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• PIPELINE NEWS NORTH
DECEMBER 22, 2017
Wishing all our members friends and family a Happy Holiday Season and all the best in 2018 Thanks to the Lido and our entertainment committee members for another great function on December 14. Elections were held and results are as follows. Updated members for 2018:
Luc Chretien
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Chris Jorven
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Dustin Stirling
Shane Stirling Keith Rost
Clayton Lingel
Dave Kellestine
Curtis Whitford Carl Lehr
Gordon Westergaard
President
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Vice President
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Director
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Treasurer Director Director Director Director
Director Director
Welcome to neWly elected execUtive members:
Chris Clay
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Director
Dillon Maier
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Director
Mike Friesen
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Secretary
Thanks for commitment to volunteer for a great organization. We also thank those that have stepped down for their commitment and service to the club. Many exciting changes to come in 2018 regarding registrations and payments as well as a commitment to ensuring new life is breathed into the society and events. Have a great Holiday season Oilmen! — Fort St. John Petroleum Association aWards Over the past 20 years, The Fort St. John Petroleum Association has recognized individuals for their efforts and continued support in our endeavours. This year, we are honoured to carry on this tradition. The Ivor MIller AwArd — Trevor Gould The Ivor Miller Award recognizes the effort of an individual and his service to the club. The Fort St John Petroleum Association is first and foremost a social club and we organize activities and social events for our membership to enjoy. We quite often work together but our events are meant and designed to build friendship. Everybody involved in the executive, as well as the event planning, do so on a volunteer basis and do not receive any financial compensation for their efforts. The purpose of this award if to offer recognition and thanks for your service. It Is a privilege to call Mr. Trevor Gould up to the front and receive the Ivor Miller award for 2017. Trevor joined the Fort St. John Petroleum Association in 1985. His oil and gas history includes companies such as Texaco and Suncor. He started working for Crew Energy in 2003 and during that time he also ran and operated his own company.
Throughout his entire working career, Trevor became heavily involved with the Petroleum a Association and partook in all of the events. He has been playing in the golf tournament for 32 straight years, the curling bonspiel for 18 years, hockey for 14 years, the family camp for the past 7 years, and even shot in the trap shoot for 4 years. Trevor’s involvement includes being on the organizing committee for all 14 years
of the Oilmen Hockey. He has played a part since the event was included in the Petroleum Association. His involvement in the golf tournament is just as impressive—he has been on the organizing end for over 10 years and counting. Trevor’s countless hours of dedication to the petroleum association has not been overlooked. We hope that he will continue being involved and many of his peers look up to him for his level of enthusiasm and support.
I must also add that his Oilmen involvement doesn’t stop in Fort St John. He has supported the Fort Nelson Oilmen’s golf, the Dawson Creek and Peace River events as well. oIlMAn of The YeAr — BrIAn SureruS The Oilman of the Year award has been created to offer special recognition to an individual
who not only is a leader in the industry but also a strong and positive influence in the Oil and Gas sector in the Peace Country. The Oilman of the Year must have shown continued support for the area and also contribute to the betterment of our community. This award is not handed out freely and carries with it huge respect and admiration from the entire local Oil and Gas community as well as its workers and families. In 1963, a young man moved from Ontario to pursue the western dream of opportunity by the mountains and ocean of British Columbia. He almost made it.
As dreams go, he ended up in Peace Country to find work on the building of the Bennett Dam as his older brother had. He never took a job at the dam and eventually was provided an opportunity to work as a swamper for an excavating contractor on a local construction project. This experience led him to Fort St. John, where he ran equipment for Al Dubeau and Sons performing maintenance works at the Taylor refinery. Working for someone else did not suit this young 21-year-old, so, in 1969, he traded in his Ford Ranger pick-up for a dump truck and incorporated his first business.
With a reputation for quality work, in 1971 his company was selected to build a small pipeline for Imperial Oil near Fort St. John. This first pipeline was installed by less than 10 men and 4 pieces of equipment, a great deal simpler than today, where he employs more than a thousand people and 400 pieces of equipment during the winter construction season. Through booms and busts, this local businessman has survived, and occasionally thrived, as he focused on installing ever larger and more complicated pipeline projects throughout Western Canada. Always based in Fort St. John, where he has proudly raised five children, built a business and supported our community, I would like to present Brian Surerus as the 2017 Oilman of the Year. —Luc Chretien, President, Fort St. John Petroleum Association
DECEMBER 22, 2017
PIPELINE NEWS NORTH •
COMMUNITY
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Surerus delivers toy donations to community groups
Above: Santa’s—er, the Surerus toy shop. Below: Shelley Van Eindhoven, Bonnie Isenberg, and Jennilee Rennie at city hall, where five blue bins worth of toys were donated to the Salvation Army through the city’s Toys For Tickets campaign.
If there was a pipeline for toys, Fort St. John’s Surerus Pipeline would likely both happily build it and supply it. The company gave a number of youth-based agencies across the city a big boost this week— delivering hundreds of toys to daycares and preschools, including the Child Development Centre, Baby Bear Daycare, Totem Preschool, Community Bridge, and the Friendship Centre, among others. One of the last stops was city hall, where employees Jennilee Rennie and Shelley Van Eindhoven presented a donation to the city’s Toys For Ticket campaign—enough to fill five blue bins—which will go to support families through the
Salvation Army. The company usually sends holiday gift baskets to its clients and vendors this time of year, but company owner Brian Surerus thought he’d spend that money on the community instead, Rennie said. “I was in shock,” said bylaw officer Bonnie Isenberg of the donation to the city’s campaign, noting she was only expecting a few toys. “We’re very fortunate to have Surerus donate these toys to kick off our campaign.” Until Dec. 19, the city is accepting toys or cash donations for those looking to pay off parking tickets received after Sept. 1 of this year.
