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Canadian oil production: conventional crude oil in red, and total petroleum liquids, including from oil sands, in blackPetroleum production in Canada is a which is important to the. Has the third largest in the world and is the world's fourth largest and fourth largest. In 2017 it produced an average of 667,747 cubic metres per day (4.2 Mbbl/d) of and equivalent.

Resource Tip: Industry guidebook for heavy oil and oil sands industry, online and in print. Description: The annual playbook for one of Canada s most important and dynamic industries, The Heavy Oil & Oilsands Guidebook examines heavy oil and oilsands development and its influencing factors holistically, providing an invaluable and unique. Oct 22, 2019  According to Mr. Krausert, Canadian energy industry and its technology could be part of the global solution to climate change – such as displacing coal at power plants in Asia with natural gas.

Of that amount, 64% was upgraded and non-upgraded bitumen from, and the remainder,. Most of Canadian petroleum production is exported, approximately 482,525 cubic metres per day (3 Mbbl/d) in 2015, with almost all of the exports going to the United States.

Canada is by far the largest single source of oil imports to the United States, providing 43% of US crude oil imports in 2015.The in Canada is also referred to as the Canadian 'Oil Patch'; the term refers especially to operations (exploration and production of oil and gas), and to a lesser degree to operations (refining, distribution, and selling of oil and gas products). In 2005, almost 25,000 new were spudded (drilled) in Canada. Daily, over 100 new wells are spudded in the province of alone. Although Canada is one of the largest oil producers and exporters in the world, it also imports significant amounts of oil into its eastern provinces since its oil pipelines do not extend all the way across the country and many of its oil refineries cannot handle the types of oil its oil fields produce. In 2017 Canada imported 405,700 bbl/day (barrels per day) and exported 1,115,000 bbl/day of refined petroleum products. Main article:The Canadian petroleum industry developed in parallel with that of the United States.

The first oil well in Canada was dug by hand (rather than drilled) in 1858 by near his asphalt plant at. At a depth of 4.26 metres (14.0 ft) he struck oil, one year before 'Colonel' 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.Petroleum production in Ontario expanded rapidly, and practically every significant producer became his own. By 1864, 20 refineries were operating in Oil Springs and seven in. 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. Western Canadian Sedimentary Basin Most of Canada's oil and gas production occurs in the which stretches from southwestern to northeastern.

The basin also covers most of Alberta, the southern half of and the southwest corner of the.Canada's unique, resources and patterns of settlement have been key factors in the. The development of the 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 (WCSB), one of the largest petroleum-containing formations in the world.

It underlies 1,400,000 square kilometres (540,000 sq mi) of including most or part of four western provinces and one northern territory. Consisting of a massive wedge of up to 6 kilometres (3.7 mi) thick extending from the in the west to the in the east, it is far distant from Canada's as well as its. It is also far from. 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 near its historic 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 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 oil field was discovered in 1914, and for a time was the biggest oil field in the, 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 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 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 m 3 (310,000,000 bbl) of oil was not a unique formation.

There were hundreds more 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. 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 under the government. Major players. Main article:Although around a dozen companies operate oil refineries in Canada, only three companies –, and – 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 in Newfoundland, in New Brunswick, in Quebec, in Saskatchewan, in British Columbia, and in Alberta, BC, and Saskatchewan. While was once owned by the Canadian government, it is now, 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.Divisions The vast majority (97%) of Canadian oil production occurs in three provinces:,. In 2015 Alberta produced 79.2% of Canada's oil, Saskatchewan 13.5%, and the province of Newfoundland and Labrador 4.4%.

And produced about 1% apiece. The four provinces of Alberta, British Columbia, Saskatchewan and Manitoba all produce their oil from the vast and oil rich, which is centered on Alberta but extends into the other three Western provinces and into the. The province of Newfoundland and Labrador produces its oil from on the in the western. Oil extraction nearis Canada's largest oil producing province, providing 79.2% of Canadian oil production in 2015. This included,. 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 deposits, whose production has been steadily rising in recent years.

These deposits give Canada the world's third, which are rivaled only by similar but even larger, and conventional. 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, and products in Canada.Oil sands 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 which is larger than. The is the only large oil field in the world suitable for, while the and the 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 developed nearby to service the oil sands operations, but its remote location in the otherwise uncleared became a problem when the entire population of 80,000 had to be evacuated on short notice because of the which enveloped the city and destroyed over 2,400 homes. Oil fields Major are found in southeast (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.Oil upgraders There are five oil sands in Alberta which convert crude bitumen to synthetic crude oil, some of which also produce refined products such as diesel fuel. Drilling rig in northernproduced 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, but most of it (62%) was.British Columbia's oil fields lie at the gas-prone northwest end of the, and its oil industry is secondary to the larger natural gas industry.

