The Canadian petroleum industry developed in parallel with that one of the United States. The first oil well in Canada was dug by hand (rather than drilled) in 1858 by James Miller Williams near his asphalt plant at Oil Springs, Ontario. At a depth of 20 metres (66 ft) he struck oil, one year before "Colonel" Edwin Drake drilled the first oil well in the United States. Williams later went on to found "The Canadian Oil Company" which qualified as the world’s first integrated oil company.
Petroleum production in Ontario expanded rapidly, and practically every significant producer became his own refiner. By 1864, 20 refineries were operating in Oil Springs and seven in Petrolia, Ontario. However, Ontario's status as an important oil producer did not last long. By 1880 Canada was a net importer of oil from the United States.
Canada's unique geography, geology, resources and patterns of settlement have been key factors in the history of Canada. The development of the petroleum sector helps illustrate how they have helped make the nation quite distinct from the United States. Unlike the United States, which has a number of different major oil producing regions, the vast majority of Canada's petroleum resources are concentrated in the enormous Western Canadian Sedimentary Basin (WCSB), one of the largest petroleum-containing formations in the world. It underlies 1,400,000 square kilometres (540,000 sq mi) of Western Canada including most or part of four western provinces and one northern territory. Consisting of a massive wedge of sedimentary rock up to 6 kilometres (3.7 mi) thick extending from the Rocky Mountains in the west to the Canadian Shield in the east, it is far distant from Canada's east and west coast ports and well as its historical industrial centres. It is also far from American industrial centres. Because of its geographic isolation, the area was settled relatively late in the history of Canada, and its true resource potential was not discovered until after World War II. As a result, Canada built its major manufacturing centres near its historic hydroelectric power sources in Ontario and Quebec, rather than its petroleum resources in Alberta and Saskatchewan. Not knowing about its own potential, Canada began to import the vast majority of its petroleum from other countries as it developed into a modern industrial economy.
The province of Alberta lies at the centre of the WCSB and the formation underlies most of the province. The potential of Alberta as an oil-producing province long went unrecognized because it was geologically quite different from American oil producing regions. The first oil well in western Canada was drilled in southern Alberta in 1902, but did not produce for long and served to mislead geologists about the true nature of Alberta's subsurface geology. The Turner Valley oil field was discovered in 1914, and for a time was the biggest oil field in the British Empire, but again it misled geologists about the nature of Alberta's geology. In Turner Valley, the mistakes oil companies made led to billions of dollars in damage to the oil field by gas flaring which not only burned billions of dollars worth of gas with no immediate market, but destroyed the field's gas drive that enabled the oil to be produced. The gas flares in Turner Valley were visible in the sky from Calgary, 75 km (50 mi) away. As a result of the highly visible wastage, the Alberta government launched vigorous political and legal attacks on the Canadian Government and the oil companies that continued until 1938 when the province set up the Alberta Petroleum and Natural Gas Conservation Board and imposed strict conservation legislation.
The status of Canada as an oil importer from the US suddenly changed in 1947 when the Leduc No. 1 well was drilled a short distance south of Edmonton. Geologists realized that they had completely misunderstood the geology of Alberta, and the highly prolific Leduc oil field, which has since produced over 50,000,000 m3 (310,000,000 bbl) of oil was not a unique formation. There were hundreds more Devonian reef formations like it underneath Alberta, many of them full of oil. There was no surface indication of their presence, so they had to be found using reflection seismology. The main problem for oil companies became how to sell all the oil they had found rather than buying oil for their refineries. Pipelines were built from Alberta through the Midwestern United States to Ontario and to the west coast of British Columbia. Exports to the U.S. increased dramatically.
Most of the oil companies exploring for oil in Alberta were of U.S. origin, and at its peak in 1973, over 78 per cent of Canadian oil and gas production was under foreign ownership and over 90 per cent of oil and gas production companies were under foreign control, mostly American. This foreign ownership spurred the National Energy Program under the Trudeau government.
