AN INTEGRATED NORTHWEST CANADA ENERGY CORRIDOR AND

MAJOR PIPELINE HUB

Mike Priaro, P.Eng., Sept. 9, 2016.

An integrated energy corridor could be created along the route of a proposed oil pipeline from the Alberta (AB)

oil sands through hydroelectric power developments in the Peace River region of British Columbia (BC), and

then on to proposed liquefied natural gas (LNG), oil, and natural gas liquids (NGL) marine terminals on

Canada’s west coast.

An energy corridor from the oil sands near Fort McMurray AB through northern BC to the west coast port of

Prince Rupert BC could contain Eagle Spirit Energy Holding Ltd’s. proposed 2.0 million bbl/d Eagle Spirit oil

pipeline, TransCanada Corp.’s proposed Prince Rupert Gas Transmission (PRGT) pipeline, and a potential

natural gas liquids pipeline. This would create a highly efficient energy corridor that would dramatically reduce

the costs and the environmental footprint of energy development in northwestern Canada and provide vastly

improved access to markets in the Pacific Rim.

An integrated energy corridor offers many business, economic, and environmental incentives and benefits, as

well as benefits to affected First Nations (aboriginal/indigenous peoples). Canada’s Supreme Court has

affirmed in a series of recent decisions many legal rights of First Nations for industrial and other developments

on their traditional lands especially in BC where traditional native lands are in general not subject to treaties.

The Prince Rupert area is sheltered and ice-free year-round with deep, natural harbours. It is widely regarded

as the safest location for marine terminals on Canada’s west coast. There are no significant hazards such as

narrow channels to navigate, resulting in an unobstructed entry into the high seas and to the northern Pacific

Great Circle shipping route which provides the shortest trade route between North America and markets in the

Asia-Pacific region.

Along with the Port of Vancouver BC, Prince Rupert is part of the Canadian government’s Asia-Pacific

Gateway Corridor and Initiative (APGCI) to connect ports, road, and rail connections across western Canada to

the economic heartlands of North America. The Port of Prince Rupert offers the deepest natural harbour in

North America; steadfast labour and community support; efficient and uncongested rail connection directly from

the terminal to the North American Midwest; and significant capacity for growth.

Figure 1. Map showing the Asia-Pacific Gateway Corridor and Initiative. Source: Government of Canada.

Clean Hydroelectric Power for the Oil Sands

An integrated energy corridor would include electric transmission lines to supply low-carbon hydroelectric

power from BC’s Peace River region, and from Alberta hydroelectric projects, while facilitating greater

penetration and use of renewable energy sources, as follows:

1. Westward to provide low-carbon hydroelectricity to power LNG liquefaction plants near Prince Rupert

BC.

2. Regionally to field operations and facilities developing and producing immense shale gas, gas liquids,

and oil resources in northeast BC and northwest AB.

3. Regionally to provide hydroelectric power to meet expanding residential, commercial and industrial

demand.

4. Eastward back to the oilsands to provide low-carbon hydroelectric power to reduce GHG emissions by

displacing some of the large volumes of natural gas used in the oilsands.

An integrated energy corridor could also provide access points to store renewable, but intermittent, energy via

the hydroelectric projects.

There is also the potential to add value to Alberta’s bitumen resources using low-carbon hydroelectric power

by;

partially-upgrading bitumen, eliminating the need for diluent, to add value and reduce the handling and

transport costs of dilbit;

fully upgrading more bitumen to syncrude, or

refining bitumen and batching products in pipelines to markets.

These opportunities could be captured in Canada at significantly reduced GHG emissions relative to other

countries by the increased use of low-carbon hydroelectric power.

Additionally, large reservoirs of water behind hydropower dams could provide the reliable quantities of water

necessary for shale gas frac’ing operations with minimal affects on river flows during natural seasonal

variations.

Both BC Hydro’s proposed Peace Region Electricity Supply (PRES) project and Alberta’s ATCO Power’s

proposed North Montney Power Supply (NMPS) project were created to provide low-carbon electricity to be

supplied from BC and Alberta transmission grids.

Construction of a third dam and hydroelectric generating station on the Peace River in BC at Site C

started in 2015 and will be completed in 2024. Hydroelectric power from Site C will provide 1,100 MW of

capacity along with existing hydropower projects in BC’s Peace River region currently totaling 3,424 MW.

Figure 2. Location of under-construction Site C dam. Source; Amnesty International.