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• PIPELINE NEWS NORTH
DECEMBER 22, 2017
OUTLOOK
PNN MISSION STATEMENT Our mission at Pipeline News North is to provide the most current, interesting, and relevant news and information about the oil and gas industry in Northeast B.C. and Northwest Alberta. Have an interesting story to share or a news lead? Email us at editor@ahnfsj.ca.
WILLIAM JULIAN REGIONAL MANAGER 250-785-5631 wjulian@ pipelinenewsnorth.ca
ALTAGAS
Construction underway at AltaGas’s Ridley Export Terminal.
10 major Canadian oil and gas projects proceeding in 2018
MATT PREPROST MANAGING EDITOR 250-785-5631 C: 250-271-0724 editor@ ahnfsj.ca
Here’s a selection of major project work underway to produce, transport or add value to Canadian oil and gas in the New Year. Note: This list does not include all Canadian oil and gas projects underway in 2018. 1. TRANS MOUNTAIN PIPELINE EXPANSION
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CONTACT US Phone (250) 785-5631 Fax (250) 785-3522
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Kinder Morgan Canada will spend the first part of 2018 working on permitting to enable full levels of construction spending on the $7.4-billion Trans Mountain Pipeline Expansion project. The 890,000 bbl/d expansion of Trans Mountain service from Alberta to Burnaby was previously expected to begin construction in September 2017 but has encountered challenges receiving required permits. This includes approvals from the City of Burnaby, which the NEB ruled recently are not required in order for the company to being construction work at its export terminals after Kinder Morgan filed a notice of motion and constitutional question. Kinder Morgan has warned of a potential delay to project completion of nine months (to September 2020) due primarily to the time required to file for, process and obtain necessary permits and regulatory approvals. Potential mitigation measures require obtaining greater clarity early in 2018 with respect to key permits, approvals and judicial reviews and continued planning with contractors to assess options to start or accelerate work in certain areas, the company said. 2. INTER PIPELINE HEARTLAND PETROCHEMICAL COMPLEX Inter Pipeline has given the go-ahead for construction of a $3.5-billion petrochemical
facility that will convert approximately 22,000 bbls/d of propane into 525,000 tonnes per year of polymer grade propylene. The Heartland Petrochemical Complex, an integrated propane dehydrogenation (PDH) and polypropylene (PP) plant will receive $200 million in royalty credits awarded through Alberta’s Petrochemical Diversification Program. Inter Pipeline says it has completed early civil work at the site in preparation for facility construction activities in early 2018. the complex is expected to be operational in late 2021. 3. KIRBY NORTH PHASE 1 In November 2016 Canadian Natural Resources became the first company to restart development of an oilsands growth project that was put on hold during the current downturn. Construction is currently underway on the 40,000 bbl/d Kirby North SAGD project, an expansion to the 40,000 bbl/d Kirby South facility, which started operating in late 2013. Kirby North will be targeted to deliver first steam-in in 2019 with first oil targeted in 2020. At the time of restart, Canadian Natural said that approximately $700 million of project capital had been invested to-date, with the remaining project costs targeted to be approximately $650 million, more than $100 million less than originally expected. 4. CENOVUS ENERGY CHRISTINA LAKE PHASE G Construction is currently underway on a project to expand production capacity at Cenovus Energy’s Christina Lake in situ oilsands project from 210,000 to 260,000 bbls/d. Construction on Christina Lake Phase G was restarted in December 2016 after being
DECEMBER 22, 2017
PIPELINE NEWS NORTH •
OUTLOOK
5. IMPERIAL OIL KEARL DEBOTTLENECK Imperial Oil says that in 2018 work will be underway on a $550-million debottleneck project at its Kearl oilsands mine. The $550-million project is expected to increase design capacity of the facility from 220,000 to 240,000 bbls/d. This will be accomplished by adding supplemental crushing capacity to create an offset for when the project has equipment downtime, the company says. 6. ALTAGAS RIDLEY EXPORT TERMINAL AltaGas announced in early 2017 that it would proceed with construction of the Ridley Export Terminal, a project to export propane off Canada’s West Coast. The terminal will be designed to export 1.2 million tonnes of propane per year (roughly 40,000 bbls per day) by the first quarter of 2019.The estimated cost of the project is approximately $450 million to $500 million. The project is supported by an agreement with Japanese LPG shipper Astomos Energy Corporation for the purchase of at least 50 per cent of the available propane annually. 7. PEMBINA NORTH CENTRAL LIQUIDS HUB Pembina Pipeline has sanctioned construction of the North Central Liquids Hub, a $320 million facility to support Montney operations for the Encana/Mitsubishi Cutbank Ridge Partnership. The facility, located near Dawson Creek, BC, is expected to be placed into service in late 2018. It will provide separation and stabilization of increased condensate volumes from the Cutback Ridge Partnership to support the recently in-service Sunrise and Saturn gas plants. Pembina says the North Central Liquids Hub can also be further expanded to serve the future requirements of the companies as well as other potential third-party producers. Additionally, the North Centrals Liquids Hub will be connected into Pembina’s pipeline systems.
8. CHEVRON COMMERCIALIZING THE DUVERNAY Chevron announced in November that it would move ahead with commercial development on its Duvernay shale acreage, six years after commencing exploration activities in the play. The company says the Duvernay — an earlystage liquids rich natural gas resource in westcentral Alberta — is “considered one of the most promising shale opportunities on the continent.” The program will utilize long-term infrastructure development and service agreements with Pembina Pipeline Corporation and Keyera Corporation, with service expected to be available during the second half of 2019, Chevron says. Pembina announced that it will construct and operate $290 million of Duvernay infrastructure under an agreement with Chevron.