Although around a dozen companies operate oil refineries in Canada, only three companies - Imperial Oil, Shell Canada and Suncor Energy - operate more than one refinery and market products nationally. Other refiners generally operate a single refinery and market products in a particular region. Regional refiners include North Atlantic Refining in Newfoundland, Irving Oil in New Brunswick, Valero Energy in Quebec, Federated Co-operatives in Saskatchewan, Chevron in British Columbia, and Husky Energy in Alberta, BC, and Saskatchewan. While Petro Canada was once owned by the Canadian government, it is now owned by Suncor Energy, which continues to use the Petro Canada label for marketing purposes. In 2007 Canada's three biggest oil companies brought in record profits of $11.75 billion, up 10 percent from $10.72 billion in 2006. Revenues for the Big Three climbed to $80 billion from about $72 billion in 2006. The numbers exclude Shell Canada and ConocoPhillips Canada, two private subsidiaries that produced almost 500,000 barrels per day in 2006.EnCana Corporation
Canadian Natural Resources Limited
Husky Energy Inc.
Talisman Energy Inc.
Devon Canada Corporation
The vast majority (97%) of Canadian oil production occurs in three provinces: Alberta, Saskatchewan, and Newfoundland and Labrador. In 2015 Alberta produced 79.2% of Canada's oil, Saskatchewan 13.5%, and the province of Newfoundland and Labrador 4.4%. British Columbia and Manitoba produced about 1% apiece. The four Western Canada provinces of Alberta, British Columbia, Saskatchewan and Manitoba all produce their oil from the vast and oil rich Western Canadian Sedimentary Basin, which is centered on Alberta but extends into the other three Western provinces and into the Northwest Territories. The province of Newfoundland and Labrador produces its oil from offshore drilling on the Grand Banks of Newfoundland in the western Atlantic Ocean.
Alberta is Canada's largest oil producing province, providing 79.2% of Canadian oil production in 2015. This included light crude oil, heavy crude oil, crude bitumen, synthetic crude oil, and natural-gas condensate. In 2015 Alberta produced an average of 492,265 cubic metres per day (3.1 Mbbl/d) of Canada's 621,560 cubic metres per day (3.9 Mbbl/d) of oil and equivalent production. Most of its oil production came from its enormous oil sands deposits, whose production has been steadily rising in recent years. These deposits give Canada the world's third largest oil reserves, which are rivaled only by similar but even larger oil reserves in Venezuela, and conventional oil reserves in Saudi Arabia. Although Alberta has already produced over 90% of its conventional crude oil reserves, it has produced only 5% of its oil sands, and its remaining oil sands reserves represent 98% of Canada's established oil reserves.
In addition to being the world's largest producer of oil sands bitumen in the world, Alberta is the largest producer of conventional crude oil, synthetic crude, natural gas and natural gas liquids products in Canada.
Alberta's oil sands underlie 142,200 square kilometres (54,900 sq mi) of land in the Athabasca, Cold Lake and Peace River areas in northern Alberta - a vast area of boreal forest which is larger than England. The Athabasca oil sands is the only large oil field in the world suitable for surface mining, while the Cold Lake oil sands and the Peace River oil sands must be produced by drilling. With the advancement of extraction methods, bitumen and economical synthetic crude are produced at costs nearing that of conventional crude. This technology grew and developed in Alberta. Many companies employ both conventional strip mining and non-conventional methods to extract the bitumen from the Athabasca deposit. About 24 billion cubic metres (150 Gbbl) of the remaining oil sands are considered recoverable at current prices with current technology. The city of Fort McMurray developed nearby to service the oil sands operations, but its remote location in the otherwise uncleared boreal forest became a problem when the entire population of 80,000 had to be evacuated on short notice because of the 2016 Fort McMurray wildfire which enveloped the city and destroyed over 2,400 homes.
Major oil fields are found in southeast Alberta (Brooks, Medicine Hat, Lethbridge), northwest (Grande Prairie, High Level, Rainbow Lake, Zama), central (Caroline, Red Deer), and northeast (heavy crude oil found adjacent to the oil sands.)
Structural regions include: Foothills, Greater Arch, Deep Basin.
There are five oil sands upgraders in Alberta which convert crude bitumen to synthetic crude oil, some of which also produce refined products such as diesel fuel. These have a combined capacity of 1.3 million barrels per day (210,000 m3/d) of crude bitumen.The Shell Canada Scotford Upgrader at Fort Saskatchewan, Alberta has a capacity of 255,000 barrels per day (40,500 m3/d) of crude bitumen.
The Suncor Energy upgrader near Fort McMurray, Alberta has a capacity of 440,000 barrels per day (70,000 m3/d) of crude bitumen.