In Alberta, ATCO Power says the Peace River could generate 1,500 MW of hydro-power while a minimally

invasive run-of-river project on the Slave River could provide 1,800 MW with another 1,500 MW from a more

traditional facility on the Athabasca River near Fort McMurray. Alberta’s current electric power generating

capacity from all sources is about 15, 000 MW.

Clean hydropower for use in the oilsands would have to compete with the 3.1 bcf/d of low-cost natural gas

currently used to provide extraction steam, process heat, and co-generated electric power in oilsands

operations. The natural gas that is displaced could be shipped to Prince Rupert and exported as LNG instead

of being burned, adding value to natural gas and reducing global GHG emissions and air pollution where it is

used instead of coal to generate electric power.

Clean hydropower for the oil sands would also help reduce the 15-20% excess GHG emissions, on a well-to-

wheel basis, of oil sands bitumen compared to the GHG emissions of the average basket of conventional crude

feedstocks supplied to U.S. refineries.

A Potential Natural Gas Liquids Pipeline

Several recent export applications to Canada’s National Energy Board (NEB) to export LPG (liquefied

petroleum gas, i.e., propane and butanes) have been made recently:

1. The NEB recently approved Pembina NGL Corp. and Pembina Resources Services Canada

application to export 86,000 bbl/d of LPG for a 25-year term from various export points in Canada.

2. AltaGas LPG’s application to the NEB for a licence to export 40,000 bbl/d, of propane annually from a

marine export terminal near Prince Rupert and from railway crossings in Alberta and British Columbia.

The term of the licence is 25 years with a maximum total volume of 419.75 million bbls.

3. Petrogas Energy Corp. application to the NEB on Mar. 16, 2016 to export 107,000 bbl/d, also for a 25-

year term, from various export points in Canada.

These are a result of the recent reversal of the Cochin liquefied petroleum gas (LPG – propane and butanes)

and NGL (condensates, or pentanes+) pipeline from Alberta to Windsor, Ontario (ON), which had imported

some of the diluent required to export oilsands bitumen as dilbit. Since then, there have been occasions when

propane has had negative value at producer outlets in Alberta because of the loss of market access. That is,

some producers actually had to pay to have their propane removed. Furthermore, the availability of vast

amounts of cheap ethane from the nearby “wet” Marcellus and Utica shale gas plays in the U.S. is also backing

out Alberta ethane and propane exports currently batched down Enbridge's Line 5 to the petrochemical centre

of Sarnia ON.

A volume of 233,000 bbl/d easily achieves the economic threshold for an LPG pipeline especially if volumes of

NGLs are added. Such a pipeline installed in the same right-of-way (ROW) and at the same time as a new

natural gas line and a new oil line, would benefit from the savings of many billions in capital, operating costs,

and pipeline tariffs.

An Integrated Northwest Canada Energy/Transportation Corridor

The concept of a northwest Canada integrated energy corridor could be expanded to include:

1. Fibre optic cables.

2. Connections between electric power transmission lines and other hydroelectric and clean energy

sources.

3. Upgraded roads, highways, and railways that provide improved access to forestry, mining, recreation,

and isolated settlements as well as to the multi-modal freight port of Prince Rupert BC.

Running power lines and other services along the same ROW as the PRGT pipeline, Eagle Spirit pipeline, and

an LPG/NGL pipeline would require a wide ROW but would dramatically reduce construction costs and

minimize the environmental footprint and wildlife habitat fragmentation when compared to the clearing and

construction of multiple ROWs through the rugged Rocky Mountains and interior and coastal mountain ranges

of British Columbia.

There are five proposed gas pipelines through northern BC: Pacific Northern gas looping project, Pacific Trails

pipeline, Spectra Energy pipeline, Coastal GasLink pipeline, and Prince Rupert Gas Transmission pipeline. All

are routed south of the Williston Lake Reservoir formed by the W.A.C. Bennett dam on the Peace River.

Figure 3. Detailed map of all proposed natural gas pipelines through northern B.C. Source: Ecotrust Canada.

However, Eagle Spirit Energy Holdings Ltd. has obtained 95% of all First Nation approvals for an oil pipeline

route north of Williston Lake, according to Calvin Helin, Chairman and President of Eagle Spirit Energy. Helin

says First Nations approval of a natural gas pipeline, and by extension a propane/LPG/NGL/condensate

pipeline, in the same ROW as the Eagle Spirit oil pipeline, is possible.