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9. PEMBINA PRINCE RUPERT TERMINAL Pembina Pipeline Corporation announced in November it would proceed with construction of the Prince Rupert Terminal, a liquefied petroleum gas (LPG) export facility. The project is expected to have a permitted capacity of approximately 25,000 bbls/d of LPG and is expected to be in service mid2020, subject to Pembina receiving necessary regulatory and environmental approvals. The terminal’s expected capital cost is $250 million to $270 million. LPG supply will primarily be sourced from Pembina’s Redwater fractionation complex in central Alberta. 10. TIDEWATER MIDSTREAM MONTNEY LIQUIDS PLANT Tidewater Midstream announced in November that it would proceed with a new gas plant near Grande Prairie, Alta. with processing capacity that is tailored for the region’s liquidsrich Montney natural gas production. The project has an estimated capital cost of approximately $210 million. Located in the Pipestone area, the 100 MMcf/d sour gas plant will have acid gas injection and 20,000 bbls/d of NGL processing capability, as well as an extensive gathering pipeline network, the company says. Operations are targeted to start up in mid-2019. —JWN Energy
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suspended in late 2014 due to the oil price collapse. The company expects the capital cost of the project to be 50 percent less than the last expansion of Christina Lake, Phase F, with a goforward estimate of between $650 million and $700 million. First oil is expected in the second half of 2019.
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• PIPELINE NEWS NORTH
DECEMBER 22, 2017
OUTLOOK
B.C. hauls in $173M at 2017 land sales It was a modest end to the 2017 B.C. land sale schedule Dec. 13, which was not indicative of the overall yearly performance for the natural gas producing province. Bonus revenue rebounded strongly this year after a difficult two years, including a record low in 2016. The December sale generated $882,835 in bonus bids on 5,665 hectares at an average price of $155.84. For the year, the province earned $173.25 million on 79,238 hectares at an average price of $2,186.49. This was a rebound year for B.C. after the record low of $15.19 million in 2016. Two sales were largely responsible for the large jump in bonus bids this year. The province started the year with a bang—the first land sale of 2017 produced $39.62 million in bonus bids, driven by a $35.13-million licence in Northeast B.C. prospective for the Montney east of Dawson Creek. Meanwhile, a large $77-million parcel highlighted the province’s July sale. That high-priced drilling licence at Inga east of the Montney production at Altares, was picked up by Scott Land & Lease Ltd., which paid an average price of $13,893.90 per hectare for the 5,542-hectare parcel.
Alberta nets $556 million
The Alberta government held its final land sale of the year on Dec. 20, bringing in $18.6 million in bonus bids. Industry picked up 73,639 hectares at an average price of $252.61 The province ended the year with $556.39 million in bonus bids on 1.48 million hectares at an average price of $374.91. “Regarding land sales in general for 2017, we did see a rebound from 2016, and in general much better prices than we were expecting,” noted Brad Hayes, president of Petrel Robertson Consulting Ltd. “However, most of the money was spent on the emerging Duvernay East Shale Basin play — a ‘new’ shale oil fairway, in the sense that industry appreciated its economic potential only recently.” —Daily Oil Bulletin
ENRBIDGE
Enbridge CEO Al Monaco.
Enbridge to monetize $3 billion in gas, renewables assets in 2018 Enbridge says it has identified $10 billion in non-core assets to sell or monetize now that the assets from its merger with Spectra Energy earlier this year are well understood. At least $3 billion of this will occur in 2018, the company said in a statement. Certain unregulated gas midstream and onshore renewables businesses will be sold or monetized next year, CEO Al Monaco said.
“We will rationalize our asset mix to a pure regulated pipeline and utility business model, which emphasizes low risk businesses and strong growth in our three crown jewel businesses: liquids pipelines and terminals, natural gas transmission and storage and natural gas utilities,” he said. According to Peters & Co., these assets could include portions of the Spectra Canada assets, Enbridge
wholly-owned assets such as the Tupper and Cabin gas plants, DCP Midstream ownership, Midcoast Energy Partners assets and onshore renewables both in Canada and the United States. Enbridge expects to deliver approximately $12 billion in new capital projects in 2017, with a remaining $22-billion capital program to execute through 2020. —JWN Energy
Sanjel Energy Services announces new president, remediation business line Sanjel Energy Services vicepresident of sales and marketing Murray Bickley has been appointed the company’s president. He will lead strategic initiatives, including the company’s new remediation business line. Shane Hooker will remain CEO, responsible for maximizing value and the company’s overall growth strategy. Sanjel says the remediation business line will focus on well abandonment, integrity, gas migration, acidizing and miscellaneous pumping operations. Sanjel Energy Services was formed in June 2016 as a new entity with a historic name and established leadership team after
Sanjel Corporation sought creditor protection after 34 years in business. Hooker and Bickley were among the original leaders of the new company, which in the year following inception successfully completed more than 4,500 service jobs. “I’m very excited to assume this new role and lead the company’s operations and our new remediation business line,” Bickley said in a statement. “As an experienced team, we have consistently proven our ability to provide the highest quality cementing and acidizing products and services, and we can now apply our knowledge and technology to the remediation business.” —JWN Energy
DECEMBER 22, 2017
PIPELINE NEWS NORTH •
OUTLOOK
7
SUBMITTED
CJ Ritchie, assistant deputy minister at B.C.’s Ministry of Jobs, Trade and Technology, during her November 29 speech at the Naturally Resourceful event hosted by Resource Works.