The Syncrude Mildred Lake upgrader near Fort McMurray has a capacity of 407,000 barrels per day (64,700 m3/d)
The China National Offshore Oil Corporation (CNOOC) Long Lake upgrader near Fort McMurray has a capacity of 72,000 barrels per day (11,400 m3/d)
The Canadian Natural Resources Ltd (CNRL) Horizon upgrader near Fort McMurray has a capacity of 156,000 barrels per day (24,800 m3/d)
Since it is Canada's largest oil producing province, Alberta is the hub of Canadian crude oil pipeline systems. About 415,000 kilometres (258,000 mi) of Canada’s oil and gas pipelines operate solely within Alberta’s boundaries and fall under the jurisdiction of the Alberta Energy Regulator. Pipelines that cross provincial or federal borders are regulated by the National Energy Board. Major pipelines carrying oil from Alberta to markets in other provinces and US states include:The Interprovincial Pipeline System (now called the Enbridge Pipeline System) was built in 1950 to transport crude oil from Edmonton, Alberta to Superior, Wisconsin where it supplies the Midwestern United States. In 1953 it was extended to Sarnia, Ontario to supply the Ontario market, and in 1976 to Montreal, Quebec.
The Trans Mountain Pipeline System (now operated by Kinder Morgan) was built in 1953 to transport crude oil and refined products from Edmonton to Vancouver, BC. It also supplies feedstock to large US oil refineries in the state of Washington. Only crude oil and condensate are shipped to the United States.
The Norman Wells Pipeline (now owned by Enbridge) was built in 1985 to carry crude oil from Norman Wells, NWT to Zama City, Alberta, where it connects with the Alberta pipeline network.
The Express Pipeline was built in 1997 to carry oil from the Alberta pipeline hub at Hardisty, Alberta to the US states of Montana, Utah, Wyoming and Colorado.
The Keystone Pipeline was built in 2011 to carry oil from Hardisty, Alberta to the major US pipeline hub at Cushing, Oklahoma, where it connects to pipelines to Texas, Louisiana, and many of the Eastern United States.
There are four oil refineries in Alberta with a combined capacity of over 458,200 barrels per day (72,850 m3/d) of crude oil. Most of these are located on what is known as Refinery Row in Strathcona County near Edmonton, Alberta, which supplies products to most of Western Canada. In addition to refined products such as gasoline and diesel fuel, the refineries and upgraders also produce off-gases, which are used as feedstock by nearby petrochemical plants.The Suncor Energy (Petro Canada) refinery near Edmonton has a capacity of 142,000 barrels per day (22,600 m3/d) of crude oil.
The Imperial Oil Strathcona Refinery near Edmonton has a capacity of 187,200 barrels per day (29,760 m3/d).
The Shell Canada Scotford Refinery near Edmonton has a capacity of 100,000 barrels per day (16,000 m3/d). It is located adjacent to the Shell Scotford Upgrader, which provides it with feedstock.
The Husky Lloydminster Refinery at Lloydminster, in eastern Alberta has a capacity of 29,000 barrels per day (4,600 m3/d). It is located across the provincial border from the Husky Lloydminster Heavy Oil Upgrader at LLoydminster, Saskatchewan, which provides it with feedstock. (Lloydminster is not a twin city but is chartered by both provinces as a single city that crosses the border.)
Other oil-related activities
Two of the largest producers of petrochemicals in North America are located in central and north central Alberta. In both Red Deer and Edmonton, world class polyethylene and vinyl manufacturers produce products shipped all over the world, and Edmonton's oil refineries provide the raw materials for a large petrochemical industry to the east of Edmonton. There are hundreds of small companies in Alberta dedicated to providing various services to this industry—from drilling to well maintenance, pipeline maintenance to seismic exploration.
While Edmonton (population 1.36 million in 2015) is the provincial capital and is considered the pipeline, manufacturing, chemical processing, research and refining centre of the Canadian oil industry, its rival city Calgary (population 1.44 million) is the main oil company head office and financial centre, with more than 960 senior and junior oil company offices. Calgary also has regional offices of all six major Canadian banks, some 4,300 petroleum, energy and related service companies, and 1,300 financial service companies, helping make it the second largest head office city in Canada after Toronto.Oil and gas activity is regulated by the Alberta Energy Regulator (AER) (Formerly the Alberta Energy Resources Conservation Board (ERCB)and the Energy and Utility Board (EUB)).
