highlights oil potential near Inga; new energy minister reflects on her first official visit to the B.C. Peace; and AltaGas inks deal with Astomos for B.C. propane
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FORT NELSON OILMEN’S GOLF TOURNAMENT this weekend (August 16-19th)
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AUGUST 18, 2017
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OILMEN
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Above, Victor Giesbrecht straightens out young Rylan Kittle’s bow during an archery competition at the FSJ Oilmen’s annual family campout at Peace Island Park. Below, it’s a mad scramble during the bucket brigade challenge, and a watermelon eatin’ challenge.
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LAND / REGULATORY ENVIRONMENTAL ARCHAEOLOGY GIS ANALYSIS & MAPPING UAV AND REMOTE SENSING
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LAND SALES
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$77M Montney drilling licence highlights B.C.’s July P&NG sale RICHARD MACEDO
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A large $77 million parcel highlighted B.C.’s July sale of petroleum and natural gas (P&NG) rights as land sale revenue this year continues its strong recovery after an anemic 2015 and 2016. Industry acquired 17,009 hectares this week for $84.73 million at an average price of $4,981.28. Year-to-date, the province has collected $155.01 million on 52,200 hectares at an average price of $2,969.54. The high-priced drilling licence was picked up by Scott Land & Lease Ltd., which paid $77 million at an average price of $13,893.90 per hectare for the 5,542-hectare parcel. Tract 1 included sections three-eight, 10, 1317, 20-23 and 29 at 85-24W6 and sections one, two, 11, northern half and southwest quarter of 12 at 85-25W6. The posting included all zones. The second tract included the southeast quarter of section 12 at 85-25W6 for P&NG below the base of the Charlie Lake. The land is located at Inga (85-24W6), east of the Montney production at Altares, and directly offsetting Montney wells drilled by [ARC Resources Ltd.],” said Michele Innes, exploration analyst with Canadian Discovery Ltd. “The existing production to the west is liquids-rich gas, but this land parcel lies inside the oil window as mapped by Canadian Discovery. There is also significant open Crown acreage to the north of this parcel in a favourable temperature and pressure regime for oil, and as such, this land sale likely sets the stage for largescale development of Montney oil at Inga.” Also at the sale, Windfall Resources Ltd. acquired a lease for $2.03 million at an average price of $7,703.49. The broker picked up section six at 87-23W6. The broker also acquired section one at 87-24W6 for an identical bonus and perhectare amount. “Parcels 66427 (87-23W6) and 66428 (8724W6) are just north of the aforementioned
parcel and were also likely purchased for their Montney potential for the same reasons,” Innes said.
Alberta hits $229M on the year with Aug. sale The Alberta government added $11.78 million to its land sale total Aug. 2. The high bonus parcel appeared to be acquired for East Shale Basin Duvernay. Industry purchased 20,438 hectares at an average of $576.49. Year-to-date, the province has collected $229.07 million in bonus bids on 699,865 hectares at an average price of $327.31. The Soo Line Resource Group Ltd. submitted the highest bonus bid at $2.65 million ($1,500 per hectare) for a licence around 38-28W4. The parcel is located in the Sylvan Lake area to the southwest of Vesta Energy’s Duvernay production at Cygnet, said Innes.
Southeast Saskatchewan drives August land sale The province’s southeast region was the focus of activity in August’s sale, representing more than $6 million of the nearly $8 million in total revenue. The province collected $7.87 million in bonus bids on 29,898 hectares at an average price of $263.13. Year-to-date, the province has collected $33.81 million on 64,744 hectares at an average price of $522.20. To the same point of 2016, $22.02 million had come into provincial coffers on the sale of 54,270 hectares at an average price of $405.83. Six exploration licences southwest of Radville received bonus bids totalling $1.6 million for 17,612.02 hectares. —Daily Oil Bulletin
AUGUST 18, 2017
PIPELINE NEWS NORTH •
PIPELINES
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Construction crews bury a section of Pembina’s Northeast BC pipeline expansion project just north of Fort St. John in August.
Wyndwood expansion approved The National Energy Board has approved a proposal from Westcoast Energy Inc. to build and operate the 27-kilometre-long Wyndwood Pipeline Expansion Project. The NEB announced its decision in a letter, released today, and expects to issue detailed reasons on or before September 28, 2017. “After considering all the evidence, the NEB found that the project was in the Canadian public interest,” the Board wrote in an announcement. The NEB attached 32 conditions to its approval, including the requirement to develop a Landowner-Specific Monitoring Plan and Consultation Update and a number of conditions related to minimizing disturbances within caribou ranges and accelerating the restoration of caribou habitat. Westcoast submitted its application on October 21, 2016 under section 58 of the National Energy Board Act. In general, these types of applications do not require a public hearing. However, given the high level of public interest in this project, the NEB decided to hold a hearing in order to consider the input of those who could be directly affected or who have expertise to share. Oral hearings were held on April 5, 2017 in Calgary and June 6 – 7, 2017 in Chetwynd. The NEB also gathered input through written comments, questions and evidence. This project is a loop of Westcoast’s existing Fort St. John Mainline, and will be built in the Stone Creek area southwest of the district along the Pine River Valley. The pipeline has a planned capacity of 50 million cubic feet per day. Completion is expected in 2018.