B.C lays out vision linking tech, natural resources More collaboration sought as O&G spends $1B annually on R&D TYLER ORTON Business in Vancouver
The future of the B.C. economy will not be a story of the nascent tech sector replacing the natural resources sector, one of the province’s top bureaucrats says. Speaking at the Naturally Resourceful event in Vancouver on Nov. 29, CJ Ritchie, an assistant deputy minister at the Ministry of Jobs, Trade and Technology, outlined the government’s preliminary vision for economic links between technology and natural resources. “There’s a perception that the natural resource sector is an industry of the past and that somehow tech and innovation or clean tech is an industry of the future,” Ritchie said. “The natural resource sector is critical to sustainability and prosperity for the economy of B.C.” Global recognition of the need to shift to a low-carbon economy has drummed up interest in clean technology, such as solar power and zero-emission vehicles, Ritchie added. And the manufacturing of those technologies will require metals, such as copper and zinc, that are abundant in B.C. mines, she said. “The demand for those metals in clean technology is really driving a new kind of interest and a new kind of demand in the clean tech industry,” she said. Ritchie went on to present data from Statistics
Canada showing that for every 100 direct jobs created in mining, 121 indirect jobs are created. And for every 100 direct jobs created in technology services, 28 indirect jobs are created. Meanwhile, the average weekly salary for mining, oil and gas workers is $1,796, while the average weekly salary for tech workers is $1,590. Resource Works, a non-profit organization researching and promoting the importance of natural resources in the B.C. economy, facilitated the Naturally Resourceful event. Executive Director Stewart Muir said his organization wanted to counter perceptions that technology would simply replace natural resources in the economy. B.C. has long been at the forefront of ecological awareness and environmental regulation, which means “companies who need to succeed here have had to invest in innovation,” Muir said. Firms specializing in satellites, drones, filtration and other technologies used by the natural resource sector account for about 200 small and medium-sized enterprises across the province, he said. But Ritchie cautioned that the province must consider the potential negative effects of the tech sector, specifically singling out automation and self-driving vehicles. While autonomous vehicles will create more efficiency moving goods and people, the assistant deputy minister said it could also have
“some short-term impacts and job losses for taxi drivers, bus drivers and first responders.” U.S.-based ride-hailing services Uber and Lyft are pursuing driverless vehicle technology, but various levels of government have stymied their entries into the B.C. market. After making a campaign promise to introduce ride—hailing services this year, the BC NDP government put that decision on hold in October. Instead, the province ordered a consultation with the taxi industry with a report to follow in early 2018. Joy Romero, vice-president of technology at Canadian Natural Resources Ltd., followed Ritchie’s address by pushing for more collaboration between universities, the tech sector, and energy companies to reduce the carbon footprint of fossil fuels. She estimated the oil and gas industry is now spending $1.3 billion annually on research and development to increase its productivity and reduce its carbon footprint. But when travelling across Canada, Romero said she has repeatedly come across experts who have independently discovered the same breakthroughs as researchers they are not collaborating with. “We do not have the time or the capacity as a country to have that kind of waste of our intellectual capital nor our finances,” she said.
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• PIPELINE NEWS NORTH
DECEMBER 22, 2017
ENVIRONMENT
Ottawa kicks in $3.5 million to support Calgary companies promoting clean tech Research institutions and firms developing potentially ground-breaking clean technologies and processes in the Calgary area have received $3.5 million from the federally run Western Economic Diversification Canada. Five of the projects are focused on developing emissions reduction technologies and three are forums that promote Canadian clean technology companies at high-profile events. Through the Pan-Canadian Framework on Clean Growth and Climate Change, Canada will focus on creating and maintaining globally competitive Canadian businesses as it transitions to a low-carbon economy, Western Economic Diversification said in a statement. The global campaign against climate change is an economic opportunity to create jobs and meet the country’s climate change goals, it said. The University of Calgary was the recipient of funding for two new projects. The first collected $400,000 to establish the Centre for Smart Emissions Sensing Technologies, which will result in the development of smart technologies to detect and quantify methane emissions in the oil and gas sector. The second project was granted $314,500 to create an outdoor validation facility for demonstrating solar biotechnology that will produce renewable gas, renewable plastic, biochar and electricity. Tecterra Inc., received $915,000 to invest in new equipment to expand GeoSpace, which will help companies to develop, test and commercialize clean, geospatial technology. GeoSpace is an equipment library open to tech companies for the development, testing and commercialization of geospatially powered clean-tech. “We are grateful for this continued support, as access to cutting-edge equipment has proven to be extremely valuable for the small and innovative companies who otherwise couldn’t access the tools they need,” said Jonathan Neufeld, Tecterra chief executive officer. “As a result of this support, companies across the West will be able to accelerate the development and commercial success of their clean-tech.” Other projects funded are as follows: CMC Research Institutes Inc. received $974,000 to support the development of technology for methane emissions monitoring in water, soil and the atmosphere. The project will improve emission detection accuracy and provide industry with sensitive tools that will aid in better understanding and reacting to methane emissions. Petroleum Technology Alliance Canada collected $393,000 to build and deploy a mobile facility, called the Centre for the Demonstration of Emissions Reductions (CeDER), which will field test methane emissions reduction technologies. CapitalRoad Foundation received $228,000 to support hosting the Canadian Financing Forum, PROPEL Energy Tech Forum, and the Banff Venture Forum from 2018 to 2020. The forums provide clean technology companies an opportunity to showcase their products and services and find investors. Alberta Clean Technology Industry Alliance was granted $190,000 to support its industry-focused events in 20172019, fostering access to services and programs, activating international opportunities and promoting Western Canada as a global clean tech destination. Canadian Global Exploration Forum received $70,906 to support the showcasing of Western Canadian clean technology innovators at the Global Petroleum Show 2017, CGEF’s annual conference 2017, and the Global Petroleum Show 2018. —JWN Energy
GOVERNMENT OF ALBERTA
Funding announcement with Deron Bilous, Minister of Economic Development and Trade, Marg McCuaigBoyd, Minister of Energy, Shannon Phillips, Minister of Environment and Parks, and David MacLean, VP Canadian Manufacturers and Exporters.