Saskatchewan is Canada's second largest oil-producing province after Alberta, producing about 13.5% of Canada's petroleum in 2015. This included light crude oil, heavy crude oil, and natural-gas condensate. Most of its production is heavy oil but, unlike Alberta, none of Saskatchewan's heavy oil deposits are officially classified as bituminous sands. In 2015 Saskatchewan produced an average of 83,814 cubic metres per day (527,000 bbl/d) oil and equivalent production.
All of Saskatchewan's oil is produced from the vast Western Canadian Sedimentary Basin, about 25% of which underlies the province. Lying toward the shallower eastern end of the sedimentary basin, Saskatchewan tends to produce more oil and less natural gas than other parts. It has four major oil producing regions:The Lloydminster area in west-central Saskatchewan has very large reserves of very heavy crude oil. (The oil field crosses the Alberta/Saskatchewan border, as do the production facilities.)
The Kindersley area in south-central Saskatchewan produces light crude oil using hydraulic fracturing from Saskatchewan's portion of the Bakken Formation, which also produces most of North Dakota's oil.
The Swift Current area in southwest Saskatchewan produces mostly conventional oil.
The Weyburn area in southeast Saskatchewan produces oil using carbon dioxide flooding in the Weyburn-Midale Carbon Dioxide Project, the world's largest carbon capture and storage project.
There are two heavy oil upgraders in Saskatchewan.The NewGrade Energy Upgrader, part of the CCRL Refinery Complex in Regina, processes 8,740 cubic metres per day (55,000 bbl/d) of heavy oil from the Lloydminster area into synthetic crude oil.
The Husky Energy Bi-Provincial Upgrader on the Saskatchewan side of Lloydminster processes 10,800 cubic metres per day (68,000 bbl/d) of heavy oil from Alberta and Saskatchewan to lighter crude oil. In addition to selling synthetic crude oil to other refineries, it supplies feedstock to the Husky Lloydminster Refinery on the Alberta side of the border. (Lloydminster is not twin cities but is a single bi-provincial city that straddles the Alberta/Saskatchewan border.)
The majority of the province's refining capacity is in a single complex in the provincial capital of Regina:The CCRL Refinery Complex operated by Federated Co-operatives in Regina processes 8,000 cubic metres per day (50,000 bbl/d) into conventional refinery products. It receives much of its feedstock from the NewGrade upgrader.
Moose Jaw Asphalt Inc. operates a 500 cubic metres per day (3,100 bbl/d) asphalt plant in Moose Jaw.
Oil and gas activity is regulated by the Saskatchewan Industry and Resources (SIR).
Newfoundland and Labrador is Canada's third largest oil producing province, producing about 4.4% of Canada's petroleum in 2015. This consisted almost exclusively of light crude oil produced by offshore oil facilities on the Grand Banks of Newfoundland. In 2015 these offshore fields produced an average of 27,373 cubic metres per day (172,000 bbl/d) of light crude oil.The Hibernia oil field is located approximately 315 kilometres (196 mi) east-southeast of St. John's, Newfoundland. The field was discovered in 1979 and has been producing since 1997. The Hibernia Gravity Base Structure is the world's largest oil platform by weight since it has to withstand collisions by icebergs.
The Terra Nova oil field is located 350 kilometres (220 mi) off the east coast of Newfoundland. The field was discovered in 1984 and has been producing since 2002. It uses a Floating Production Storage and Offloading (FPSO) vessel rather than a fixed platform to produce oil.
The White Rose oil field is located 350 kilometres (220 mi) off the east coast of Newfoundland. The field was discovered in 1984 and has been producing since 2005. It uses a FPSO vessel to produce oil.
Newfoundland has one oil refinery, the Come By Chance Refinery, which has a capacity of 115,000 barrels per day (18,300 m3/d). The refinery was built before the discovery of oil offshore Newfoundland to process cheap imported oil and sell the products mainly in the United States. Unfortunately the startup of the refinery in 1973 coincided with the 1973 oil crisis which quadrupled the price of the refinery's crude oil supply. This and technical problems caused the refinery to go bankrupt in 1976. It was restarted under new owners in 1986 and has gone through a series of owners until the present date when it is operated by North Atlantic Refining Limited. However despite the fact that major oil fields were subsequently discovered offshore of Newfoundland, the refinery was not designed to process the type of oil they produced, and it did not process any Newfoundland oil at all until 2014. Until then all of Newfoundland's production went to refineries in the United States and elsewhere in Canada, while the refinery imported all its oil from other countries.