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PIPELINES
NDP pushes province to join Trans Mountain legal fight NELSON BENNETT & MATT PREPROST The BC NDP government has hired Thomas Berger, a former BC Supreme Court judge who chaired the Royal Commission on the failed Mackenzie Valley pipeline project in the 1970s, to lead a legal battle against the $7.4 billion Trans Mountain pipeline expansion. NDP Environment Minister George Heyman and Attorney General David Eby jointly announced Thursday Aug. 10 that the province will launch two legal strategies to halt the expansion, which has been granted both federal and provincial approval through the National Energy Board and the BC Environmental Assessment Office. The government will seek intervener status in legal challenges that will soon be heard by the federal court against the National Energy board’s approval of the expansion. It will also refuse to issue permits until all conditions with respect to consulting First Nations have been met, as per the provincial Environmental Assessment Office. Not all conditions have been met, Heyman said. “There are a number of permits issued, but they cannot be acted on until the company meets the requirements of the environmental assessment certificate that was issued by the previous government of British Columbia,” Heyman said. “Before they can begin work, the certificate required them to complete environmental management plans. There are eight of them. Only three have been accepted to date and the other five have been not accepted because they have not, according to the environmental assessment office, met the test of adequate consultation with First Nations. “So until those plans are completed, Kinder Morgan—with the exception of private land and with the exception of some clearing or right-ofway—cannot put shovels in the ground.” He said it was “highly unlikely” that can be done by September 12. “Until it is completed, they are not able to begin work. They will be in violation of their environmental certificate.” The National Energy Board approved the pipeline’s expansion in 2016, saying it was in the national interest. The expansion would triple the pipeline’s capacity, which runs from Edmonton to Burnaby. Responding to the announcement, Kinder Morgan Canada said it is taking the NDP
government’s threats seriously and will be carefully reviewing them. But Kinder Morgan Canada president Ian Anderson said the company plans to move forward, as planned, with its construction work in September. “We are committed to working with the province and permitting authorities in our ongoing process of seeking and obtaining necessary permits and permissions,” President Ian Anderson said. “We have undertaken thorough, extensive and meaningful consultations with Aboriginal Peoples, communities and individuals and remain dedicated to those efforts and relationships as we move forward with construction activities in September.
Two challenges before the courts There are currently two legal challenges that will soon come before a federal court that the NDP government now plans to participate in as an intervener. One is a judicial review that will soon come before a federal court that challenges the NEB process that approved the project. The other is a challenge by the Squamish First Nation, in which the B.C. government was named as a respondent. In other words, the government will be in the strange position of having already responded in defence of the pipeline expansion, and then as an intervener, taking an opposite position.
Not all First Nations in B.C. are opposed to the project. Many have signed benefits agreements with Kinder Morgan. Heyman said they too will be part of the additional consultation that the NDP government will now require. Provided the federal court grants the government intervener status, the government plans to argue that consultations with First Nations have not been adequate. The NDP also wants the United Nations Declaration on the Rights of Indigenous Peoples (UNDRIP) to guide those consulations. The federal government attached 157 conditions to the project when it issued an environmental certificate, while the province added another 37 conditions of its own, including continued aboriginal consultations. In January, former BC Liberal premier Christy Clark said the pipeline had finally met her five conditions for approval, including a revenue sharing agreement of up to $1 billion, and marine and land oil spill response and protection measures. “Negotiating in good faith is important in this day in age,” said Peace River North MLA Dan Davies. “There are reasons why we’re all part of confederation, because we, as a country, need to work together as best we can. “We’re a province that has access to water, access to port, access to world markets. We need to be understanding that this is something we have to do to make sure the economy of Canada stays strong, and the economy of B.C. stays strong.” —with Business in Vancouver files
Canadian oil production rebounded in spring: IEA Following sharp declines in March and April, Canadian oil supplies saw a slight rebound in May, according to the International Energy Agency (IEA), which issued its monthly report on the oil market this month. Output fell by a total of 650,000 bbls/d over the past two months
to 4.35 million bbls/d, according to the latest consolidated data published by Statistics Canada through April. In May, however, preliminary data suggest Alberta oil production saw a slight recovery, “contrary to our earlier expectations.” Alberta oil output was 110,000
bbls/day higher month-on-month, despite continued outages at Syncrude’s Mildred Lake upgrader. The 350,000 bbl/d plant, hit by a fire in mid-March, is now expected to return to full production by August, two months behind the original schedule as maintenance planned for later in the year was
moved up while the facility was offline and as the plant was hit by another minor fire in July. Total Canadian oil supplies are forecast to expand by 220,000 bbls/d in 2017 and 180,000 bbls/d next year. —JWN Energy
AUGUST 18, 2017
PIPELINE NEWS NORTH •
POLITICS
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BC GOVERNMENT PHOTO
Energy and Mines Minister Michelle Mungall with natural gas industry reps, local service providers, and Dawson Creek Mayor Dale Bumstead.
