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Athabascu U: The hallmark of Ken Hutchinson

A passionate artist and architect, dedicated leader, community advocate, volunteer, philanthropist, devoted husband, dad, activist, and stalwart champion of the ‘underdog.’

This, is the lengthy legacy of Alberta ‘star’ architect, Ken Hutchinson — whose imprint will continue to transform the lives of Canadians, AU learners, and his beloved family, through his positive “glass half-full outlook on life.”

While the AU community has had much to celebrate this year, unfortunately, we have seen an inordinate amount of sadness as well. Today, is no exception, as we share the news of the passing, in Calgary, on April 14th, of Ken Hutchinson, a prominent Alberta architect, and yet another extraordinary member of the AU community.

Soon after moving to the Calgary area from his native Red Deer, Hutchinson built a prolific career as an architect, wielding tremendous design influence throughout Western Canada, with the hundreds of buildings fashioned and erected from his blueprints.

From schools and theatres to recreational centres, libraries, and fire halls throughout Alberta, B.C., and Saskatchewan, some of Hutchinson’s most iconic designs included the Saamis Teepee in Medicine Hat, Alta. (pictured to the right), the Westside Recreation Centre in Calgary, the Calgary Real Estate Board headquarters, the MacKenzie Towne Fire Hall, and, according to his obituary “the project closest to his heart,” the Hobbema Healing Lodge (PêSâkâstêw Centre) in Maskwacis.

Consummate ‘Communitarian’

Hutchinson was a Paul Harris Fellow, reserved for supporters of the Rotary Foundation of Rotary,a past president and lifetime member of the Alberta Association of Architects, and in 2010, he was inducted into the Royal Architectural Institute of Canada. While regarded a pillar among his architecture peers in Western Canada, his bearings ran even deeper into the communities he valued and served, and from which he helped others to plant the seedlings for their own successes.

With a life’s mission devoted to service, and the contribution for a “better Alberta,” Hutchinson’s immeasurable philanthropy and penchant for making a difference, paved numerous pathways, transforming the lives of the many people and organizations with whom he connected.

His brilliant and creative design mind, coupled with an unwavering spirit of benevolence, resulted in the crafting of some enormous opportunities for those fortunate enough to cross Ken’s path — or even, indirectly, to connect with some small tendril of his kindness (even though he stood 6 feet, 7 inches tall!)

Yet, while his many Canadian communities, and architecture ‘family’ will mourn his passing, at the age of 74, after a lengthy illness, Hutchinson’s impact and influence will not soon be forgotten.

“Those who loved and admired Ken will greatly miss him as a pillar of generosity. He created a vibrant legacy of a life well-lived,” said Athabasca University Board Chair Vivian Manasc.

For the Athabasca University community, particularly the RAIC Centre for Architecture at AU, Hutchinson’s passing will be especially poignant. After all, his is the namesake behind the Ken and Janny Hutchinson Scholarship in Architecture — a $1,500 annual endowment for two AU students. Created by Hutchinson’s brother and sister-in-law, Ralph and Janet, and their company Daytona Homes, the scholarship honours the philanthropic values shared by Ken, and Janny, his beloved wife of 40 years.

Changing lives, two AU learners at a time

Since its inception in 2013, the Ken and Janny Hutchinson Scholarship in Architecture, has provided $18,000 to eight Athabasca University students. This year’s recipient, Salam Yousef, 26, knows just how far the Hutchinsons’ help can go.

The Edmonton-based learner in AU’s Bachelor of Science in Architecture (post-diploma) program attests the endowment monies she received, covered the tuition costs of the design course she started in January, of which she is finally wrapping up this week.

Tomorrow, she submits her last project.

Mr. Hutchinson’s generosity has inspired me to help others, and to give back to the community. I hope that one day I will be able to help students achieve their goals, just as I am achieving mine, because of his support.

~ Salam Yousef, AU student and recipient of the 2017-18 Ken and Janny Hutchinson Scholarship in Architecture.

Yousef, who will graduate next year, notes the Hutchinsons’ funding enabled her to keep her eyes on her coursework rather than fretting over finances. “Being awarded the Ken and Janny Hutchinson Scholarship in Architecture lightened my financial burden and helped me to focus more on the most important aspect of school and learning,” she said.

“Mr. Hutchinson’s generosity has inspired me to help others, and to give back to the community. I hope that one day I will be able to help students achieve their goals, just as I am achieving mine, because of his support.”
Hutchinson’s Hallmark

“‘Decorated architect,’ ‘devoted family man,’ and ‘community leader dedicated to providing support for those who need it the most’ — including our learners here at AU. These are but a few of the remarkable qualities Ken upheld throughout his career and life,’” said Athabasca University President Neil Fassina.

“On behalf of the entire Athabasca University Community, our warmest thoughts go out to Janny, Ralph, Keesa, Kodi, and the rest of Ken’s family. Thank you for your support of Athabasca University. Our learners will continue to reap the benefits of yours and Ken’s generosity.”

Hutchinson’s memorial was held in Calgary on Tuesday, April 24, at Eden Brook Memorial Gardens & Funeral Home. To share memories and condolences, please visit:


Government of Canada announces Jury for Smart Cities Challenge

Thirteen jurors will help select the finalists and winners of the competition

Ottawa, Ontario, April 26, 2018 — Being innovative and using data and connected technology will strengthen our communities, make them more liveable and inclusive, and create economic opportunities and jobs for middle class Canadians.