British Columbia produced an average of 8,643 cubic metres per day (54,000 bbl/d) oil and equivalent in 2015, or about 1.4% of Canada's petroleum. About 38% of this liquids production was light crude oil, but most of it (62%) was natural-gas condensate.
British Columbia's oil fields lie at the gas-prone northwest end of the Western Canadian Sedimentary Basin, and its oil industry is secondary to the larger natural gas industry. Drilling for gas and oil takes place in Peace Country of north-eastern British Columbia, around Fort Nelson (Greater Sierra oil field), Fort St. John (Pink Mountain, Ring Border) and Dawson Creek
Oil and gas activity in BC is regulated by the Oil and Gas Commission (OGC).
BC has only two remaining oil refineries.The Husky Energy Prince George Refinery in Prince George, BC processes 12,000 barrels per day (1,900 m3/d) of light oil produced locally in northeastern BC.
The Chevron Canada Burnaby Refinery in the Vancouver suburb of Burnaby processes 55,000 barrels per day (8,700 m3/d) of light oil received from Alberta via the Kinder Morgan Trans Mountain Pipeline System.
There once were four oil refineries in the Vancouver area, but Imperial Oil, Shell Canada, and Petro Canada converted their refineries to product terminals in the 1990s and now supply the BC market from their large refineries near Edmonton, Alberta, which are closer to Canada's oil sands and largest oil fields. Chevron's refinery is at risk of closure due to difficulties in getting oil supply from Alberta via the capacity-limited Trans Mountain Pipeline, its only pipeline link to the rest of Canada.
In June 2016 Chevron put its oil refinery in Burnaby, BC up for sale, along with its fuel distribution network in British Columbia and Alberta. “The company acknowledges these are challenging times and we need to be open to changing market conditions and opportunities as they arise,” a company representative said. The refinery, which started production in 1935, has 430 employees. Chevron's offer to sell follows Imperial Oil's sale of 497 Esso gas stations in B.C. and Alberta. It is unclear what will happen if Chevron fails to sell its BC assets.
Manitoba produced an average of 7,283 cubic metres per day (46,000 bbl/d) of light crude oil in 2015, or about 1.2% of Canada's petroleum production.
Manitoba's oil production is in southwest Manitoba along the northeast flank of the Williston Basin, a large geological structural basin which also underlies parts of southern Saskatchewan, North Dakota, South Dakota and Montana. Unlike in Saskatchewan, very little of Manitoba's oil is heavy crude oil.A few rigs drilling for oil in South western Manitoba
There are no oil refineries in Manitoba.
The Northwest Territories produced an average of 1,587 cubic metres per day (10,000 bbl/d) of light crude oil in 2015, or about 0.2% of Canada's petroleum production. There is an historic large oil field at Norman Wells, which has produced most of its oil since it started producing 1937, and is continuing to produce at low rates. There used to be an oil refinery at Norman Wells, but it was closed in 1996 and all of the oil is now pipelined out to refineries in Alberta.Drilling for tight oil in the Canol shale play near Norman Wells by Husky Energy and others.
Extensive drilling was done in the Canadian Arctic during the 1970s and 1980s by such companies as Panarctic Oils Ltd., Petro Canada and Dome Petroleum. After 176 wells were drilled at a cost of billions of dollars, a modest 1.9 billion barrels (300×106 m3) of oil were found. None of the finds were big enough to pay for the multibillion-dollar production and transportation schemes required to bring the oil out, so all the wells which had been drilled were plugged and abandoned. In addition, after the Deepwater Horizon explosion in the Gulf of Mexico in 2010, new rules were introduced which discouraged companies from drilling in the Canadian Arctic offshore.There is currently no offshore oil production in northern Canada
There is currently no offshore drilling in northern Canada
Ontario produced an average of 157 cubic metres per day (1,000 bbl/d) of light crude oil in 2015, or less than 0.03% of Canada's petroleum production. Onshore production in other provinces east of Ontario was even more insignificant.