Alberta launches $1.4 billion fund to reduce emissions DEBORAH JAREMKO JWN Energy
The Government of Alberta says that a new $1.4-billion investment to reduce emissions from oil and gas and electricity follows the example set by one of the most successful innovation programs in the province’s history. The program, announced on Dec. 5, will provide $440 million for oilsands innovation, $225 million for R&D across sectors, $240 million for industrial energy efficiency projects, $63 million in grants for bioenergy and $400 million in loan guarantees to reduce risk for financial institutions. “These investments build on the legacy of former premier Peter Lougheed’s support for innovation and technology that helped develop steam assisted gravity [drainage] access to oilsands without excavation or tailings ponds,” the province said in a statement, referencing the Alberta Oil Sands Technology and Research Authority (AOSTRA), which proved the viability of SAGD in the 1980s and changed the trajectory of the oilsands towards exponential growth. “The new funds will extend that legacy to the next generation of technology,” the statement said. An announcement is coming later this week about the rules governing large emitters, the province said, resulting in changes that “update and upgrade facilities and processes,” the province said.
“For some oilsands companies, making these changes will take time and the government is helping companies adjust through the oilsands innovation fund. Funding will start at $40 million a year in 2019-20, rising to $80 million in 2020-21 through 2024-25.” Alberta is also giving $80 million to Emissions Reduction Alberta in a continuation of funding for innovation grants and spending $145 million to create the new Climate Change Innovation and Technology Framework to manage government investments in these projects. The bulk of the funding comes levies paid by large Alberta emitters. While the environmental Pembina Institute praised the investment, it urged the government to pursue zero-carbon versus lower-carbon technologies. “It will be important to ensure dollars for oilsands innovation are invested in truly innovative technology, rather than incremental improvements.” Duncan Kenyon, Pembina’s responsible fossil fuels director, said in a statement. “We are glad to see the Government of Alberta using revenue generated by the Climate Leadership Plan to drive clean technology innovation and deployment. “Energy efficiency is a low-hanging fruit for emissions reductions and innovation but it is critically under-utilized. We are pleased to see support for energy efficiency in the form of loans, as this is a proven low-cost way to deploy energy efficiency at scale.”
DECEMBER 22, 2017
PIPELINE NEWS NORTH •
LNG
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Canada’s first LNG shipment arrives in China Canada’s first liquefied natural gas shipment to China arrived in the country Dec. 14. The 950-gigajoule shipment left FortisBC’s Tilbury facility on Nov. 18, travelling more than 9,000 kilometres to its destination. “It is just the beginning of the golden age of natural gas,” Calvin Xu, CEO of True North Energy, which oversaw the logistics of the shipment, said. “There are still huge opportunities for BC to supply LNG to China.” True North partnered with China-based CIMC ENRIC Holdings Limited and FortisBC on the shipment. The LNG was shipped in a single intermodal container and bypassed receiving LNG terminals and regasification plants—a route less travelled, according to the companies, one that reduced cost and infrastructure constraints of shipping by a conventional LNG tanker. “The main advantage of shipping LNG by ISO containers is high flexibility,” Xu said. “Instead of relying on dedicated LNG carriers, exporting and receiving terminals, ISO containers enable us to utilize existing container ports, ships, trucks and rails to transport the LNG.” Fortis BC announced the shipment Nov. 22, saying it tests the business case for expanding and delivering future shipments. “It’s a pilot to test out the viability of all the logistics and the timing and costs of getting it there and then see if it can build into something larger,” said Doug Stout, FortisBC’s vice president of market development and external relations. FortisBC supplied the gas through its Tilbury facility in Delta, in operation since 1971 and in the midst of a $400-million expansion. To put the shipment into perspective, the average Vancouver home uses about 90 gigajoules of gas per year, according to the company. B.C. Energy Minister Michelle Mungall said she was pleased to see the first shipment be delivered. “The opportunities for good jobs as we reduce carbon emissions in the transition to
KBR selected to carryout Pre-NTP services for Woodfibre LNG KBR Inc. has been selected to carryout prenotice to proceed (pre-NTP) services for the Woodfibre liquefied natural gas project. The Woodfibre LNG Project is located in the District of Squamish near Vancouver and is licensed to export approximately 2.1 mtpa of LNG for 40 years. The selection of KBR for pre-NTP services follows the successful completion of a competitive front end engineering design (FEED) process for Woodfibre LNG, which was announced in October 2016. Pre-NTP services will be carried out by KBR’s operating centers in Houston and Edmonton. The services include additional
FORTIS BC
Filling Canada’s first liquefied natural gas shipment to China on Nov. 18. FortisBC supplied the gas through its Tilbury facility in Delta. True North Energy Corporation and CIMC ENRIC Holdings Limited provided logistics and equipment for the shipment.
cleaner fuels is just getting started,” Mungall said in a statement. Bob Zimmer, the federal MP for Prince George-Peace-River-Northern Rockies, applauded the shipment as an important first step forward for B.C.’s LNG export industry, which has struggled to get off the ground. Not one of the 20 LNG projects proposed for B.C. has been built, and Tilbury is the only functioning plant in the province. “Many British Columbians have waiting many years to see this day come to fruition,” Zimmer said in a statement. “Although the industry has a long way to go, this is a great day for all those who have so worked hard to make LNG exports to Asia a reality.” The Tilbury plant was used in the past to produce LNG strictly for backup purposes, in the event of an interruption of gas on its pipelines. But the company invested $400 million in an expansion that takes the plant FEED work and cost optimization as well as a proposal for an engineering, procurement and construction (EPC) contract. Woodfibre LNG expects to commence the EPC phase of the project in 2018. “The successful completion of FEED and now the selection of KBR to carryout pre-NTP services are all important steps in moving the Woodfibre LNG project forward,” said Byng Giraud, vicepresident of corporate affairs for Woodfibre LNG Limited, the privately held Canadian company behind the project. “We look forward to reaching our next project development milestone – the awarding of an EPC contract in 2018.” KBR has designed or constructed over 30 different liquefaction projects across the globe.