Peace Country pride and building sustainable communities were just some of the takeaways for new Energy Minister Michelle Mungall following her visit to the region in August. Mungall had two jammed back-to-back days Aug. 11 and 12, meeting with local officials and First Nations, touring oil and gas sites, and taking in the Dawson Creek Stampede. The trip began with a meeting with Mayors Lori Ackerman and Rob Fraser, who emphasized the importance of prioritizing local economies when attracting investors to the province, Mungall said. “So it’s no surprise given one of our four conditions for the natural gas industry, for the LNG industry specifically, is that local communities are getting the benefits, and that British Columbians are getting a fair rate of return for their resources,” Mungall said. Mungall also met with Oil and Gas Commission officials, and took in tours of Encana and ARC Resources work sites both on the ground and from the air. The sense of pride shared by workers is what struck home the most, she said. “Workers would start off with, ‘I’ve grown up here my whole life,’ though there’s plenty of workers who haven’t as well,” Mungall said. “This industry is employing people from all over Western Canada, but the people who came from the community were so proud they would tell me their life story.” In terms of industry, Mungall was impressed by the use of recycled water in hydraulic fracturing operations. “The actual fracking is being done so far below from where we pull our own potable water from, it was very interesting to see,” she said.“I had read about that, but it was interesting to see it up close, what’s going on.”
Still, a scientific review of the practice remains an NDP commitment and will take place, she said. While her visit coincided with an announcement that the province will seek legal status in challenges against the Trans Mountain pipeline expansion, Mungall stressed the difference between that project and the natural gas infrastructure currently being built or proposed for the northeast. “One is for the Alberta tar sands, one is for B.C. One is about bitumen, one is about a completely different product, that’s a really important thing to remember,” she said. “For the condensates, for the liquids, one of the challenges we have in B.C. is getting those products to market. Right now, our market endpoint is going to be shifting in the next few years from the U.S. and the rest of Canada to Asian markets. So those are one of the challenges we need to start thinking about today, so we are planning for that market shift to come in five to 10 years.” Mayor Lori Ackerman shared with her fellow councillors during a council meeting that her discussions with Mungall were productive and centred on the importance of building social infrastructure through local hiring and business opportunities when it comes to industry development. “We talked about how we understand energy is not just a commodity, it’s a responsibility,” Ackerman said. Mungall said she also met with Blueberry River Chief Marvin Yahey, and West Moberly Chief Roland Willson. She also had a roundtable discussion with elected officials from Dawson Creek. Chetwynd, Tumbler Ridge, and Pouce Coupe.
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Energy minister reflects on Peace tour
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LNG Petronas spent $900m to get to ‘no’ on $36b PNW LNG NELSON BENNETT From Kitimat to Calgary, the implications of Petronas’ decision to pull the plug on its $36 billion Pacific NorthWest LNG project are still being calculated, if not yet felt. The decision’s most immediate impact will be felt by the 44 employees, many of them in Vancouver, who will be laid off. But there are many other ramifications that have yet to be felt. What does the decision mean for the permitted, shovel-ready Prince Rupert Gas Transmission project that TransCanada Corp. planned to build to supply the liquefied natural gas plant, and for the First Nations along the corridor who signed revenue-sharing agreements? What does the project’s cancellation mean for the cash, Crown land and revenue-sharing agreements offered to the Lax Kw’alaams, Metlakatla and Kitselas First Nations in exchange for their support for the project? And what kind of signal does it telegraph to other potential LNG developers, like Shell, Nexen and Chevron Corp.? In announcing the project’s cancellation, Anuar Taib, chairman of the Pacific NorthWest (PNW) LNG board of directors, said the decision was based solely on market conditions and economics. PNW LNG suffered delays in getting federal environmental approval. The industry was then hit by an oil price crash that was followed by falling international LNG prices, as new supplies came into the market from Australia. Petronas had also warned the BC Liberal government in 2014 that the new LNG tax it was planning could make LNG projects in B.C. uneconomic. Asked if the new BC NDP government coming to power had anything to do with the decision, Taib said it had not. “It really boils down to whether or not the project could be competitive in the market conditions of the day.” Taib added that the company looked forward to working with the new NDP government as it continues to develop its natural gas assets in northeastern B.C. But the BC Liberals and at least one industry analyst said the timing of the announcement – coming just eight days after the new Greenbacked NDP government formally assumed power – was an unmistakable signal. Jas Johal, the new Liberal MLA for RichmondQueensborough, pointed out that the NDP’s new environment minister, George Heyman, was part
Wan Badrul Hisham, Petronas’ chief project officer for PNW LNG, was on hand for the signing of $200 million deal between the province and Lax Kw’alaams and Metlakatla First Nations
of an anti-fracking campaign in B.C. while he was executive director for the Sierra Club BC and that NDP Premier John Horgan lobbied the federal government against the PNW LNG project while he was in opposition. “Would you invest $36 billion in this province when cabinet ministers and the premier are speaking out against this project?” said Johal. Michelle Mungall, the NDP’s new energy, mines and petroleum resources minister, said Petronas made it clear that it wasn’t blaming her government for cancelling the project. She added that the NDP government is committed to working with the industry to see other LNG projects built. But her government should not expect cooperation from the BC Green Party. Green Party Leader Andrew Weaver said the Petronas decision confirmed his skepticism about the LNG industry’s prospects in B.C. The Pembina Institute welcomed the project’s demise, saying the greenhouse gases it would have generated would have made it impossible for B.C. to meet its greenhouse gas reduction targets. Ellis Ross, former chief of the Haisla Nation, who was elected the Liberal MLA for the Skeena riding, said opponents of LNG don’t realize how much First Nations in B.C. had been counting on the industry to provide jobs and revenue. As recently as February and March, Petronas had signed multimillion-dollar revenue-sharing deals with First Nations, as did the provincial government. “For those celebrating the demise of Petronas, and possibly celebrating the demise of the LNG industry, you haven’t been to a community that has suffered under 60% unemployment,” Ross said. “You haven’t been to a community that has suffered under poverty.” He said Kitimat and Terrace boomed, providing jobs for First Nations and non-First Nations alike, when companies like Petronas began laying the groundwork for LNG projects in Kitimat and Prince Rupert.