Ontario was the centre of the Canadian oil industry in the 19th century. It had the oldest commercial oil well in North America (dug by hand in 1858 at Oil Springs, Ontario, a year before the Drake Well was drilled in Pennsylvania), and having the oldest producing oil field in North America (producing crude oil continuously since 1861). However, it reached its production peak and started to decline more than 100 years ago.Sporadic drilling in southern Ontario
Sporadic drilling in western Newfoundland
Sporadic drilling in northern Nova Scotia and western Cape Breton Island
Sporadic drilling in northern and eastern Prince Edward Island
Canada had one of the world’s first oil pipelines in 1862 when a pipeline was built to deliver oil from Petrolia, Ontario to refineries at Sarnia, Ontario. However, Ontario's oil fields began to decline toward the end of the 19th century, and by World War II Canada was importing 90% of its oil. By 1947, only three Canadian crude oil pipelines existed. One was built to handle only Alberta production. A second moved imported crude from coastal Maine to Montreal, while the third brought American oil into Ontario. However, in 1947 the first big oil discovery was made in Alberta when Leduc No. 1 struck oil in a suburb of Edmonton, Alberta. It was followed by many even larger discoveries in Alberta, so pipelines were built to take the newly discovered oil to refineries in the American Midwest and from there to refineries in Ontario.The Interprovincial Pipeline (now known as Enbridge) was built in 1950 to take Alberta oil to US refineries. In 1953 it was extended through the US to Sarnia, Ontario and in 1956 to Toronto. This made it the longest crude oil pipeline in the world.
The Interprovincial Pipeline was extended to Montreal in 1976 after the 1973 oil crisis interrupted foreign oil supplies to Eastern Canada.
The Portland–Montreal Pipe Line was built during World War II to bring imported oil from the marine terminal at South Portland, Maine through the United States to Montreal. As of 2016, the pipeline is no longer operational since the only remaining Montreal Refinery, is now owned by Suncor Energy, which produces enough oil to meet its needs from the Canadian oil sands.
Despite having very little oil production, Eastern Canada has a large number of oil refineries. The ones in Ontario were built close to the historic oil fields of southern Ontario; the ones in provinces to the east were built to process oil imported from other countries. After Leduc No. 1 was discovered in 1947, the much larger oil fields in Alberta began to supply Ontario refineries. After the 1973 oil crisis drastically increased the price of imported oil, the economics of refineries became unfavorable, and many of them closed. In particular, Montreal, which had six oil refineries in 1973, now has only one.
OntarioNanticoke Refinery - (Imperial Oil), 112,000 bbl/d (17,800 m3/d)
Sarnia - (Imperial Oil), 115,000 bbl/d (18,300 m3/d)
Sarnia - (Suncor Energy), 85,000 bbl/d (13,500 m3/d)
Corunna - (Shell Canada), 72,000 bbl/d (11,400 m3/d)
Mississauga - (Suncor Energy), 15,600 bbl/d (2,480 m3/d)
QuebecMontreal Refinery - (Suncor Energy), 140,000 bbl/d (22,000 m3/d).
Lévis - (Valero Energy Corporation)), 265,000 bbl/d (42,100 m3/d)
New BrunswickIrving Oil Refinery, Saint John (Irving Oil), 300,000 bbl/d (48,000 m3/d)
Newfoundland and LabradorNorth Atlantic Refinery, Come By Chance - (North Atlantic Refining), 115,000 bbl/d (18,300 m3/d)
The province of Newfoundland and Labrador is Canada's third largest oil producer with 27,373 cubic metres per day (172,000 bbl/d) of light crude oil from its Grand Banks offshore oil fields in 2015, about 4.4% of Canada's petroleum. See the Newfoundland and Labrador section above for details. Most of the other offshore production was in the province of Nova Scotia, which produced 438 cubic metres per day (2,750 bbl/d) of natural gas condensate from its Sable Island offshore natural gas fields in 2015, or about 0.07% of Canada's petroleum.Offshore oil drilling and production at Hibernia, Terra Nova, and White Rose fields off the coast of Newfoundland
Offshore gas drilling and production on Sable Island fields off the coast of Nova Scotia
Sporadic drilling along continental shelf off Nova Scotia (e.g. Shelburne Basin)
Sporadic drilling in Laurentian fan at southern end of Cabot Strait
Sporadic drilling in eastern Northumberland Strait
Oil Production In North America
Broadly speaking Canadian conventional oil production (via standard deep drilling) peaked in the mid-1970s, but East Coast offshore basins being exploited in Atlantic Canada did not peak until 2007 and are still producing at relatively high rates.