Today, the Honourable Amarjeet Sohi, Minister of Infrastructure and Communities, announced the names of the jury members who will advise on the selection of finalists and winners of the Smart Cities Challenge. The Smart Cities Challenge encourages communities of all sizes across the country to develop and implement smart cities initiatives.

The jurors, selected through a transparent and merit-based process, are diverse professionals who are accomplished and publically recognized in fields related to smart cities, including urban planning, architecture, and policy innovation.

The jury members, are:

  • Brent Bellamy: Winnipeg, Manitoba.
  • Leanne Bellegarde: Saskatoon, Saskatchewan.
  • Matthew Claudel: Cambridge, Massachusetts.
  • Andrea Feunekes: Fredericton, New Brunswick.
  • Carol Anne Hilton: Victoria, British Columbia.
  • Lisa Holmes: Morinville, Alberta.
  • Maxime Johnson: Montreal, Quebec.
  • Kaviq Kaluraq: Iqaluit, Nunavut.
  • Kourosh Rad: Halifax, Nova Scotia.
  • Stéphane Roche: Quebec City, Quebec.
  • Gabe Sawhney: Toronto, Ontario.
  • Maayan Ziv: Toronto, Ontario

The Jury will be led by Chairperson Mark Romoff, from Toronto, Ontario. The biographies of the jury members can be found on the Infrastructure Canada website.

Over the next few weeks, the Smart Cities Challenge jury will review applications that have been submitted to the competition from communities across Canada. They will assess the applications and recommend twenty finalists to the Minister of Infrastructure and Communities.

These finalists will be announced in the coming weeks. The jury will also help choose the winners of the competition, who will be announced in spring 2019.


“The Smart Cities Challenge will support innovation and drive real outcomes for residents across the country. The skilled and diverse jury announced today will help us find the best ideas Canada has to offer so that we can build more inclusive and accessible communities where our residents are informed, secure and healthy.

– The Honourable Amarjeet Sohi, Minister of Infrastructure and Communities

Quick facts

  • The callout for jury applications was launched in November 2017 with the launch of the Smart Cities Challenge. The callout was posted on the Infrastructure Canada website.
  • The jury is made up of a chairperson and 12 leaders who are recognized in their respective fields.
  • The jury will also select the winners of the Challenge, who will be announced in spring 2019.
  • Through the Investing in Canada plan, the Government of Canada launched the first of three competitions of the Smart Cities Challenge to encourage communities across the country to develop and implement smart cities initiatives. Finalists will be announced in the coming weeks.

Related products

Associated links


Brook Simpson
Press Secretary
Office of the Minister of Infrastructure and Communities

Infrastructure Canada
Toll free: 1-877-250-7154


It really works’: Alberta maternity group calls for midwives in Indigenous and rural communities – CBC

‘The practice of traditional midwifery is something that was taken away from traditional midwives,’ says doula

Apr 26, 2018

Picture a woman days away from childbirth, leaving her small community and being marooned away from her family and friends in order to give birth in a hospital in a big city.

Danielle Voyageur, a doula, meets Indigenous pregnant women just like this regularly in Edmonton.

“(They’re) isolated from family and friends and the support system she would have had in her own community,” Voyageur said. “I want to change this.”

Read More:

AltaGas Ltd. Reports First Quarter 2018 Results

CALGARYApril 26, 2018  –

(all financial figures are unaudited and in Canadian dollars unless otherwise noted)

  • Achieved normalized EBITDA1 of $223 million in the first quarter of 2018;
  • Achieved normalized funds from operations1 of $169 million in the first quarter of 2018;
  • Received regulatory approval from Maryland Public Service Commission (PSC of MD) for the approximately $9 billion transformational pending acquisition of WGL Holdings, Inc. (WGL Acquisition);
  • Propane secured for close to 75 percent of Ridley Island Propane Export Terminal (RIPET) export capacity; construction of the facility remains on-time and on-budget for start-up in the first quarter of 2019;
  • Signed new long-term take-or-pay agreement with Birchcliff Energy Ltd. (Birchcliff); and
  • Awarded a second Resource Adequacy contract at the Ripon facility for October through December 2018.

AltaGas Ltd. (AltaGas) (TSX:ALA) today reported that normalized EBITDA in the first quarter of 2018 was $223 million, compared to $228 million in the same quarter in 2017. Normalized funds from operations were $169 million ($0.96 per share) for the first quarter of 2018, compared to $170 million ($1.01 per share) in the same period of 2017. On a U.S. GAAP basis, net income applicable to common shares for the first quarter of 2018 was $49 million ($0.28 per share) compared to $32 million ($0.19 per share) in the first quarter of 2017. Normalized net income1 was $70 million ($0.40 per share) for the first quarter of 2018, compared to $65 million ($0.39 per share) in the same period of 2017.

“2018 is off to a great start, both from a financial perspective as well as from the advancements made toward closing the WGL Acquisition,” said David Harris, President and Chief Executive Officer of AltaGas. “We have just one approval remaining before we are in a position to close the WGL Acquisition. We are excited about the benefits that our combination with WGL will bring to customers, shareholders and all stakeholders. Together with WGL, AltaGas will have over $20 billion in robust, high quality, low-risk, long-lived assets across all three of our business segments with great scale and diversity.”

Significant progress on WGL Acquisition

On April 4, 2018, the PSC of MD approved the proposed merger of AltaGas and WGL. The 4:1 favourable decision by the PSC of MD followed a comprehensive public process and contained a number of conditions which were in line with the merger commitments offered up by the companies. On April 5, 2018, both AltaGas and WGL accepted the conditions.