Drilling for gas and oil takes place in of north-eastern, around , (Pink Mountain, Ring Border) andOil and gas activity in BC is regulated by the Oil and Gas Commission (OGC). Oil refineries BC has only two remaining oil refineries. The in processes 12,000 barrels per day (1,900 m 3/d) of light oil produced locally in northeastern BC. The in the Vancouver suburb of processes 55,000 barrels per day (8,700 m 3/d) of light oil received from Alberta via the.There once were four oil refineries in the Vancouver area, but, and converted their refineries to product terminals in the 1990s and now supply the BC market from their large refineries near, 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. 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 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, a large geological which also underlies parts of southern Saskatchewan, North Dakota, South Dakota and Montana. Unlike in Saskatchewan, very little of Manitoba's oil is. A few rigs drilling for oil in South western ManitobaThere are no oil refineries in Manitoba.Northern Canada (onshore) The produced an average of 1,587 cubic metres per day (10,000 bbl/d) of in 2015, or about 0.2% of Canada's petroleum production.

There is an historic large oil field at, 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 in the near Norman Wells by and others.Northern Canada (offshore). See also:Extensive drilling was done in the during the 1970s and 1980s by such companies as,. After 176 wells were drilled at a cost of billions of dollars, a modest 1.9 billion barrels (300 × 10 ^ 6 m 3) 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 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 CanadaEastern Canada (onshore) produced an average of 157 cubic metres per day (1,000 bbl/d) of in 2015, or less than 0.03% of Canada's petroleum production. Onshore production in other provinces east of Ontario was even more insignificant. Oil fields 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, a year before the was in ), 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. Sporadic drilling in western. Sporadic drilling in northern and western. Sporadic drilling in northern and easternOil pipelines Canada had one of the world’s first oil pipelines in 1862 when a pipeline was built to deliver oil from to refineries at. 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 to, while the third brought American oil into Ontario. However, in 1947 the first big oil discovery was made in Alberta when struck oil in a suburb of. It was followed by many even larger discoveries in Alberta, so pipelines were built to take the newly discovered oil to refineries in the and from there to refineries in Ontario.

The Interprovincial Pipeline (now known as ) was built in 1950 to take Alberta oil to US refineries. In 1953 it was extended through the US to and in 1956 to. This made it the longest crude oil pipeline in the world. The Interprovincial Pipeline was extended to in 1976 after the interrupted foreign oil supplies to Eastern Canada. The was built during to bring imported oil from the marine terminal at through the United States to. As of 2016, the pipeline is no longer operational since the only remaining, is now owned by, which produces enough oil to meet its needs from the Canadian oil sands.Oil refineries 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 was discovered in 1947, the much larger oil fields in Alberta began to supply Ontario refineries. After the drastically increased the price of imported oil, the economics of refineries became unfavorable, and many of them closed. Mexican production peaked in 2004 and is now in declineBroadly speaking Canadian conventional oil production (via standard deep drilling) peaked in the mid-1970s, but being exploited in Atlantic Canada did not peak until 2007 and are still producing at relatively high rates.Production from the Alberta is still in its early stages and the province's established bitumen resources will last for generations into the future. The estimates that the province has 50 (310 billion ) of ultimately recoverable bitumen resources. At the 2014 production rate of 366,300 m 3/d (2.3 million bbl/d), they would last for about 375 years.

Overview of an oil pipeline system from the wellhead to downstream consumers Midstream The midstream sector involves the transportation, storage, and wholesale marketing of crude or refined petroleum products. Canada has a large network of - over 840,000 km - that transport crude oil and natural gas across the country. There are four main pipeline groups: gathering, feeder, transmission, and distribution pipelines.

Gathering pipelines transport crude oil and natural gas from wells drilled in the subsurface to oil batteries or natural gas processing facilities. The majority of these pipelines are found in petroleum producing areas in Western Canada. Feeder pipelines move crude oil, natural gas, and natural gas liquids (NGLs) from the batteries, processing facilities, and storage tanks to the long-distance portion of the transportation system: transmission pipelines. These are the major carriers of crude oil, natural gas, and NGLs within provinces and across provincial or international borders, where the products are either sent to refineries or exported to other markets. Finally, distribution pipelines are the conduit for delivering natural gas to downstream customers, such as local utilities, and then further distributed to homes and businesses. If pipelines are near capacity or non-existent in certain areas, crude oil is then transported over land by or, or over water by.The midstream operations are often taken to include some elements of the upstream and downstream sectors.

For example, the midstream sector may include plants which purify the raw natural gas as well as removing and producing and as finished end-products. Midstream service providers in Canada refer to companies, companies, companies, companies, and companies, companies and Terminal developers and operators.

Development of the massive oil sand reserves in Alberta would be facilitated by enhancing the which would transport to refineries or export facilities. Downstream The downstream sector commonly refers to the and the, as well as the marketing and distribution of. The downstream sector touches consumers through products such as, and as well as hundreds of.