Figure 4. Map showing the proposed route of the Eagle Spirit oil pipeline. Source: Eagle Spirit Energy.

The routing of the 2.0 million bpd Eagle Spirit oil pipeline from Fort McMurray to the Prince Rupert area would

offer large efficiencies and cost reductions in manpower, operations, management, infrastructure and

emergency spill response, as well as a reduced environmental footprint, if the oil, natural gas, and natural gas

liquids pipelines all terminated together in the Prince Rupert area.

The following table shows that the proposed 48-in. diameter Eagle Spirit oil pipeline has the capacity to match

the total capacity of the three other pipeline proposals with only minor adjustments to operating parameters.

PROPOSED PIPELINE CAPACITY bbl/day

Energy East 1,100,000

Northern Gateway 525,000

Trans Mountain Expansion 590,000

TOTAL 2,215,000

Eagle Spirit 2,000,000

Table 1. Capacity of proposed oil pipelines.

In addition to improving the economics of exploiting the oil sands by accessing higher netbacks in new markets

and by reducing pipeline tariffs, it is anticipated that Eagle Spirit could draw volumes from Enbridge’s 2,600,000

bbl/d Mainline which supplies large volumes of discounted crude to refineries in the U.S. Midwest and from the

Trans Mountain expansion should it not obtain approval of the federal cabinet of Prime Minister Justin Trudeau.

A Northwest Canada Pipeline Hub

This proposed northwest Canada energy corridor will provide multiple tie-in points to the existing TransCanada

Corp. NOVA Gas Transmission Ltd. (NGTL) gas gathering system infrastructure in northeast BC and northwest

AB.

Figure 5. Map showing location of TransCanada Corp.’s Alberta and BC gas gathering system, Source;

TransCanada Corp.

According to Russ Girling President and Chief Executive Officer, “Our NGTL System is sitting on top of

extensive natural gas supplies, making it well-positioned to unlock the resource and reliably and efficiently link

it to growing markets…”, and, “The system has been operating at capacity, and more capacity is needed in

these key areas that support the growth of the prolific gas resource in the Western Sedimentary Basin.”

Figure 6. Detailed map of TransCanada Corp.’s NGTL system showing current expansion projects, Source;

TransCanada Corp.

TransCanada Corp.’s subsidiary, NOVA Gas Transmission (NGTL) recently signed contracts for 2.7 Bcf/d of

new firm natural gas transportation service that will require a $570 million system expansion for 2018.

Significant growth in unconventional natural gas supplies in northeastern BC and northwestern AB are the

primary driver for these new contracts, coupled with continued growth in market demand, according to

TransCanada.

The 2018 expansion program will increase the overall investment on the NGTL beyond the already announced

$7.5 billion of projects. About $2.8 billion worth of these projects have received regulatory approval, with $800

million under construction, and an additional $1.7 billion of facilities are under regulatory review, according to

the company. The new expansion includes multiple projects that total 90 km of nominal 20- to 48-inch pipeline,

one new compressor, about 35 new and expanded meter stations and other associated facilities. Subject to

regulatory approvals, construction is expected to start in 2017, with all facilities expected to be in service in

2018.

Spectra Energy and its partner, BG Group, propose to build an approximately 850-km. natural gas pipeline

corridor from the Cypress area in NE BC to BG Group's proposed LNG export facility on Ridley Island, near

Prince Rupert.

Figure 7. Detailed map of Spectra Energy proposed Westcoast Connector Gas Transmission pipeline. Source;

Spectra Energy.

It may be possible to build one gas pipeline to accommodate volumes for both Spectra’s Westcoast Connector

Gas Transmission project to Ridley Island near Prince Rupert and TransCanada’s proposed Prince Rupert Gas

Transmission pipeline to Lelu Island at Port Edward near Prince Rupert - greatly reducing the cost and

significantly enhancing the economic viability of each proposal.

Figure 8. Detailed map of TransCanada Corp.’s proposed Prince Rupert Gas Transmission pipeline. Source; Spectra

Energy.

The concept of a major northwest Canada pipeline hub is indicated on the map below which shows Spectra

Energy’s existing gas pipeline to the BC Lower Mainland and the main shale oil and gas producing areas of NE

BC and NW AB.

Figure 9. Concept of a northwest Canada pipeline hub. Source; Mike Priaro and Spectra Energy.