Metlakatla Chief Harold Leighton also expressed disappointment in the Petronas decision. “This project provided significant opportunity to improve the quality of life in our community.” Taib confirmed his company spent $400 million just on the LNG site in Prince Rupert. Another $500 million was spent on the Prince Rupert Gas Transmission line. TransCanada last week stated that an agreement with Petronas ensures the company will be reimbursed. PNW LNG would have represented a total capital investment of $36 billion, about a third of which is already invested in upstream assets in northeastern B.C. The LNG plant in Prince Rupert would have cost $11 billion. The new gas pipeline would have cost another $5 billion. After spending roughly $1 billion on PNW LNG, Petronas decided to cut its losses. TransCanada could find another partner to build the Prince Rupert Gas Transmission (PRGT) line. Nexen, for example, will need a new gas pipeline for its Aurora LNG project in Prince Rupert, if that project gets approved. Asked it that is a possibility, TransCanada spokesman Shawn Howard last week said, “We really can’t speculate about next steps, as we’re focused on having discussions with people along the proposed pipeline route who have been so supportive and important to PRGT.” As for jobs that won’t be created, the Independent Contractors and Businesses Association estimates the PNW LNG project would have generated 4,500 construction jobs and 330 long-term operations positions. Though his own company no longer sees any prospects for itself in the LNG space in B.C., Taib said he still thinks others could be successful here. “I am a believer that there is a space for the LNG business in B.C. and there’s a space for it in Canada,” he said. “You just have to find the right project and at the right time.” —Business in Vancouver
AUGUST 18, 2017
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LNG Supporters sound off on Pacific NorthWest LNG news get these projects approved. If that continues, we will see a lot more investments not moving forward.” —Lori Ackerman, Mayor, Fort St. John
Capital Cost Allowance and the extension of export licenses were, unfortunately, not enough to overcome the current market forces and it appears that will not be the only obstacle in front of these types of projects in BC.” —Bob Zimmer, MP, Prince George-Peace River-Northern Rockies
“After all the hard work that FSJ for LNG has done working towards a federal approval, this happens. The timing of this statement gives us a hint of the reason behind this decision. Coming after an NDP
“My understanding at this time is that Petronas is committed to developing their natural gas assets in Canada. As well they will continue to explore all options as part of its long-term investment strategy moving forward. That does provide some comfort. What is important to note is the significant length of time that it took for Canada and BC to
as proposed in its current state, was uneconomical to move forward. “B.C. remains a player in the LNG sector… I’ll be talking to other LNG stakeholders to ensure we are ready to work with them moving forward, that we have a road map to get them to a full realization of their projects.” —Michelle Mungall, B.C. Minister of Energy, Mines & Petroleum Resources takeover of the province, PNW sees the NDP as not the ideal partners to risk a multi-billion investment in.” —Alan Yu, Founder, Fort St. John For LNG “The company was very clear. This was a decision they are making because of the economic challenges in the global energy marketplace. The Pacific NorthWest LNG project,
“We streamlined the National Energy Board with our One-ProjectOne-Review mandate that would allow proponents of these types of projects, as well as communities involved, a manageable timeline to work within. The 24-month period would give adequate time for everyone involved to voice their opinions and at the same time give viable projects a real chance to succeed. “This, along with the Accelerated
develop an LNG industry providing work opportunities for our members and training opportunities for our apprentices. We hope on a go forward basis that the promotion and development of the industry will be more realistic in terms of what British Columbians might actually realize from the establishment of LNG in our province.” —Tom Sigurdson, Executive Director, BC Building Trades
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“There’s a lot of people in the northeast who have worked extremely hard to advocate for this project to go forward, which I had a part in—the truck rally, the people rally, a lot of people working hard on seeing this project move ahead … They (the NDP) need to be now, more than ever, reaching out these proponents and working to get a deal, period.” — Dan Davies, MLA, Peace River North
“We remain hopeful that BC will
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LNG
NDP retract comments made about fired LNG advocate The province’s former liquefied natural gas advocate is speaking out after being abruptly fired by the new NDP government earlier this month. Gordon Wilson was fired from his job as LNG Buy BC advocate Aug. 1 after serving in the role since October 2013. In announcing the decision, Jobs Minister Bruce Ralston said the government could find no written reports by Wilson during a review of his role and tenure, and thus his $150,000 per year contract was terminated. However, the Province newspaper uncovered 180 pages of publicly available documents and reports that shed light on Wilson’s time in the position, including a work plan, meeting summaries, research findings, and project updates. The information was made public in 2015 following a freedom of information request by the NDP. “The things they said about me are absolutely outrageous and untrue,” Wilson said in an interview with columnist Mike Smyth. “How could they do a ‘review’ of my work and not consider these documents? They never interviewed me or asked me a single question
Gordon Wilson was in Fort St. John in February 2014 to trumpet the province’s LNG Buy BC program, created to link local businesses with job opportunities expected to flow from LNG development.