from a production capacity of 5,000 gigajoules per day to 39,000. Although the expansion was intended mostly to serve a growing domestic LNG market—in the trucking sector, for example—FortisBC has also had an eye to potential small-scale exports. FortisBC is also considering additional expansions, including a doubling of the Tilbury’s capacity and possibly a larger new plant, about the size of the planned Woodfibre LNG plant in Squamish, at a cost of $1 billion to $2 billion and annual capacity of 1 million to 2 million tonnes per year. Whereas larger LNG plants would supply LNG on long-term contract basis to large utilities in Asia, FortisBC is targeting small commercial and industrial complexes in China, many of which still use coal or oil-fired heating systems. “This is replacing coal and oil with natural gas,” Stout said.
Malahat LNG project scrapped The Malahat Nation and Steelhead LNG are no longer exploring the possibility of a liquefied natural gas project in the Saanich Inlet. Plans had called for construction of a floating liquefaction production and export facility at a 525-hectare site on Bamberton industrial land owned by the Malahat Nation. “Steelhead LNG made the decision after careful consideration and based on several factors as we look to develop a project that delivers low-cost LNG that is globally competitive,” says a statement. Steelhead LNG is continuing to explore its Kwispaa LNG project, formerly known as Sarita LNG, in partnership with the Huu-ay-aht First Nations.
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• PIPELINE NEWS NORTH
DECEMBER 22, 2017
OPERATIONS AltaGas completes North Pine liquids plant ahead of schedule, turns focus to propane terminal DEBORAH JAREMKO JWN Energy
The 10,000-bbl/d North Pine NGL separation facility near Fort St. John, BC is now up and running, months before its original schedule thanks to construction progressing faster than expected. AltaGas says the project, which has Painted Pony Energy as its anchor customer, was completed approximately $15 million under its budget, coming in at $120 million. With the North Pine facility complete, the company will now turn its capital spending to focus on its Ridley Island Propane Export Terminal in its focus to provide “a broad suite of midstream services and new market diversification,” CEO David Harris said in a statement. AltaGas said the terminal is also currently ahead of schedule and under budget. The company plans a capital program of $400 million to $500 million in 2018, not including spend related to the company’s $8.4 billion acquisition of Washington,
DC-based utility WGL Holdings, which is moving through the regulatory process. Investment next year will focus on the Ridley Island terminal, AltaGas said. Overall, spend will be directed up to 65 percent to its gas business and up to 35 percent to its utilities business, with remaining dollars going to its power business. Capital investment in 2018 will increase substantially following a successful close of the WGL deal. “The consolidated 2018 capital program for AltaGas and WGL on a combined basis, assuming a Q2/2018, closing is expected to be in the range of approximately $1.2 $1.5 billion. Close to half of this total will be allocated to Gas, with the majority of the remaining expected capital for Utilities, followed by Power,” the company said. AltaGas expects that the largest portion of WGL’s total 2018 capital program will be allocated to investments in the Central Penn and Mountain Valley gas pipeline developments in the Marcellus region.
Kinder Morgan squeezed as Trans Mountain expansion hits delay DEBORAH JAREMKO JWN Energy
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It’s another month of not enough space on the existing Trans Mountain Pipeline from Edmonton to Burnaby as permitting issues delay construction of its expansion. As lawyers stood last month before the National Energy Board arguing whether Kinder Morgan should be able to bypass the City of Burnaby’s regulatory process to start the build, some producers looking to ship on the existing system were out of luck. The pipeline, which has been operating since the 1950s, is oversubscribed by 23 percent overall for the month of December, Kinder Morgan reported to the Daily Oil Bulletin. The pipeline will ship 309,604 bbls/d for December, including 78,917 bbls/d to the Westridge Dock
for export. The overbook is not an unusual situation – according to DOB records this has occured throughout 2017. According to the National Energy Board, which notes that Trans Mountain capacity varies depending on the proportion of heavy and light crude transported, capacity on the pipeline is 300,000 bbls/d assuming 20 percent of the oil in the pipeline is heavy. NEB data show that Trans Mountain utilization averaged 105 percent in 2015. After receiving federal approval to proceed with the 890,000 bbl/d Trans Mountain Expansion project, Kinder Morgan gave it the corporate green light in May 2017, expecting construction to begin in September. The company has now pushed that into next year, anticipating that “the first part of 2018” will be spent working on permitting.