A northwest energy corridor to Prince Rupert BC could also tie into the proposed 1,200-kilometre Mackenzie

Valley natural gas pipeline transporting Arctic, Beaufort Sea, Mackenzie Delta, and Northwest Territories oil

and gas resources to Canadian and U.S. markets via tie-in to TransCanada’s existing NOVA gas gathering and

transmission system in Alberta.

Figure 10. Map of proposed Mackenzie Valley pipeline (Northcentral Crossing pipeline will not be required with

northwest energy corridor to west coast). Source; Mackenzie Valley Project.

Along with the existing Keystone pipeline to the U.S. Gulf Coast, Enbridge’s Mainline system to the U.S.

Midwest and Gulf Coast, and the proposed Energy East pipeline to Canada’s east coast, the result would be a

major, inter-connected oil, natural gas and natural gas liquids pipeline network and hub that would efficiently tie

together the vast hydrocarbon resources of northern and western Canada and provide flexibility of access to

the best prices available on world markets.

There would be major economic benefits to the province of British Columbia from the revenue from low-carbon

hydroelectric power generation in the Peace River region, from the provision of adequate residential,

commercial, and industrial power for increased development in northern BC, and from the reduction in GHG

emissions of resource development.

The Hydrocarbon Resources of Northwest Canada

Oil, natural gas liquids, and natural gas pipelines to LNG plants and marine terminals near Prince Rupert would

encourage development of immense oilsands and shale gas, oil, and natural gas resources in northeast BC

and northern Alberta as well as hydrocarbon resources in Canada’s Northwest Territories, Yukon territory, the

Mackenzie Delta, Beaufort Sea, and Arctic Islands.

The following table details the immense hydrocarbon resources of northwest Canada. The table generally

uses figures for in-place resources. The exceptions include figures for ultimate potential for Alberta’s

conventional gas and Coal Bed Methane (CBM) and figures for remaining proved reserves for conventional oil

and gas.

Compare the figure of 8,203 tcf for northwest Canada’s natural gas resources with proved reserves of 6,906 tcf

for the world in 2014 according to the U.S. EIA. U.S. proved reserves of natural gas in 2014 were 338 tcf.

Note that at least another half-dozen prospective shale formations are less completely evaluated in Alberta,

British Columbia, and Northwest Territories. And of course resource exploration and development in Canada’s

Northwest Territories, Yukon territory, Mackenzie Delta, Beaufort Sea, and Arctic Islands are in their infancy.

HYDROCARBON RESOURCES OF NORTHWEST CANADA

Area Formation Natural gas Gas liquids Oil Source

trillion cu. ft. billion bbl billion bbl

Alberta Oilsands Surface

mining

n.d. n.d. 130.9 AER (1)

In-situ n.d. n.d. 1,204.6 AER (1)

Alberta Bitumen

Carbonates

Grosmont n.d. n.d. 405.9 AER (1)

Nisku n.d. n.d. 102.1 AER (1)

Alberta Conventional Various 232 1.6 1.8 AER (1)

Alberta CBM Various 500 n.d. n.d. AER (1)

Alberta Shales

Duvernay 443 11.3 61.7 ERCB/AGS (2)

Muskwa 419 14.8 115.1 ERCB/AGS (2)

Montney 2,309 28.9 136.3 ERCB/AGS (2)

Nordegg 148 1.4 37.8 ERCB/AGS (2)

Wilrich 246 2.1 47.9 ERCB/AGS (2)

Banff/Exshaw 35 0.1 24.8 ERCB/AGS (2)

Alberta Tight Sands Cardium n.d. n.d. 9.1 NEB (3)

Saskatchewan Heavy Oil

Heavy Oil

Mannville n.d. n.d. 21.5 Sask. Gov’t (4)

Saskatchewan Oilsands Mannville n.d. n.d. 9.4 Oilsands Quest(5)

Saskatchewan Shale Bakken n.d. n.d. 71.0 NEB (6)

Sask. Conventional Various 1.8 n.d. 1.2 Sask. Gov’t (7)

British Columbia Shales

Montney 1965 96.3 2.8 NEB et al (8)

Horn River 448 n.d. n.d. NEB at al (9)

Liard 848 n.d. n.d. NEB at al (9)

BC Conventional Various 12.6 n.d. 0.1 BC Gov’t (10)

Yukon Shales Liard, Horn 68 n.d. n.d. NEB at al (11)

NWT Shales Liard, Horn 505 n.d. n.d. NEB at al (11)

Canol,

Bluefish

n.d. n.d. 191.2 NEB (12)

NWT Mainland Various 10.0 0.05 1.5 NEB (13)

NWT Arctic Islands Various 3.8 n.d. 0.3 NEB (13)

NWT Beaufort Sea Various 9.2 0.01 4.9 NEB (13)

TOTAL NORTHWEST

CANADA RESOURCES 8,203 157 2,582

Table 2. Hydrocarbon resources of northwest Canada. Source: Mike Priaro.