about the program before they fired me. What kind of ‘review’ is that?” Ralston, along with Premier John Horgan, have since retracted and apologized for the comments. “I acted on the basis of information
that was provided to me,” Ralston told the Province. “I’m taking the responsibility. So I do want to apologize for the statements I made.” Said Horgan: “I offer an apology to Mr. Wilson. I think we need to move
on.” Wilson, however, hasn’t ruled out a possible defamation lawsuit. “I am still hoping to do work in the LNG sector and I can’t allow my reputation to be slagged,” he said. Wilson was a former BC Liberal party leader from in the late 1980s and early 1990s. He has has served both parties in the province -- losing the Liberal leadership race against Gordon Campbell in 1991, then taking a cabinet position with the New Democrats in the late 1990s, before endorsing Clark in the 2013 election. The LNG Buy BC program was announced by former premier Christy Clark as a “matchmaker” service, exposing and linking local businesses to procurement opportunities from proponents through an online portal. During a stop in Fort St. John in February 2014, Wilson told attendees at a Chamber of Commerce luncheon that he came out out of retirement to develop the LNG Buy BC program as a skeptic, but said trotting around the globe and meeting with industry proponents and officials gave him a chance to analyze the potential.
Petronas positioning Montney assets as leader in North America Although Petronas is abandoning its B.C. LNG project, it’s not abandoning B.C. or Canada. In fact, it sees so much promise in its natural gas assets in northeastern B.C., the Malaysian company plans to move its unconventional gas centre of excellence from Kuala Lumpur to Calgary. “For Petronas, we are positioning Progress Energy to be one of the top natural gas exporters in North America,” said Anuar Taib, chairman of the Pacific NorthWest LNG board of directors. When Petronas acquired Alberta’s Progress Energy in 2013 for $5 billion, it acquired an asset that has value, even without access to an Asian export market via LNG. Through that acquisition, as well as the $1.5 billion acquisition of Talisman Energy’s Montney assets, Petronas now has the second-largest position in B.C.’s Montney formation, which is rich in propane and other natural gas liquids. The company estimates its potential natural gas reserves at 52 trillion cubic feet. “I think we’ll continue to find ways to successfully develop that across Western Canada and into North American natural gas markets,” said Progress Energy President Mark Fitzgerald. Cheniere Energy Inc., has stated that it wants to lock up agreements to buy gas from B.C. and Alberta to supply its expanding LNG plants on the U.S. Gulf Coast. Asked if Progress Energy could end up selling B.C. gas to American producers on the Gulf Coast, Fitzgerald said: “That resource that we own is
world-class and highly competitive. We’ll look at every option that we can to bring that to market.”
Japex committed to Montney despite LNG cancellation Japan Petroleum Exploration (Japex) says the partners in the now-cancelled Pacific NorthWest LNG project remain committed to Montney shale gas development. PNW majority owner Petronas announced the $36 billion project would not proceed as a result of changes to the global LNG market rendering it globally uncompetitive. Japex owns 10 percent of PNW along with Petronas (62 percent), Sinopec (15 percent), Indian Oil Corporation (10 percent) and Petroleum Brunei (3 percent). The company was planning to use LNG exported from PNW to supply its Soma import project on the east coast of Japan, which is currently under construction. “The construction of our Soma LNG terminal continues as planned and is scheduled to commence operation from March 2018,” Japex said in a statement. “Considering the current circumstances in the LNG market, we believe that multiple alternative sources of supply are available for the procurement of LNG for the time being.” However, Japex says that it and its partners “remain committed to exploring all options to maximize the value of the [Montney] upstream
project and will continue to implement an efficient
Indian Oil, partners look for cheaper site development of significant gas assets.” Indian Oil Corp Ltd. is in talks with its partners to scout for an alternative, cheaper site for the Pacific NorthWest LNG terminal after the recent pullout of the lead developer cast doubt on the future of the Canadian project, Reuters reports. Sanjiv Singh, chairman of Indian Oil, which has a 10 per cent stake in the Canadian project, said the company remained interest in going ahead with at least part of the plan. “We are very much positive going ahead with the upstream part of it, which is gas production. Liquefaction and transportation further in the liquid form we are not pursuing, I mean, we don’t want to pursue very aggressively as of now,” he told a news conference. “We are also looking at a different location which might be much less expensive than the earlier one,” Singh said. Indian Oil is the first partner to suggest the project could still go ahead, in modified form. Indian Oil Corp. planned to lift 1.2 million tonnes of the super-cooled fuel for 20 years from the British Columbia project for its five million tonne a year regasification LNG plant at Ennore in eastern India. Indian Oil was expecting deliveries from the western Canadian project to begin in 2020. —Business in Vancouver, JWN Energy
AUGUST 18, 2017
PIPELINE NEWS NORTH •
RESEARCH
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Pipeline waiting to be put in the ground near Fort St. John.