DECEMBER 22, 2017
PIPELINE NEWS NORTH •
POLITICS
11
Notley greeted in Vancouver with applause and protest NELSON BENNETT Business in Vancouver
Under normal circumstances, an NDP premier from Alberta – especially one who worked as a staffer, alongside John Horgan, for the Glen Clark NDP government – might expect to feel welcome in a province that is also now governed by an NDP government. But Rachel Notley’s visit to Vancouver November 30 was marked by crowd of protesters outside the Fairmont Waterfront Hotel, where she was speaking, and a conspicuous lack of representation by B.C.’s NDP government in the audience when she spoke to the Greater Vancouver Board of Trade (GVBOT). Notley and federal Natural Resources Minister Jim Carr were in Vancouver to speak about the importance of both climate change policies and oil pipelines, the latter of which makes Notley persona non grata for the B.C. NDP government, and the mayors of Vancouver and Burnaby. Although the Trudeau government approved both the Trans Mountain pipeline and Line 3 pipeline expansions – while simultaneously killing the Northern Gateway pipeline – some have questioned the federal government’s resolve in seeing them built. The $7.4 billion Trans Mountain pipeline project is now nine months behind schedule, thanks to delays in getting permits – the City of Burnaby being the biggest foot-dragger. Carr made it clear his government intends to see both pipelines built. “These new pipelines will diversify our markets, be built with improved environmental safety, and create thousands of good-paying middle-class jobs, including in indigenous communities,” Carr said. “They were the right decisions then, and they are the right decisions now. Our government wants to see them built.” But there has been a tacit agreement between Ottawa and Alberta that support for Canada’s energy sector must be balanced against the need for effective climate change policies – something some view as incompatible. Alberta contributes a disproportionately large amount of greenhouse gases to Canada’s carbon profile, thanks to its oil sands. It also contributes disproportionately to Canada’s economy. In terms of transfers, Alberta annually contributes $22 billion more than it gets back from Ottawa, Notley said. In 2014, before the oil price crash, 44,000 British Columbians worked in Alberta, Notley added. “Alberta’s energy industry is a dominant part of what makes Canada tick,” Notley said. “There is not a school, there is not a hospital, there is not bus, a road, a bike lane or a port that doesn’t owe something to the strong energy industry in the province of Alberta,” she said, to applause. But she acknowledged that, for too long, Alberta has failed to act on mitigating the impacts on the climate both from its oil sands and its reliance on coal for power generation – something her government is trying to correct with an ambitious climate change plan that includes carbon taxes, a cap on oil sands emissions, a plan to phase out coal power by 2030 and investments in renewable energy. “When we are done, we will have made good on one of the most dramatic clean energy conversions anywhere in the world,” she said, adding that Alberta’s is now “one of North America’s hottest renewable energy markets.” “Albertans took this step because, as Canada’s largest energy producer, we know that we have a unique responsibility to tackle climate change,” Notley said. “And we know that any climate action plan that doesn’t include Alberta, frankly, is not a plan. It won’t work.” But she also warned that Alberta cannot finance such a massive transition without a strong economy. “Alberta cannot fund the transition to a greener, lower carbon future if our economy is held hostage by geography,” she said, referring to the need to get Alberta oil to foreign markets via B.C. Earlier in the week, at the Clean Energy BC’s Generate 2017 conference, Dave Nikolejsin, B.C.’s deputy minister of Energy, Mines and Petroleum Resources, spoke of the potential for B.C. to help Alberta in its energy transition.
GOVERNMENT OF ALBERTA
Alberta Premier Rachel Notley was in Vancouver Thursday, November 30 speaking to the Greater Vancouver Board of Trade about climate change policies, energy transitions and pipeline politics.
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• PIPELINE NEWS NORTH
DECEMBER 22, 2017
INVESTMENTS
PEMBINA PIPELINE CORP
Construction at Pembina’s RFS II site.
Pembina Pipeline Corp. approves new Montney liquids hub, Prince Rupert LPG terminal Pembina Pipeline Corporation has approved the development of a new liquids hub in the Montney, as well as its proposed liquefied petroleum gas export terminal in Prince Rupert. The two new projects are part of a $1.3-billion capital program for 2018 approved by the company’s board of directors and announced Nov. 29. Pembina President and CEO Mick Dilger called 2017 a “transitional year” in the company’s history. “Since the beginning of 2015, we have placed approximately $8 billion of predominately contracted assets into service, marking the culmination of an unprecedented growth strategy implemented in 2013,” Dilger said in a statement. “In addition, we also completed the largest corporate acquisition of our company’s history during the year. We expect to continue this positive momentum into 2018, as we remain focused on completing the remaining growth portfolio and advancing our strategy of creating new market access for our customers. With increased size and scale, greater diversification and a broader service offering, the future is bright for Pembina.”
NORTH CENTRAL LIQUIDS HUB The estimated $320-million hub ($150 million net to Pembina) will support operations for the Cutbank Ridge Partnership in the Montney, providing separation and stabilization of increased condensate volumes from the partnership to support the recently in-service Sunrise and Saturn gas plants in the South Peace. The project, expected to be in service in late 2018, is being advanced through Pembina’s midstream limited partnership with Kohlberg Kravis Roberts & Co. L.P., in which Pembina owns approximately a 46 per cent interest, the company said. The hub will be connected into Pembina’s pipeline systems, and can be further expanded to serve future requirements of the Cutbank Ridge Partnership, as well as other potential third-party producers. PRINCE RUPERT LPG TERMINAL The estimated $250- to $270-million Prince Rupert terminal will be sited on Watson Island, on lands leased from a wholly-owned subsidiary of the city of Prince Rupert, the company said.
The terminal is subject to regulatory and environmental approvals. It is expected to have a capacity of 25,000 barrels per day of liquefied petroleum gas, and to be in service by mid2020. Pembina says it has executed definitive commercial agreements with the city, and will source its LPG supply from its Redwater fractionation complex in Alberta. “Since our initial announcement of potentially developing the Prince Rupert Terminal, we’ve worked diligently with municipal and other stakeholders and are now able to move forward with our final investment decision,” Stuart Taylor, Pembina’s Senior Vice President, NGL & Natural Gas Facilities, said in a statement. “We are very excited to progress the Prince Rupert Terminal and continue working with the local communities, stakeholders, First Nations and governments in the area. “This Project will provide significant economic benefits to thePrince Rupert area including 150 to 200 construction positions and, once operational, it will create between 20 to 30 full-time positions in addition to generating annual property tax revenue and lease payments.”