The WGL Acquisition is expected to provide strong accretion to earnings per share and normalized funds from operations per share through 2021. Starting with the first full year in 2019, the WGL Acquisition is expected to support visible dividend growth through 2021, while allowing AltaGas to maintain a conservative payout of normalized funds from operations. Dividend growth is expected to be further supported by AltaGas’ portfolio of highly contracted assets. In the first full year 2019, AltaGas expects approximately 85 percent of its EBITDA to come from contracted or regulated assets.

With the WGL Acquisition, AltaGas will have a larger, diversified platform for growth with approximately $4.5billion in secured growth projects and approximately $1.5 billion of additional growth opportunities in advanced stages of development through 2021. Combined, AltaGas will have a significant platform of diversified energy infrastructure assets in all three of its business segments – Gas, Power and Utilities – across North America. AltaGas’ Gas segment will have a premier footprint in two of North America’s most prolific gas plays, the Montneyand Marcellus, and is uniquely positioned to grow energy exports to premium markets including Asia. AltaGas’ Power segment presents significant opportunities to continue to grow its clean energy portfolio of renewables, battery storage and distributed generation, while the Utilities business segment will have a combined rate base of approximately $4.5 billion and close to $3 billion in opportunities over the next several years, through customer additions, accelerated replacement programs and general system betterment capital expenditures.

Together AltaGas and WGL will have over $20 billion in energy infrastructure assets and an enterprise value of over $17 billion. Closing of the WGL Acquisition continues to be on track for mid-2018. Financing to close the WGL Acquisition is fully backstopped with $2.6 billion in proceeds from AltaGas’ bought deal and private placement of subscription receipts which closed in the first quarter of 2017, and a US$3 billion fully committed bridge facility which may be drawn upon for closing and could remain in place for up to 12 to 18 months thereafter.

With all financing in place to close the WGL Acquisition, AltaGas continues to evaluate and advance an asset monetization strategy in a prudent and timely fashion in step with the regulatory process and consistent with AltaGas’ long-term strategic vision. Management expects the repayment of the bridge facility to result from the monetization of over $2 billion from its asset sale processes and from offerings of senior debt and hybrid securities, subject to prevailing market conditions.

“As we enter into the final phase of the WGL Acquisition and gain certainty around regulatory approvals, we will be able to provide more concrete details on our asset monetization processes,” said Mr. Harris. “We are actively in discussions on several fronts, including the potential sale of appropriate minority interest(s) in our Northwest B.C. Hydro Facilities. Ultimately, we expect to deliver a strong financial outcome for AltaGas and meaningful financial returns for our shareholders.”

Ridley Island Propane Export Terminal

AltaGas has significantly advanced its propane supply contracting efforts for RIPET, and now has close to 75 percent of supply secured for the start-up of the facility, with third party arrangements subject to customary conditions. A portion of these volumes are under tolling arrangements and AltaGas expects approximately 40 percent of RIPET’s annual expected capacity to be under tolling arrangements.

RIPET is expected to be the first propane export facility off the west coast of Canada. The site is near Prince Rupert, British Columbia, has a locational advantage given very short shipping distances to markets in Asia, notably a 10-day shipping time compared to 25 days from the U.S. Gulf Coast. The brownfield site also benefits from excellent railway access and ample deep water access to the Pacific Ocean. AltaGas’ arrangements with Ridley Terminals Inc. (RTI) give AltaGas access to extensive land and water rights and a world class marine jetty, which allows for the efficient loading of Very Large Gas Carriers that can access key global markets. Propane from British Columbia and Alberta will be transported to the facility using 50-60 rail cars per day through the existing CN rail network. RIPET is expected to ship 1.2 million tonnes of propane per annum (which is equivalent to approximately 40,000 Bbls/d of export capacity).

“We are pleased with the progress being made on RIPET and producers are starting to see the benefits of having access to a new premium market for their propane,” said Mr. Harris. “We are uniquely positioned to offer energy exports to producers and are excited about the potential future growth of this business.”

New long-term take-or-pay agreement with Birchcliff

On April 3, 2018, Birchcliff and AltaGas announced a definitive agreement effective January 1, 2018 for a long-term natural gas processing arrangement at AltaGas’ deep-cut sour gas processing facility located in Gordondale, Alberta, replacing the parties’ existing Gordondale processing arrangement. Under the new processing arrangement, Birchcliff is being provided with up to 120 MMcf/d of natural gas processing on a firm-service basis, and Birchcliff’s take-or-pay obligation is 100 MMcf/d. The term of the processing arrangement is for at least 15 years, subject to extension in accordance with the terms of the arrangement.

The new arrangement allows AltaGas to maximize the long-term value and returns from the Gordondale Facility as it fills the existing capacity and significantly enhances the potential to flow third-party volumes through the facility and to grow those volumes. This will allow AltaGas to optimize the facility and bring the operating capacity up to 150 MMcf/d. The long-term commitment from Birchcliff, potential for third-party volumes and the strategic proximity of this asset to the liquids-rich Montney fairway further supports AltaGas’ plans for future expansion of the Gordondale Facility. In addition, AltaGas will benefit from growing propane volumes which will be dedicated to RIPET as part of the commercial arrangements.