Without new pipeline capacity, more oil will move by rail, two new studies warn NELSON BENNETT Should B.C.’s NDP government succeed in halting the expansion of the Trans Mountain pipeline, it won’t necessarily prevent increased volumes of oil moving from Alberta to the west coast. It could result in increased volumes of oil moving through B.C. by rail. And according to a new Fraser Institute study, pipelines are 2.5 times less likely to result in a spill than rail. “The evidence is clear – building new pipelines and shipping oil by tanker is the safest and most environmentally responsible way to get Canadian oil to global markets,” says the report’s author, Ken Green, the institute’s director of energy and natural resource studies. The report, Safety First: Intermodal Safety for Oil and Gas Transportation, builds on the findings of a number of other reports on rail, pipeline and tanker oil spill risks. It arrives at conclusions similar to those of a report by the Manhattan Institute, an American public policy think-tank, which likewise warns that a lack of pipeline capacity in the U.S. will result in more oil moving by rail, truck and tanker. “If the supply of U.S. pipelines is not allowed to expand to meet demand, energy firms will increasingly switch to more dangerous and costly transportation alternatives,” the Manhattan Institute report concludes. Given how much oil moves through North
America by pipeline, the number of oil pipeline spills are low, Green said. “While the risks of accidents and possible releases are certainly real, they are quite small for all modes of transportation given the volume of these commodities that are moved,” he told Business in Vancouver. When there is a spill, however, the impacts can be significant. One year ago, a ruptured Husky Energy Inc. pipeline spilled more than 220,000 litres of diluted bitumen into the North Saskatchewan River. It has cost the company more than $100 million to clean up the spill, and several communities, including the City of Prince Albert, had to find alternative drinking water supplies. Since 1961, there have been 82 spills from the Trans Mountain pipeline, according Kinder Morgan Canada. Of those spills, 21 were 100 barrels or more of crude; eight were spills of more than 1,000 barrels. Although pipeline oil spills are far more frequent than oil tanker spills at sea, it’s the latter that British Columbians are most concerned about. Spills at sea are much more difficult to clean up, and the environmental impacts can be significant. The number of crude oil tanker spills at sea globally has decreased dramatically, thanks to the Exxon Valdez disaster in 1989 in Alaska. That spill forced governments and the industry to improve safety measures, including
requirements that oil tankers be built with double hulls and guided in and out of ports at low speed with escorts of tugboats. Since the mid-1970s, the amount of oil moved on oil tankers globally has doubled, while the number of spills went down by 98%, Green said. “If you look at tanker safety, what you see is just truly remarkable, actually, improvements in the safety of moving oil by tankers. We have not had a major spill – or even a significant spill – off of Canadian waters for more than 20 years. We know how to do this.” According to Clear Seas for Responsible Marine Shipping, which cites Transport Canada statistics, there are roughly 20,000 oil tanker movements in Canadian waters annually – 17,000 of which (85%) occur on the Atlantic coast. Oil tankers currently represent just 2% of all marine traffic in the Port of Vancouver. That would rise to 14%, however, after the Trans Mountain pipeline expansion. The largest crude oil spill from a tanker in Canada was in 1970 off the coast off Nova Scotia, according to Transport Canada. In 1988, a crude oil barge off the coast of Vancouver Island spilled 87 tonnes of oil. Most of the marine spills in B.C. waters have been petroleum fuel spills, such as marine bunker fuel, not crude oil. —Business in Vancouver
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• PIPELINE NEWS NORTH
AUGUST 18, 2017
INVESTMENTS
AltaGas board chairman David Cornhill, left, and Astomos Energy president Osamu Masuda officially sign a sale and purchase agreement for LPG from the Ridley Island propane export terminal, which is currently under construction.
AltaGas, Astomos sign milestone agreement exporting Canadian propane to Japan CARTER HAYDU August’s agreement between AltGas and Astomos Energy securing a long-term Japanese customer for the Ridley Island propane export terminal was a welcomed “step in the right direction” for the Canadian energy sector, giving hope that other West Coast export projects could follow, says one industry representative. “It is another small step towards some of the bigger [LNG] projects, and having this export and a relationship with Japanese buyers is important,” Patrick Ward, president and chief executive officer of Painted Pony Energy, told the Daily Oil Bulletin following a signing ceremony for the agreement. The Ridley Island terminal is currently under construction. “Hopefully this will help to lift prices, which gives us more cash flow to drill more wells.” The previously announced agreement provides Canadian producers with new access to premium Asian markets for propane. Astomos, which is one of the world’s largest LPG players, will purchase — beginning in Q1 2019 — 50 per cent of the 1.2 million tonnes of propane shipped from the terminal each year. “We could see this growing to $500 million a year in new exports, and that works out to a six to seven per cent increase in exports to Japan,” said David Cornhill, board chairman and founder of AltaGas,. “It is very significant, and we have growth opportunities from that. The key thing for us is getting world price for our products. For Japan, it is about secure, dependable partners who will deliver clean energy to Japan, and clearly that is an opportunity.”
For Osamu Masuda, president of Astomos, the agreement with AltaGas represents a significant milestone for his company, which globally handles more than 10 million tonnes of LPG annually and currently operates a fleet of 21 large gas tanker ships. “I firmly believe this contributes to the stable supply of LPG for a stable energy supply in Japan, and it maximizes the value of the natural gas resources for AltaGas and for Canada,” he said. AltaGas, which announced the project’s final investment decision early this year, has executed long-term agreements securing land tenure along with rail and marine infrastructure on the site near Prince Rupert on a section of land leased by Ridley Terminals Inc. from the Prince Rupert Port Authority. Negotiations entered into with several producers and suppliers underpin much of Ridley Island’s annual expected capacity under tolling arrangements with producers and other suppliers. During the second quarter, global tank storage company Royal Vopak obtained 30-per-cent interest in the LPG terminal, with AltaGas providing construction and operating services. Dan Woznow, vice-president of energy exports at AltaGas, suggested the Astomos deal is an opportunity for Japan to secure energy in a form the Japanese already regularly use in their residences. “Twenty four million homes in Japan use propane for heating and cooking. It is a standard practice there. It is not like over here where we use natural gas,” he said.