DECEMBER 22, 2017
PIPELINE NEWS NORTH •
INVESTMENTS
13
B.C. plummets in Global Petroleum Survey “Political instability” in British Columbia since the May provincial election has caused the province’s ranking in terms of attractiveness for oil and gas investment to plunge, according to the Fraser Institute in its annual Global Petroleum Survey. B.C. fell from 39th place out of 96 jurisdictions last year to 76th out of 97 in 2017. “Investor confidence matters, and having a government that’s openly hostile to resource development has apparently sent a chill throughout the oil and gas industry,” said
Kenneth Green, senior director of the Fraser Institute’s Centre for Natural Resources. Some of the comments from investors surveyed for the study included: “Regulatory uncertainty and prohibitive timelines are detrimental to the approval process for major energy projects such as Kinder Morgan’s Trans Mountain Pipeline and Northern Gateway;” and “Not only has B.C. been unable to build pipelines, but it has also failed to develop its LNG industry, and this is a major deterrent to
investment.” Other issues of concern in B.C., according to the study, are disputed land claims and protected areas. According to the study, Newfoundland and Labrador has the most investment-friendly climate in Canada; that province increased in ranking from 25th of 96 last year to 4th of 97. One of the reasons for the increase in attractiveness in this region related to a decrease in regulatory duplication and inconsistencies. —Business in Vancouver
November saw $976M in new Cdn upstream deals Canada saw less than C$1 billion in new upstream M&A activity for the first time in three months according to the latest review from CanOils. November’s total of C$976 million represents a significant fall of 46 per cent and 39 per cent, respectively, from totals witnessed in September and October.
The single largest deal in November was another asset sale by Cenovus Energy. The company agreed to sell its Weyburn unit in Saskatchewan to Whitecap Resources, in so doing reaching a major debt milestone related to its C$17.7 billion acquisition from ConocoPhillips. This month also saw Pengrowth Energy continue its asset sales program in Alberta,
completing a C$150 million deal in Swan Hills and agreeing another minor deal in Quirk Creek. The company will focus its efforts on two assets going forward – thermal oil production at Lindbergh and Montney gas at Groundbirch. November saw almost 28,000 boe/d put up for sale in new public asset listings. —JWN Energy
Black Diamond opens new workforce lodge A new workforce lodge has opened in the heart of the Montney liquids-rich natural gas play in another sign of stronger development activity. Black Diamond Group started housing customers at the new Little Prairie Lodge in Chetwynd, BC in November. With the opening of the new 252-person facility, Black Diamond says it now has over 2,500 rooms operating in the Montney and Duvernay plays in northwest Alberta and northeast BC. The property is being operated through Black Diamond Cygnus, a partnership between the company and the West Moberly First Nations, on whose traditional land the facility is located. Growing interest in Canada’s liquids-rich natural gas resources, primarily focused in the Montney play, was a key factor that led the Petroleum Services Association of Canada to increase its 2018 drilling forecast to 7,900 wells, up from 7,550 wells expected in 2017.
BLACK DIAMOND GROUP
The new Little Prairie Lodge.
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• PIPELINE NEWS NORTH
DECEMBER 22, 2017
COMMUNITY
Doig, Clean Harbors partner to tackle holiday hunger
From left: Shawn Doré, Cameron Eggie, Gerry Attachie, Kevin Emes, Chief Trevor Makadahay, Kelvin Davis Jr., Tatjana Eggie, Christina Redgun, and young Kelvin Davis III.
The Doig River First Nation and Clean Harbors Canada are wishing a Merry Christmas and happy, healthy New Year to families in need this holiday season. The First Nation and company partnered up to donate and deliver 40 whole turkeys and $1,000 cash to the Salvation Army on Dec. 18. That’s good news for the agency, which is expecting to help at least 134 families this year, but only had 100 turkeys to hand out. “Now no one on Wednesday is going without a turkey,” executive director Cameron Eggie said. “We would have had to buy the extras, so when the call came through it was awesome.” Clean Harbors donated 40
turkeys to Doig last year as part of its working relationship with the band and its work in Doig’s traditional territory. When the company suggested doing the same this year, Chief Trevor Makadahay suggested paying it foward to the Salvation Army instead. “We we more than happy to do that,” said Kevin Emes, the company’s community engagement lead. Doig topped up the turkeys with the $1,000 donation. “It’s in our culture to share as much as we can,” Makadahay said. “Hopefully other communities will see this and it sparks them to give, too.”
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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.
DECEMBER 22, 2017
PIPELINE NEWS NORTH •
IN BRIEF
15
PSAC on the hunt for new CEO as Mark Salkeld resigns The Petroleum Services Association of Canada (PSAC) announced that is looking for a new president and CEO. Mark Salkeld, who has led the organization since November 2010, is resigning effective March 15, 2018. He will move into a new role as vice-president of operations and business development for CLEANTEK Industries, a developer of systems for wastewater management and solar-hybrid lighting and power for off-grid operations. PSAC said in a statement that the petroleum services, supply and manufacturing sectors are looking forward to more certain times following the past two challenging years. “We will need another strong leader that will be able to steer the association on the path we now find ourselves and the
changing landscape in which we operate,” said PSAC chair Scott Van Vliet, CEO and founder of Environmental Refuelling Systems Inc. “Mark has delivered tremendous value to our members, including spearheading a review of membership types which now extends to companies in the alternative energy space. He supported the development of an effective government relations program ensuring PSAC’s voice was at the table on major policy issues across all levels of government. He also helped to guide the organizations on major public outreach efforts and build out the association’s role in addressing a myriad of issues from health and safety to labour pool development.” PSAC’s executive search will be led by past chair Doug McNeill. —JWN Energy
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DECEMBER 22, 2017
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