First quarter 2018 results

Normalized EBITDA in the quarter was $223 million compared to $228 million for the same quarter of 2017. Normalized EBITDA from the Gas segment increased compared to the first quarter of 2017, benefitting from the higher realized frac spread and frac exposed volumes, as well as contributions from the Townsend 2A and North Pine facilities which entered into commercial operations in the fourth quarter of 2017. Gains in the Gas segment were partially offset by the sale of the EDS and JFP transmission pipelines in March of 2017, as well as lower natural gas storage margins and lower equity earnings from Petrogas Energy Corp. (Petrogas). Normalized EBITDA results in AltaGas’ Utilities segment were also strong; however, they were impacted slightly due to the U.S. tax reform effect at SEMCO, as well as due to unfavourable foreign exchange rates. In Power, normalized EBITDA decreased approximately $9 million, primarily as a result of planned outages at the Blythe and Craven facilities, lower renewable generation from both the Northwest Hydro Facilities and the Bear Mountain wind facility, and due to unfavourable foreign exchange rates.

Normalized funds from operations for the first quarter of 2018 were $169 million ($0.96 per share), compared to $170 million ($1.01 per share) for the same quarter in 2017, reflecting the same drivers as normalized EBITDA, partially offset by lower current income tax expense. In the first quarter of 2018, AltaGas received $3 million of dividends from the Petrogas Preferred Shares (2017 – $3 million) and $1 million of common share dividends from Petrogas (2017 – $1 million).

AltaGas recorded income tax expense of $18 million for the first quarter of 2018 compared to $21 million in the same quarter of 2017. The decrease was mainly due to the recently enacted change in U.S. Federal tax rate from 35 percent to 21 percent.

Net income applicable to common shares for the first quarter of 2018 was $49 million ($0.28 per share), compared to $32 million ($0.19 per share) for the same quarter in 2017. The increase was mainly due to lower transaction costs incurred on the pending WGL Acquisition, and lower interest and income tax expense, partially offset by the same previously referenced factors resulting in the decrease in normalized EBITDA, higher losses on investments, higher preferred share dividends, and higher depreciation and amortization expense.

Normalized net income was $70 million ($0.40 per share) for the first quarter of 2018, compared to $65 million($0.39 per share) reported for the same quarter in 2017. The increase was mainly due to lower interest and income tax expense, partially offset by the same previously referenced factors resulting in the decrease in normalized EBITDA, higher preferred share dividends, and higher depreciation and amortization expense. Normalizing items in the first quarter of 2018 included after‑tax amounts related to losses on investments, transaction costs on acquisitions, financing costs associated with the bridge facility for the pending WGL Acquisition, unrealized gains on risk management contracts, and gain on sale of certain non-core gas assets. In the first quarter of 2017, normalizing items included after-tax amounts related to transaction costs on acquisitions, unrealized gains on risk management contracts, loss on sale of assets, and amortization of financing costs associated with the bridge facility.

2018 Outlook

AltaGas expects the WGL Acquisition to close in mid-2018. As a combined entity, AltaGas expects normalized EBITDA to increase by approximately 25 to 30 percent and normalized funds from operations to increase by approximately 15 to 20 percent.

The WGL Acquisition is expected to drive growth in all three business segments. The combined Utilities segment is expected to have the largest contribution to EBITDA, followed by the Gas segment. Specifically for Utilities, the combined segment is expected to have an overall rate base of approximately $5 billion and is expected to grow through planned capital investments in 2018. The WGL Acquisition will also increase the number of utility customers by approximately 1.2 million. The Gas segment is expected to benefit from the addition of WGL’s pipeline investments in the prolific Marcellus/Utica gas resource regions as well as a gas supply agreement associated with the Cove Point LNG Terminal which recently began exporting LNG. WGL’s investment in the Stonewall Gas Gathering System is currently in-service and WGL expects the Central Penn and Mountain Valley pipelines to be operational by the end of 2018. The Gas segment will also benefit from a full year of contributions from AltaGas’ Townsend 2A Facility and the first train of the North Pine Facility. Finally, the Power segment is expected to benefit from the addition of WGL’s distributed generation assets to its portfolio.

The overall forecasted normalized EBITDA and funds from operations for the combined business include assumptions around the timing of closing of the WGL Acquisition, the U.S./Canadian dollar exchange rate, the impact of certain contemplated asset monetizations and other financing initiatives as part of the WGL financing plan, and the impact of U.S. tax reform. Any variance from AltaGas’ current assumptions could impact the forecasted increase to normalized EBITDA and funds from operations.

On a standalone basis, excluding the WGL Acquisition and potential asset monetizations, AltaGas expects a moderate increase to both normalized EBITDA and funds from operations in 2018 compared to 2017 related to its base business, mainly as a result of growth in the Gas segment. The moderate increase to normalized EBITDA and funds from operations for AltaGas’ standalone base business is primarily due to full year contributions from Townsend 2A and the first train of the North Pine Facility, higher realized frac spread mainly due to higher hedged prices, higher expected earnings from the Northwest Hydro Facilities due to contractual price increases and continued efficiency improvements, and colder weather and rate base and customer growth at certain of the Utilities. These increases may be partially offset by the impact of a weaker U.S. dollar on reported results of the U.S. assets, the impact of planned turnarounds at the Harmattan and JEEP facilities, and the expiry of the Power Purchase Agreement (PPA) at the Ripon facility in the second quarter of 2018. U.S. tax reform is expected to be immaterially negative to normalized EBITDA and funds from operations for AltaGas’ U.S. businesses while, on a net income basis, the impact of U.S. tax reform is expected to be immaterially positive. This 2018 outlook does not include any potential upside associated with new developments in either the Gas or Power segments.