For tanker ships, Woznow noted, Japan is only a 10-day voyage from the Prince Rupert area, compared to a 25-day sea trek for vessels leaving from the Gulf Coast. This shorter, safer journey is a major reason for Astomos’s interest in pursuing “maple leaf propane” via the Ridley Island terminal. “This is a pretty great deal, because it shows that when we work together and concentrate on the benefits of what we can bring both to [Japan] and [Canada], we can see how our global community can transport great things that can lead to a better environment, as well as a productive business arrangement,” said Calgary MP Kent Hehr. “This fits squarely with our government’s commitment to find new markets for our energy products in sustainable ways.” Currently, there is a 75-person crew working at the LPG terminal location. Woznow told the signing ceremony that as the project continues moving into its construction phase with different components throughout the next few months, the number of onsite workers will grow. “The tank is coming up out of the ground and it is great to see progress there. We hope by early 2019 to be filling the ships of Astomos to be taking the product from Canada over to Japan.” He added: “We know folks from Japan are saying that things don’t happen fast enough in Canada. Well, we were able to move quickly because of the location. We had a brownfield site because we were able to work with community members to ensure they understood and were supportive of the facility.” —Daily Oil Bulletin
AUGUST 18, 2017
PIPELINE NEWS NORTH •
OUTLOOK
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Horn River challenged as liquids fuel Montney JIM BENTEIN The head of one of Canada’s largest geophysics consulting companies says the decision by Pacific NorthWest LNG (PNW LNG) to not go ahead with its proposed LNG project in Port Edward, British Columbia won’t have an immediate impact on gas drilling activity in the province, but it will inevitably lead to less drilling and development. Brad Hayes, president of Calgarybased Petrel Robertson Consulting Ltd., said activity in parts of the province won’t be significantly affected, particularly the liquids-rich Montney. That’s because operators there, such as Seven Generations Energy Ltd., which have been focused on the Montney and have found markets in Canada, the U.S. and elsewhere for their gas and liquids, have been developing the play without the assumption LNG will go ahead on the West Coast. However, activity in the once hot Horn River Basin and other plays will inevitably slow down, without a large LNG plant to send their production to. “There will still be activity in B.C., particularly in the Montney, because of better economics,” said Hayes. “But in areas like the Horn River, activity will be affected, because it’s further away from markets and it’s dry gas.” Although Crown land sales in the province won’t be directly affected immediately, Hayes said that will happen eventually, as producers face fewer marketing options for their gas. At one point, as many as 20 LNG projects were being proposed for the B.C. coast, which would have created a market for billions of cubic feet of gas daily, but only one small plant is proceeding. Crown sales so far this year in B.C. have been much stronger than last year, driven almost entirely by activity in the Montney. For example, the province brought in $70.28 million for 35,191 hectares for the first six months, compared with just $4.22 million for the same period last year. However, Hayes points out that past land sales in the province, when there was much optimism about LNG plants going ahead, were generating over $1 billion a year. “In 2014, there was a piece of land
in the Montney that went for $100 million,” he said. YOUR COMPANY HAS MET THE Those days are likely long past, he HIGHEST SAFETY STANDARD said, as gas prices stay low and LNG projects aren’t proceeding. However, eventually Hayes does think larger LNG projects will be developed on the B.C. coast. “At some point the world will need that gas,” he said. But he said there could be several years of lower Crown land sales in B.C. and subsequent lower drilling and development activity. Producers will now be focused on the Montney, he said, since it is one of the few plays that is competitive with It’s the ultimate test of safety planning and practices. Benefits: the Permian, the Marcellus and other gas plays in the U.S. Earning a Certificate of Recognition (COR) shows your company commitment · Assistance with audit preparation But because land positions have to safety. Beyond being recognized with WCB incentives and reduced premiums, · Internal Auditor training and COR companies contribute to better safety performance overall and help bring workshops mostly long been established in the workers home safely every day. · Free tools and resources for Montney, there will be no incentive building health and safety programs for much more Crown land buying in Maintaining a level of safety excellence is a coordinated effort. As the Certifying · Ongoing support and advice for the province. Partner for the COR program in the Canadian oil and gas industry, we can help maintaining and renewing your Independent energy consultant you maintain and optimize your COR certification to improve safety performance COR certification in your organization. Bill Gwozd, previously senior vicepresident of Solomon Associates LLC and, prior to that a senior executive Visit www.enform.ca/CORsupport for more information. with the former Ziff EnergyGroup, widely respected for its natural gas expertise, laid the blame for the R0011454088 cancellation on politics. Gwozd went on to point out that the PETRONAS project would have Certified Auditor Ad 1/4 Page July 24.indd 1 2017-07-26 12:48 PM created jobs countrywide, including for shipyards on the east coast and steel mills in Ontario. The consultant, who testified at National Energy Board (NEB) hearings on behalf of PETRONAS, said the project would have created billions of dollars in tax revenues for the B.C. and federal governments. It would also have created thousands of construction jobs. The consultant pointed out that LNG demand worldwide is growing by one-two bcf a day each year, which will lead to the development of several LNG export plants. Finally, he outlined a dark scenario for the economy of northeastern B.C., with the prospect of LNG plants not proceeding. Have a shapes scavenger hunt, taking turns finding shapes “Northeastern B.C. was gearing up indoors and outdoors. Then make each shape with your to move [two-eight bcf per day] of gas, body — kids and adults work together. thus drilling for more gas,” he wrote. “This drilling will automatically How do you learn as a family? Tell us #FamilyLiteracyDay fl come to a complete standstill and service sectors, existing producers LEARN AT PLAY, EVERY DAY. and existing suppliers will surely face Find more ways to learn at play as a family at intense economic pressure.”