Production from the Alberta oil sands is still in its early stages and the province's established bitumen resources will last for generations into the future. The Alberta Energy Regulator estimates that the province has 50 billion cubic metres (310,000 MMbbl) of ultimately recoverable bitumen resources. At the 2014 production rate of 366,300 cubic metres per day (2.3 Mbbl/d), they would last for about 375 years. The AER projects that bitumen production will increase to 641,800 cubic metres per day (4.0 Mbbl/d) by 2024, but at that rate they would still last for about 213 years. Because of the enormous size of the known oil sands deposits, economic, labor, environmental, and government policy considerations are the constraints on production rather than finding new deposits.
In addition, the Alberta Energy Regulator has recently identified over 67 billion cubic metres (420 Gbbl) of unconventional shale oil resources in the province. This volume is larger than the province's oil sands resources, and if developed would give Canada the largest crude oil reserves in the world. However, due to the recent nature of the discoveries there are not yet any plans to develop them.
These oil fields are or were economically important to the Canadian economy:Oil Springs, Ontario
Turner Valley oil field, Alberta
Leduc oil field, Alberta
Pembina oil field, Alberta
Athabasca oil sands, Alberta
Peace River oil sands, Alberta
Cold Lake oil sands, Alberta
Duvernay Formation, Alberta (shale oil and gas)
Montney Formation, Alberta, BC (shale oil and gas)
Hibernia oil field, offshore Newfoundland
Terra Nova oil field, offshore Newfoundland
White Rose oil field, offshore Newfoundland
There are three components of the Canadian petroleum industry: upstream, midstream and downstream.
The upstream oil sector is also commonly known as the exploration and production (E&P) sector.
The upstream sector includes the searching for potential underground or underwater crude oil and natural gas fields, drilling of exploratory wells, and subsequently drilling and operating the wells that recover and bring the crude oil and/or raw natural gas to the surface. With the development of methods for extracting methane from coal seams, there has been a significant shift toward including unconventional gas as a part of the upstream sector, and corresponding developments in liquified natural gas (LNG) processing and transport. The upstream sector of the petroleum industry includes Extraction of petroleum, Oil production plant, Oil refinery and Oil well.
The midstream sector involves the transportation (by pipeline, rail, barge, or truck), storage, and wholesale marketing of crude or refined petroleum products. Pipelines and other transport systems can be used to move crude oil from production sites to refineries and deliver the various refined products to downstream distributors. Natural gas pipeline networks aggregate gas from natural gas purification plants and deliver it to downstream customers, such as local utilities. The midstream operations are often taken to include some elements of the upstream and downstream sectors. For example, the midstream sector may include natural gas processing plants which purify the raw natural gas as well as removing and producing elemental sulfur and natural gas liquids (NGL) as finished end-products. Midstream service providers in Canada refer to Barge companies, Railroad companies, Trucking and hauling companies, Pipeline transport companies, Logistics and technology companies, Transloading companies and Terminal developers and operators. Development of the massive oil sand reserves in Alberta would be facilitated by development of a North American pipeline network which would transport dilbit to refineries or export facilities.
Canada's oil sands for example are landlocked and it is crucial to the petroleum industry that transportation of petroleum products keep pace with production. Currently landlocked Canadian oil sands petroleum products suffer huge losses on price differentials. Until Canadian crude oil, Western Canadian Select, accesses international prices like LLS or Maya crude oil by getting to tidewater (south to the US Gulf ports via Keystone XL for example, west to the BC Pacific coast via the proposed Northern Gateway line to ports at Kitimat, BC or north via the northern hamlet of Tuktoyaktuk, near the Beaufort Sea., the Alberta government (and to some extent, the Canadian government) loses from $4 billion to $30 billion in tax and royalty revenues, because the primary product of the oil sands, Western Canadian Select (WCS), the bitumen crude oil basket, is discounted so heavily against West Texas Intermediate (WTI) while Maya crude oil, a similar product close to tidewater, is reaching peak prices. Calgary-based Canada West Foundation warned in April 2013, that Alberta is "running up against a [pipeline capacity] wall around 2016, when we will have barrels of oil we can’t move."