AltaGas estimates an average of approximately 10,500 Bbls/d will be exposed to frac spreads prior to hedging activities. For 2018, AltaGas has frac hedges in place for approximately 7,500 Bbls/d at an average price of approximately $33/Bbl excluding basis differentials.

Growth Capital and Project Updates

Based on projects currently under review, development or construction, AltaGas expects net capital expenditures in the range of $500 to $600 million (excluding WGL) for 2018. AltaGas’ Gas segment will account for approximately 50 to 55 percent of the total capital expenditures, while AltaGas’ Utilities segment will account for approximately 30 to 35 percent and the Power segment will account for the remainder. Gas and Power maintenance capital is expected to be approximately $25 to $35 million of the total capital expenditures in 2018. The majority of AltaGas’ capital expenditures is focused on the continued construction at RIPET, maintaining and growing rate base at its existing utilities, pre-construction design, engineering, and right-of-way procurement for the Marquette Connector Pipeline (MCP), and growth capital associated with the tie-in of incremental third party gas volumes. The Corporation continues to focus on enhancing productivity and streamlining businesses, including the disposition of smaller non‑core assets.

AltaGas’ 2018 committed capital program is expected to be funded through internally‑generated cash flow and the Premium DividendTM, Dividend Reinvestment and Optional Cash Purchase Plan (DRIP).

Following the close of the WGL Acquisition (expected close date in mid-2018), the consolidated 2018 capital program on a combined basis, including capital for WGL, is expected to be in the range of approximately $1.0 to $1.3 billion. Close to half of this total will be allocated to the Gas segment, with the majority of the remaining expected capital for the Utilities segment, followed by the Power segment. AltaGas expects that the largest portion of WGL’s 2018 capital program subsequent to close will be allocated to investments in the Central Penn and Mountain Valley gas pipeline developments in the Marcellus region. Capital allocated to WGL’s utilities business will represent most of the remaining 2018 capital subsequent to close, with spending consistent with recent levels.

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ATCO Reports First Quarter 2018 Earnings

CALGARY, Alberta, April 26, 2018 — ATCO Ltd. (TSX:ACO.X) (TSX:ACO.Y)

ATCO today announced first quarter adjusted earnings for 2018 of $99 million, or $0.87 per share, compared to $116 million, or $1.01 per share, in the first quarter of 2017. Lower earnings in the Company’s utility businesses were mainly due to rate rebasing under Alberta’s regulated model, partially offset by higher earnings from Alberta PowerLine.

ATCO invested $772 million in capital growth projects in the first quarter of 2018, of which 98 per cent was invested in assets that earn a return under a regulated business model or are under commercially secured long-term contracts.

In the period 2018 to 2020, ATCO expects to invest an additional $4.5 billion in regulated utility and commercially secured capital growth projects. This capital investment is expected to contribute significant earnings and cash flow, and create long-term value for share owners.

On April 4, 2018, ATCO declared a second quarter dividend for 2018 of 37.66 cents per Class I Non-Voting and Class II Voting Share.


  • In April 2018, Structures & Logistics executed a contract extension for accommodations for 750 persons at the Lake Charles, Louisiana project. The 29-month contract, originally awarded in 2015 for the design, construction, transportation, installation and rental of modular units for a 1,900-person village, was scheduled for completion in May 2018. The extension agreement runs until the end of 2018, with an option to extend to April 2019.
  • On February 20, 2018, Canadian Utilities, an ATCO company, completed the acquisition of Electricidad del Golfo, which owns a long-term contracted, 35 MW hydroelectric power station based in the state of Veracruz, Mexico. The transaction was recorded for an aggregate purchase price of $112 million.
  • In March 2018, ATCO announced we will build a 26 MW cogeneration project, known as the La Laguna Cogeneration facility, on the site of the Chemours Company Mexicana S. de R.L. de C.V.’s chemical facility near Gómez Palacio, in the state of Durango, Mexico. Developed in partnership with RANMAN Energy, the La Laguna Cogeneration facility will provide low-carbon and cost-effective electricity and heat under a long-term agreement. The total investment associated with the project is approximately $70 million, and the facility is expected to be operational in 2019.
  • On March 21, 2018, the Alberta Balancing Pool provided notice of its intent to terminate the Power Purchase Arrangement (PPA) for Battle River unit 5 and that dispatch control of Battle River unit 5 would be turned back to ATCO no later than September 30, 2018. As part of the turn back, the Balancing Pool is obligated to pay ATCO a PPA termination payment, the terms of which have not been finalized.
  • In March 2018, we completed work on Battle River unit 4 to enable the unit to co-fire with natural gas. Natural gas can now be used for approximately half of the unit’s 155 MW total electricity generation capacity.