Key Issues

There are a number of key issues that must be resolved in order to achieve an integrated northwest Canada

energy corridor and pipeline hub:

1. Sufficient approvals are required from inland First Nations along the proposed route for an integrated

energy corridor containing an oil pipeline, a natural gas pipeline, a natural gas liquids pipeline, electric

power transmission lines, fibre-optic cables, and access roads.

2. Sufficient approvals are required from coastal First Nations for oil, LNG, and natural gas liquids marine

terminals in the Prince Rupert area.

3. Agreement by the Government of British Columbia is necessary that an integrated northwest Canada

energy corridor meets its five conditions for approval of a heavy oil pipeline through BC.

4. Waiver of the proposed federal tanker moratorium in northern waters off BC’s coast for terminals in the

Prince Rupert area is required.

5. Sufficient agreement is required from all other stakeholders that an integrated northwest Canada

energy corridor is the best solution to the economic, environmental and ecological issues surrounding

resource development.

Canadian Domestic Political Considerations

This proposed northwest Canada energy corridor respects the concerns, needs, legal responsibilities to, and

desires of, First Nations, as well as environmental concerns, far better than any of the other oil pipeline

proposals to Canada’s west coast – Enbridge’s Northern Gateway pipeline proposal and Kinder Morgan’s

Trans Mountain pipeline expansion proposal. It ties in very well with current Canadian federal government

priorities to improve the economic and social well-being of First Nations.

There must be direct, long-term economic benefit to First Nations from pipelines and facilities on First Nations

lands. This could be achieved through federal loans providing a measure of capital participation by affected

First Nations. There would also be significant benefit to First Nations, as well as project proponents, through

their involvement and assistance designing, constructing, operating, and managing the energy corridor and

associated pipelines and facilities with training provided by industry.

Co-ordinated leadership for an integrated northwest Canada energy/transportation corridor will challenge

Canadians. It is a complex mega-project that will require the leadership and support of the Canadian federal

government under Prime Minister Justin Trudeau and the federal Ministers of Transport, Natural Resources,

Environment, Infrastructure, and Indigenous and Northern Affairs, the provincial governments of Premiers Clark

and Notley of British Columbia and Alberta, First Nations, affected local municipalities, BC Hydro, Alberta

Energy, power companies, and, of course, companies in the oil and gas industry.

Mike Priaro, P.Eng.

Calgary, Alberta,

403-281-2156

Cited

1. Alberta Energy Regulator, ST98-2015: Alberta’s Energy Reserves 2014 and Supply/Demand Outlook

2015–2024 http://www.aer.ca/documents/sts/ST98/ST98-2015.pdf

2. Energy Resources Conservation Board/Alberta Geological Survey, Summary of Alberta's Shale- and

Siltstone-Hosted Hydrocarbons http://ags.aer.ca/document/OFR/OFR_2012_06.PDF

3. National Energy Board, Tight Oil Developments in the Western Canada Sedimentary Basin,

https://www.neb-one.gc.ca/nrg/sttstc/crdlndptrlmprdct/rprt/tghtdvlpmntwcsb2011/tghtdvlpmntwcsb2011-

eng.pdf

4. Government of Saskatchewan, Evaluation of Saskatchewan’s Heavy Oil Reserves,

http://publications.gov.sk.ca/documents/310/38724-Eval_Sask_Heavy_Oil.pdf

5. Oilsands Quest Inc., http://www.newswire.ca/news-releases/oilsands-quest-announces-reporting-of-the-

independent-estimate-of-discovered-resources-at-axe-lake-provides-activity-update-534587161.html ;

http://www.rigzone.com/news/oil_gas/a/43005/Oilsands_Quest_Issues_Ops_Update_Prelim_Bitumen_Res

erves_Estimate

6. National Energy Board, The Ultimate Potential for Unconventional Petroleum from the Bakken Formation of

Saskatchewan http://www.neb-one.gc.ca/nrg/sttstc/crdlndptrlmprdct/rprt/2015bkkn/2015bkkn-eng.pdf