Frustrated by delays in getting approval for Keystone XL (via the US Gulf of Mexico), the Enbridge Northern Gateway Pipelines (via Kitimat, BC) and the expansion of the existing TransMountain line to Vancouver, British Columbia, Alberta has intensified exploration of two northern projects "to help the province get its oil to tidewater, making it available for export to overseas markets." Under Prime Minister Stephen Harper, the Canadian government spent $9 million by May, 2012, and $16.5 million by May, 2013, to promote Keystone XL.
In the United States, Democrats are concerned that Keystone XL would simply facilitate getting Alberta oil sands products to tidewater for export to China and other countries via the American Gulf Coast of Mexico.
Port Metro Vancouver has a number of petroleum terminals, including: Suncor's Burrard Products Terminal, Imperial Oil Limited'a Ioco in Burrard Inlet East, Kinder Morgan Westridge Kinder Morgan Westridge in Burnaby, Shell Canada's Shellburn, Chevron Canada Ltd.'s Stanovan in Burnaby.
The downstream sector commonly refers to the refining of petroleum crude oil and the processing and purifying of raw natural gas, as well as the marketing and distribution of products derived from crude oil and natural gas. The downstream sector touches consumers through products such as gasoline or petrol, kerosene, jet fuel, diesel oil, heating oil, fuel oils, lubricants, waxes, asphalt, natural gas, and liquified petroleum gas (LPG) as well as hundreds of petrochemicals. Midstream operations are often included in the downstream category and considered to be a part of the downstream sector.
Crude oil, for example, Western Canadian Select (WCS) is a mixture of many varieties of hydrocarbons and most usually has many sulfur-containing compounds. The refining process converts most of that sulfur into gaseous hydrogen sulfide. Raw natural gas also may contain gaseous hydrogen sulfide and sulfur-containing mercaptans, which are removed in natural gas processing plants before the gas is distributed to consumers. The hydrogen sulfide removed in the refining and processing of crude oil and natural gas is subsequently converted into byproduct elemental sulfur. In fact, the vast majority of the 64,000,000 metric tons of sulfur produced worldwide in 2005 was byproduct sulfur from refineries and natural gas processing plants.
See also Energy policy of Canada
The jurisdiction over the petroleum industry in Canada, which includes energy policies regulating the petroleum industry, is shared between the federal and provincial and territorial governments. Provincial governments have jurisdiction over the exploration, development, conservation, and management of non-renewable resources such as petroleum products. Federal jurisdiction in energy is primarily concerned with regulation of inter-provincial and international trade (which included pipelines) and commerce, and the management of non-renewable resources such as petroleum products on federal lands.
Oil and Gas Policy and Regulatory Affairs Division (Oil and Gas Division) of Natural Resources Canada (NRCan) provides an annual review of and summaries of trending of crude oil, natural gas and petroleum product industry in Canada and the United States (US)
The petroleum industry is also regulated by the National Energy Board (NEB), an independent federal regulatory agency. The NEB regulates inter-provincial and international oil and gas pipelines and power lines; the export and import of natural gas under long-term licenses and short-term orders, oil exports under long-term licenses and short-term orders (no applications for long-term exports have been filed in recent years), and frontier lands and offshore areas not covered by provincial/federal management agreements.
In 1985, the federal government and the provincial governments in Alberta, British Columbia and Saskatchewan agreed to deregulate the prices of crude oil and natural gas. Offshore oil Atlantic Canada is administered under joint federal and provincial responsibility in Nova Scotia and Newfoundland and Labrador.
There were few regulations in the early years of the petroleum industry. In Turner Valley, Alberta for example, where the first significant field of petroleum was found in 1914, it was common to extract a small amount of petroleum liquids by flaring off about 90% of the natural gas. According to a 2001 report that amount of gas that would have been worth billions. In 1938 the Alberta provincial government responded to the conspicuous and wasteful burning of natural gas. By the time crude oil was discovered in the Turner Valley field, in 1930, most of the free gas cap had been flared off. The Alberta Petroleum and Natural Gas Conservation Board (today known as the Energy Resources Conservation Board) was established in 1931 to initiate conservation measures but by that time the Depression caused a waning of interest in petroleum production in Turner Valley which was revived from 1939-1945.