A financial summary and reconciliation of adjusted earnings to earnings attributable to Class I and Class II Shares is provided below:

For the Three Months
Ended March 31
($ millions except share data) 2018 2017 (4)
Adjusted earnings (1) 99 116
Unrealized losses on mark-to-market forward commodity contracts (2) (9 ) (3 )
Rate-regulated activities (2) (1 ) (13 )
Other (3) 1
Earnings attributable to Class I and Class II Shares 90 100
Weighted average shares outstanding (millions of shares) 114.4 114.4
(1) Adjusted earnings are defined as earnings attributable to Class I and Class II Shares after adjusting for the timing of revenues and expenses associated with rate-regulated activities and unrealized gains or losses on mark-to-market forward commodity contracts. Adjusted earnings also exclude one-time gains and losses, significant impairments, and items that are not in the normal course of business or a result of day-to-day operations. Adjusted earnings present earnings on the same basis as was used prior to adopting International Financial Reporting Standards (IFRS) – that basis being the U.S. accounting principles for rate-regulated entities – and they are a key measure used to assess segment performance, to reflect the economics of rate regulation and to facilitate comparability of ATCO’s earnings with other Canadian rate-regulated companies.
(2) Refer to Note 5 of the consolidated financial statements for detailed descriptions of the adjustments.
(3) The Company adjusted for the deferred tax asset which was recognized as a result of the Tula Pipeline Project impairment. The adjustment is due to a difference between the tax base currency, which is the Mexican peso, and the U.S. dollar functional currency.
(4) These numbers have been restated to account for the impact of IFRS 15. Additional details on IFRS 15 are discussed  in the Other Financial Information section of the MD&A.

This news release should be used as a preparation for reading the full disclosure documents. ATCO’s consolidated financial statements and management’s discussion and analysis for the quarter ended March 31, 2018 will be available on the ATCO website (, via SEDAR ( or can be requested from the Company.

With approximately 7,000 employees and assets of $22 billion, ATCO is a diversified global corporation delivering service excellence and innovative business solutions in Structures & Logistics (workforce housing, innovative modular facilities, construction, site support services, and logistics and operations management); Electricity (electricity generation, transmission, and distribution); Pipelines & Liquids (natural gas transmission, distribution and infrastructure development, energy storage, and industrial water solutions); and Retail Energy (electricity and natural gas retail sales). More information can be found at

Media & Investor Inquiries:

D.A. (Dennis) DeChamplain
Senior Vice President & Chief
Financial Officer


Paint your frustration away: Lethbridge hospital offers the public a chance to create a masterpiece – Global News

Patients, their families and friends, and the public are putting together personal masterpieces at the Chinook Regional Hospital in Lethbridge.

The Indigenous Health Program and Therapeutic Recreation worked together to put on the event, called Art in the Atrium, on Wednesday afternoon where people could come and work on a watercolour landscape painting to celebrate southern Alberta.

The event was open to anyone, including patients and their loved ones.

Both groups say art, and painting in particular, offers stress and emotional release.

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Safety board to release report on plane crash that killed Jim Prentice – CP

Source: The Canadian Press
Apr 26, 2018 

CALGARY _ The Transportation Safety Board is to release a report today on the plane crash that killed former Alberta premier Jim Prentice and three other men.

The Cessna Citation jet went down shortly after takeoff from Kelowna, B.C., on its way to the Springbank airport west of Calgary in October 2016.

No distress signal was sent before the aircraft vanished from radar.

Also aboard were optometrist Ken Gellatly, the father-in-law of one of Prentice’s three daughters, and Calgary businessman Sheldon Reid.

Jim Kruk, a retired RCMP officer and aviation enthusiast, was flying the plane.

The small aircraft was not required to have voice and data recorders, which the Transportation Safety Board warned would make its investigation particularly challenging.

Days after the crash, board chairwoman Kathy Fox made a renewed call for the devices to be required on small planes.

“This latest accident is another reminder of how important these recorders are,” she said in a statement at the time. “If we are to get to the underlying causes of these tragic accidents, Transport Canada and the aviation industry need to take immediate action to address this outstanding safety issue.”

Greg McConnell, national chairman of the Canadian Federal Pilots Association, said one change he would like to see is regular Transport Canada inspections for small aircraft such as the business jet Prentice died in.

He said it’s possible the TSB may not be able to pinpoint a single cause for why the plane went down.

“Often with accidents it’s never one thing, but it’s a culmination of a bunch of little things,” McConnell said.

“We won’t know until we see the report, I guess.”


Statement: Dear Minister George Heyman

Dear Minister Heyman:

I am writing to follow up on the meeting the Prime Minister held with British Columbia Premier John Horgan and Alberta Premier Rachel Notley in Ottawa on April 15, 2018 to discuss the twinning of the Trans Mountain Expansion (TMX) project.

The Government of Canada has a strong regime in place to protect the environment in land and marine areas under its jurisdiction, and is committed to continuous improvement in this respect. We are dedicated to ensuring that Canada’s resources are developed in a way that is informed by rigorous science and evidence, aligns to Canada’s climate change plan, protects Canada’s rich natural environment, including our Oceans, respects the rights of Indigenous Peoples, and supports our economy. Our priority remains to effectively advance both Canada’s economic progress and our environmental responsibilities.

In this context, I wanted to underscore our government’s commitment to seeing the TMX project go ahead, as this vital infrastructure is in Canada’s national interest, and to outline why our government has confidence this project can proceed in a manner that is safe, environmentally responsible, and can be built and operated to the highest standards. I also outline measures we have taken, and propose potential areas for future collaboration, to ensure concerns about the project and the protection of B.C.’s coast are addressed in a comprehensive and meaningful way.

Protecting the coast
The Government of Canada firmly stands by its decision to approve the TMX project.  The project was approved, with 157 legally-binding conditions, within the context of Canada’s climate action plan and after a rigorous review based on science and evidence, as well as extensive consultations with Indigenous peoples and other relevant parties. These conditions, including for marine safety, are among the most stringent ever imposed. We believe the marine safety requirements alone are more onerous than those imposed for any other project proponent.