7. Saskatchewan Government, http://www.economy.gov.sk.ca/5yr-oil-summary

http://www.economy.gov.sk.ca/5yr-gas-summary

8. NEB et al, The Ultimate potential for Unconventional Petroleum from the Montney Formation of British

Columbia and Alberta, http://www2.gov.bc.ca/assets/gov/farming-natural-resources-and-industry/natural-

gas-oil/petroleum-geoscience/oil-gas-reports/og_report_2013-1_montney_assessment.pdf

9. National Energy Board, Ultimate Potential for Unconventional Natural Gas in Northeastern British

Columbia’s Horn River Basin, http://www.empr.gov.bc.ca/OG/Documents/HornRiverEMA.pdf

10. Hydrocarbon and By-Product Reserves in British Columbia, 2013. https://www.bcogc.ca/node/12346/download

11. The Unconventional Gas Resources of Mississippian-Devonian Shales in the Liard Basin of British

Columbia, the Northwest Territories, and Yukon, March 2016, https://www.neb-

one.gc.ca/nrg/sttstc/ntrlgs/rprt/ltmtptntlbcnwtkn2016/index-eng.html

12. An Assessment of the Unconventional Petroleum Resources of the Bluefish Shale and the Canol Shale in

the Northwest Territories https://www.neb-one.gc.ca/nrg/sttstc/crdlndptrlmprdct/rprt/2015shlnt/index-

eng.html

13. Assessment of Discovered Conventional Petroleum Resources in the Northwest Territories and Beaufort

Sea, November, 2014. https://www.neb-one.gc.ca/nrth/pblctn/2014ptrlmrsrc/2014ptrlmrsrc-eng.pdf

Author Bio

Mike Priaro, B.Eng.Sc. (Chem. Eng.), U.W.O. '76, P.Eng., Lifetime Member Association of Professional

Engineers and Geoscientists of Alberta (APEGA), worked in facilities, production, operations and reservoir

engineering, as engineering consultant, area superintendent, and engineering management in Alberta's oil

patch for 25 years for companies such as Amoco and PetroCanada.”

He increased oil production from the historic Turner Valley oilfield and brought in under-balanced drilling and

completion technology to drill out, complete, and test several of the highest producing gas wells ever on

mainland Canada at Ladyfern. He co-authored ‘Advanced Fracturing Fluids Improve Well Economics’ in

Schlumberger's Oilfield Review and developed the course material for the ‘Advanced Production

Engineering’ course at Southern Alberta Institute of Technology.

Mike has presented his work to Canada’s House Committee on Natural Resources in Ottawa and had work

published by the Macdonald-Laurier Institute in the March and April, 2014 and February, 2015 editions

of Inside Policy magazine, by U.S. energy industry websites such as RBN Energy, in the July 17, 2014 edition

of the Oil and Gas Journal, in Petroleum Technology Quarterly, Q3 2014, and in several columns in the Calgary

Herald, Edmonton Journal, Montreal Gazette, Halifax Chronicle Herald, and others.

Mike has no formal connection to any oil company, environmental organization, think tank, labour organization,

lobbying or special interest group, academia, or to provincial or federal politics.

In 2015 Mike provided "A Preliminary Engineering, Economic, and Environmental Evaluation of ASRL's Partial

Upgrading Process" to Alberta Sulphur Research Limited and presented it to 80 representatives of ASRL's

member companies. ASRL partial upgrading subsequently obtained Alberta government funding and industry

support. On Jan. 29, 2016, the Alberta Government made partial upgrading a priority based on its Royalty

Review Panel’s recommendations. As of Sept., 2016 the ASRL partial upgrading flow test pilot is running at

CANMET/NRCan’s research facility in Devon, AB.

In 2016 Mike was invited to be a Bowman Centre Volunteer Associate at the not-for-profit Bowman Centre for

Sustainable Energy. Its goal is “to catalyze big energy projects which drive Canada’s energy strategy and

generate sustainable wealth and jobs”.

Mike’s work can be found on his LinkedIn pages: https://www.linkedin.com/in/mike-priaro or Behance website:

https://www.behance.net/Mike_Priaro

Mike is available for special projects and speaking engagements.