Together we can keep it that way
www.FamilyLiteracyDay.ca
—Daily Oil Bulletin
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• PIPELINE NEWS NORTH
AUGUST 18, 2017
IN BRIEF
Montney drilling drives record volumes at Simonette
is pleased with the progress it is making on its growth projects with most of its projects coming in on schedule and under budget, he said.
SemGroup looks to extend Wapiti footprint
Keyera Corp. says it has seen a surge in throughput at its Simonette gas plant, setting a new record in June as producers continue to develop the liquids-rich Montney geological zone. However, throughput volumes were lower at its Strachan and Rimbey gas plants, the company said in reporting second quarter 2017 results. Simonette volumes also will be lower in August as the plant undergoes a 19-day scheduled maintenance turnaround which began this week although to minimize the impact on its customers, Keyera has planned the expected $13 million turnaround to coincide with TransCanada Corporation’s most significant forecast maintenance-related curtailments. The curtailments will affect throughout at several Keyera gas plants on an intermittent basis, said the company. “Keyera recorded solid financial results in the second quarter of 2017 as our integrated feefor-service assets continued to provide a strong foundation for our business,” David Smith, president and chief executive officer, said in a conference call this morning. The company also
With site work underway on the SemCAMS Wapiti Montney sour gas plant, parent SemGroup Corporation is reviewing other pipelines and processing expansions in the region and is considering another new plant to the north, says the company’s chief executive. “If there is ample interest, we envisage constructing a new plant in the 2019-2020 timeframe,” Carlin Conner, president and CEO, said in a conference call to discuss second quarter 2017 results for the Tulsa, Oklahoma-based midstream company. “Projects take a long time up there, especially the permitting,” he said. “Permitting is ongoing and we will hopefully have a FID [final investment decision] sometime in the near future but marketing and permit conditions will obviously dictate that.” In the meantime, growing demand for SemCAMS’s sulphur recovery capacity capability
is driving significant opportunities with wellcapitalized producers, said Conner. “Our SemCAMS team continues to make progress to further commercialization of the previously announced Wapiti sour gas plant.” The Wapiti plant, which will be capable of processing up to 200 mmcf per day of raw sour gas and 20,000 bbls per day of condensate, is expected to cost US$225 million to $250 million and to be in operation in the second half of 2019 (DOB, Oct. 12, 2016). It will use SemCAMS’s existing Wapiti/ Simonette pipeline systems and the Kaybob K3 sour gas plant to process approximately 350 tonnes per day of sulphur. As SemCAMS continues development around its assets, it has increased its anticipated processing volumes by nearly six per cent to between 400 mmcf per day and 420 mmcf per day, Bob Fitzgerald, senior vice-president and chief financial officer, said in the conference call. The increased volumes are due to the aggressive drilling in both the Montney and Duvernay, he said. “We are seeing a lot of volumes coming down our Wapiti pipeline system into K3 and we also are seeing good development around the Duvernay area which is feeding into KA (Kaybob A).” —Daily Oil Bulletin
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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 18, 2017
PIPELINE NEWS NORTH •
IN BRIEF Shell launches methane detection pilot test Shell has launched a methane detector pilot at one of its shale gas sites near Rocky Mountain House in Alberta. The pilot test is part of a wider multistakeholder initiative called the Methane Detectors Challenge, a partnership between Environmental Defense Fund (EDF), oil and gas companies, U.S. government agencies and technology developers to test next generation methane detection technologies. The initiative aims to enable better early detection and repair of methane leaks, and ultimately reduce emissions. While detection technologies and processes are already in place across the oil and gas industry, more technical innovation is desired. “This pilot shows we’re serious about reducing the methane emissions associated with natural gas production to support the overall climate benefit of this fuel,” said Greg Guidry, Executive Vice President Unconventionals, Shell. “Shell is looking at all aspects of its operations, from equipment to processes, to assess and identify emission reduction opportunities.”
Shell is using infrared cameras to scan for methane emissions so that leaks can be repaired. The company announed Aug. 9 it has launched a methane detector pilot at one of its shale gas sites near Rocky Mountain House.
Shell follows global operating principles to develop its shales resources safely and responsibly, and has voluntary leak detection and repair programs across all its shale gas sites. However, the Quanta3 sensing system used in the pilot is a new technology that can continuously monitor methane emissions, unlike handheld optical gas imaging (OGI) cameras.
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Dirk Richter, the Founder and CEO of Quanta3, said: “Our technology provides operators with real time information on the integrity and performance of their sites.” “A new frontier of methane detection is coming, and Shell is helping to give us a glimpse of that future,” said Ben Ratner, Director, EDF. “The ultimate test will be whether the industry scales new tools and approaches to minimize wasteful methane emissions in North America and across the world.” West central Alberta was selected as the location for Shell’s North American detector pilot as it offers the necessary infrastructure to adequately test the technology. Additionally, the cold weather conditions in Alberta provide a unique environment to test the system compared to previous pilots. Depending on the outcome of the pilot, next generation detection technologies could be used to complement OGI cameras and other monitoring tools. These technologies could also have broader applications across the natural gas value chain.
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