The Oceans Protection Plan
In addition, the federal government has launched the $1.5 billion Oceans Protections Plan (OPP), the largest investment Canada has ever made to protect our coasts and marine environments. This plan will provide far greater protections to our coast after this project is built than we have today, despite the small increase in tanker traffic. This funding will enhance marine safety along Canada’s entire coastline, the longest in the world – supporting new and ongoing prevention, preparedness and response measures. This directly responded to recommendations, including those from the Royal Society of Canada in 2015, to fill the gaps that existed in Canada’s system at that time. These improvements will be completed on the BC coast before the pipeline infrastructure expansion is operational.

We are developing a marine safety system that rivals any in the world. The marine safety improvements from the Oceans Protection Plan, coupled with the stringent project conditions for the TMX project, and building on the robust system already in place, will put extraordinary safeguards in place for all vessels, including those carrying petroleum products. Those safeguards include:

  • Requirements for, and the use of, experienced pilots and tethered tugs to escort resources safely out to sea;
  • Increasing the towing capacity of the Coast Guard by adding two large vessels capable of towing large vessels and installing towing equipment on 25 large vessels;
  • Five new spill-response stations funded by industry to enhance emergency response capacity, as well as new, significantly shorter response time which could benefit Burrard Inlet;
  • Based on the polluter-pay principle, removal of the Ship-Source Oil Pollution Fund per-incident limit of liability, and making an unlimited amount of compensation available for spill response;
  • Strong partnerships on monitoring and spill response with coastal and Indigenous communities; and,
  • The Kitsilano Coast Guard Station has been re-opened.

Crude oil has been shipped safely through the Vancouver harbour for over 60 years, and diluted bitumen for over 30 years.  We are confident that these improvements will help maintain this impressive record, and not only address concerns about tanker traffic, but will increase marine safety for all vessels, the over 3100 large vessels that use the port of Vancouver and 206,000 vessel movements in the Salish Sea annually. Once the expansion project is complete, Trans Mountain tankers will represent less than seven per cent of the total large commercial marine vessels transiting the Juan de Fuca Strait.

To complement Canada’s world-leading marine safety regime and response capacity, the Oceans Protection Plan will add to the already significant body of scientific knowledge concerning petroleum products in the marine context and incorporate Indigenous knowledge.

Our government has invested substantially in oil spill and response research for over 35 years, and has produced over 60 peer-reviewed publications in the last five years alone focused on the science of diluted bitumen spills. As a result of this research, and ongoing work by Canadian and international researchers, Canada has advanced overall understanding of the fate and behaviour of petroleum products in ocean and fresh water.

Based on current scientific evidence and limited real-world spill experience, diluted bitumen behaves similarly to conventional crude oils; it will float initially for several days depending on the environmental conditions.

Since 2013, the Government of Canada has made concerted efforts to increase investment, collaboration and coordination of work among Fisheries and Oceans Canada, Natural Resources Canada and Environment and Climate Change Canada to increase understanding of spills of diluted bitumen in marine and freshwater environments. That investment was augmented in 2016 with additional funding provided to implement the Oceans Protection Plan, which includes focusing research on the fate, behaviour and effects of various oil products in different spill conditions and under extreme Canadian climates, to improve the security of transport of oil products, spill recovery and responses.

Collectively, the Government of Canada has dedicated some 50 scientists, technologists, chemists and engineers in four major programs to study oil spill behaviour and recovery technologies. There is a significant body of work in the public domain that have been peer reviewed domestically and internationally, which helped inform decisions on pipeline projects as well as oil spill planning and preparedness. This body of knowledge, coupled with continued research, means we can say with confidence that responders will be able to better understand and predict the behavior of petroleum products in marine and freshwater environments—enhancing Canada’s ability to prepare for and respond to spills.

Working with Indigenous peoples and industry
We are collaborating with coastal and Indigenous communities and industry, industry, provinces, and territories, to realize the goals outlined in the Oceans Protection Plan, and working in partnerships with Indigenous peoples to ensure strong marine safety and environmental protection.

Pipeline and Rail Safety
The Railway Safety Act, the Pipeline Safety Act, the National Energy Board Act, the Canada Shipping Act, 2001, the Marine Liability Act, the Fisheries Act, as well as the Canadian Environmental Protection Act, 1999, establish a comprehensive world-leading federal regime in Canada related to the transportation of petroleum and other products.

The highest safety and security standards are in place in all modes of transportation to prevent incidents and accidents, while enabling rapid, science-based planning and response actions in the unlikely event of a spill.

The robust federal system is built on the “polluter pays” principle, whereby the industry transporting the product is responsible for costs related to cleanup and pollution damage. Further, a world-leading suite of liability and compensation measures is in place, addressing activities under federal jurisdiction and protecting Canadians from damages and costs associated with spills.

The recent measures enacted under the Pipeline Safety Act and amendments to the National Energy Board Act also demonstrate our government’s commitment to world-leading pipeline safety, as does Canada’s commitment of $65 million in new funding to support activities and priorities of the co-developed Indigenous Advisory and Monitoring Committee for the TMX project. This Committee provides a mechanism for Indigenous communities to provide advice to federal regulators, and participate in the monitoring of the existing line, the expansion project, and associated marine shipping.

Marine Sector
The Government of Canada has established a national ship-source oil spill regime comprised of three key areas: prevention, preparedness and response, and liability and compensation. This world-leading regime has its foundation in international obligations and is built on international and domestic cooperation and standards. Through new legislation and major investments, such as the Oceans Protection Plan, the Government of Canada is dramatically strengthening this already robust regime.

The more than 100 regulations, 30 acts and international agreements and commitments that make up Canada’s marine safety regime, are first and foremost, focused on preventing accidents from occurring.

We are confident that the full suite of measures in the Oceans Protection Plan and beyond will ensure comprehensive environmental protection, minimize any risks to the land and marine environments arising from TMX or similar infrastructure projects, and allow for a quick, efficient and effective response in the unlikely event that such actions were necessary. The Oceans Protection Plan and additional project-specific safeguards are rooted in scientific research, and our commitment to evidence-based decision making is unwavering.

Looking ahead
I understand that our senior officials have met a number of times over the past few months to provide further clarity and information on the Oceans Protection Plan, and on the science, including diluted bitumen, to discuss areas of concern to British Columbia, and to consider possible solutions. In this context, we remain open to explore those solutions further – such as examining ways to ensure more effective towing capacity on the West Coast, or to strengthen loss and damage provisions under rail safety legislation. In February, we also announced federal programs to reduce reliance on diesel fuel in rural and remote communities along British Columbia’s coast, and we are committed to working with Indigenous communities and B.C. to support access to these programs.

Our officials have been meeting to consider how we can advance collaboration and alleviate any ongoing concerns regarding spill response capacity. One proposal that we would like to highlight is a potential partnership among the Government of Canada, the Government of British Columbia and Indigenous peoples, to articulate a seamless land-to-sea system to protect British Columbia from spill risks through integrated work on planning, preparedness, response, and recovery and critical alignment of safety and response systems in our respective jurisdictions. Initial steps would include identifying any potential incidents whose impacts are most likely to cross jurisdictions, and improving upon joint systems and protocols to address environmental risks and incidents, including spills.

Should your government wish to further collaborate on science, we could consider establishing a joint Scientific Expert Advisory Panel. Such a panel would build on our science investments and results, take stock of work on the fate, behaviour, and effects of various oil products in different spill conditions and under extreme Canadian climates in order to inform further scientific work under the OPP and spill response modelling, preparedness and response measures. Such a panel would be made up of independent experts, be national in scope, and examine all types of petroleum products.

In addition to these measures, I also wanted to advise you that the Government of Canada has today submitted its response to the Government of British Columbia’s “Policy Intentions Paper for Engagement: Phase Two Enhancements to Spill Management in British Columbia”. Canada’s submission outlines the full scope of federal activities that underpin our confidence that the TMX project can be developed and operated safely, given that British Columbia did not address in its Consultation Paper the robust Canadian safety regimes, the long-standing scientific expertise, and significant recent investments made by the Government of Canada related to spill management. It is essential that Canadians have access to a complete and accurate picture of federal jurisdiction, spill management in Canada, and the world-leading federal measures in place to protect Canada’s coast, communities and environment.

Yours sincerely,

Catherine McKenna, P.C., M.P
Minister of Environment and Climate Change


Valley Line West LRT stops and stations names released – City of Edmonton

April 25, 2018

The City of Edmonton’s Naming Committee has announced the approved names for the 14 street-level stops and two elevated stations along the future Valley Line West LRT extension:

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The stop names were primarily chosen based on location to support passenger wayfinding. The Alex Decoteau Stop pays tribute to Alex Decoteau, who joined the Edmonton Police Service in 1911, becoming Canada’s first Indigenous police officer. The Yards/116 St. Stop is a historic reference to the CN Rail Yards that previously operated in the area.

As part of the City Planning Branch, the Naming Committee approves names for municipal facilities, new neighbourhoods, parks and roads. This name selection process involves input from City administration and consultation with Citizen Working Groups along the Valley Line route.

The 14 km Valley Line West extension is the second stage of the Valley Line LRT, an urban-style 27 km line that will operate between Mill Woods in southeast Edmonton and Lewis Farms in west Edmonton.

The project team is reviewing the preliminary design completed in 2013, and working to be procurement-ready later this year. Once procurement begins, the Valley Line West LRT Project will take approximately one year to select a contractor and another five years for construction.

For more information:

Media contact:
Cory Sousa
Principal Planner
Naming Committee & Addressing

Jennifer Villeneuve
Acting Communications Advisor
Valley Line West


Amiskwaciy History Series: Elder Irene Morin – City of Edmonton

April 25, 2018

Join Elder Irene Morin for an evening of storytelling and laughter as she shares her history as an Indigenous woman in leadership roles. This session is part of the Amiskwaciy History Series.

Date: Thursday, April 26, 2018
Time: 6:30 – 8:30 p.m.
Location: City Room, City Hall, 1 Sir Winston Churchill Square
Cost: Free, refreshments provided

Morin is a residential school survivor. She has had an extensive career, working for the then – Department of Indian Affairs in the 1960s and with Enoch Cree Nation for nearly 30 years. Throughout her life, Morin has provided great leadership on many important initiatives, and has been the driving force behind the Alberta Aboriginal Role Model Awards for 22 years. In 2017, she received the Queen’s Golden Jubilee Medal and the Senate of Canada 150 Medal.

The Amiskwaciy History Series is an Indigenous grassroots initiative aimed at building awareness of the often untold Indigenous history of the Edmonton area. Through free monthly educational sessions, the series aims to provide accessible and culturally appropriate education to the public on Indigenous history as lived and told by the people.

The name Amiskwaciy comes from Amiskwaciy Waskahikan, or “Beaver Hill House,” a Cree term used to describe the Edmonton area.
For more information:

Media contact:
Francis Asuncion
Communications Advisor
Citizen Services


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