Midstream operations are often included in the downstream category and considered to be a part of the downstream sector.Crude oil Crude oil, for example, (WCS) is a mixture of many varieties of and most usually has many. The refining process converts most of that sulfur into gaseous. Raw natural gas also may contain gaseous hydrogen sulfide and sulfur-containing, which are removed in plants before the gas is distributed to consumers. The 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.

Export capacity Total Canadian crude oil production, most of which is coming from the (WCSB), is forecast to increase from 3.85 million barrels per day (b/d) in 2016 to 5.12 million b/d by 2030. Supply from the Alberta oil sands accounts for most of the growth and is expected to increase from 1.3 million b/d in 2016 to 3.7 million b/d in 2030.

Bitumen from the oil sands requires blending with a in order to decrease its viscosity and density so that it can easily flow through pipelines. The addition of diluent will add an estimated 200,000 b/d to the total volumes of crude oil in Canada, for a total of 1.5 million extra barrels per day requiring the creation of additional transport capacity to markets. The current takeaway capacity in Western Canada is tight, as oil producers are beginning to outpace the movement of their products.Pipeline capacity measurements are complex and subject to variability. They depend on a number of factors, such as the type of product being transported, the products it is mixed with, pressure reductions, maintenance, and pipeline configurations. The major oil pipelines exiting Western Canada have a design transport capacity of 4.0 million b/d. In 2016, however, the pipeline capacity was estimated at 3.9 million b/d, and in 2017 the Canadian Association of Petroleum Producers (CAPP) estimated the pipeline capacity to be 3.3 million b/d. The lack of available pipeline capacity for petroleum forces oil producers to look to alternative transport methods, such as rail.Crude-by-rail shipments are expected to increase as existing pipelines reach capacity and proposed pipelines experience approval delays.

The rail loading capacity for crude in Western Canada is close to 1.2 million b/d, although this varies depending on several factors including the length of the unit trains, size and type of railcars used, and the types of crude oil loaded. Other studies, however, estimate the current rail loading capacity in Western Canada to be 754,000 b/d.

The (IEA) forecasts that crude-by-rail exports will increase from 150,000 b/d in late 2017 to 390,000 b/d in 2019, which is much greater than the record high of 179,000 b/d in 2014. The IEA also warns that rail shipments could reach as high as 590,000 b/d in 2019 unless producers store their produced crude during peak months. The oil industry in the WCSB may need to continue to rely on rail in the forecastable future, as no major new pipeline capacity is expected to be available before 2019. The capacity - to a certain extent - is there, but producers must be willing to pay a premium to move crude by rail.Getting to tidewater Canada has had access to western tide water since 1953, with a capacity of roughly 200,000 - 300,000 bpd via the Kinder Morgan Pipeline.

There is a myth perpetuated in Canadian media that Canadian WCS oil producers will have better access to “international prices” with greater access to tidewater, however, this claim does not take into account existing access. Shipments to Asia reached their peak in 2012 when the equivalent of nine fully loaded tankers of oil left Vancouver for China. Since then, oil exports to Asia have completely dropped off to the point at which China imported only 600 barrels of oil in 2017. With regard to the claim that Canada does not have access to “international prices”, many economists decry the concept that Canada does have access to the globalized economy as ridiculous and attribute the price differential to the costs of shipping heavy, sour crude thousands of kilometres, compounded by over supply in the destinations able to process aforementioned oil. Due to a doubling of a “production and export” model bet on by the biggest players in the tar sands, producers have recently (2018) encountered an over supply problem, and have sought further government subsidies to lessen the blow of their financial miscalculations earlier this decade.Preferred access ports include the US Gulf ports via the pipeline to the south, the British Columbia Pacific coast in via the, and the line to Vancouver, BC.

Frustrated by delays in getting approval for, the, and the expansion of the existing Trans Mountain line to, Alberta has intensified exploration of northern projects, such as building a pipeline to the northern hamlet of near the, 'to help the province get its oil to tidewater, making it available for export to overseas markets'. Under Prime Minister, 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.In 2013, Generating for Seven Generations (G7G) and received $1.8 million in funding from to study the feasibility of building a railway from northern Alberta to the Port of. The proposed 2,440-km railway would be capable of transporting 1 million to 1.5 million b/d of bitumen and petroleum products, as well as other commodities, to tidewater (avoiding the along British Columbia's northern coast). The last leg of the route - through the coastal mountain range to Valdez - was not deemed economically feasible by rail; an alternative, however, may be the transfer of products to the underutilized (TAPS) to Valdez.Port Metro Vancouver has a number of petroleum terminals, including Suncor Burrard Terminal in Port Moody, Imperial Oil Ioco Terminal in Burrard Inlet East, and Kinder Morgan Westridge, Shell Canada Shellburn, and Chevron Canada Stanovan terminals in Burnaby. Pipeline versus rail debate The public debate surrounding the trade-offs between pipeline and rail transportation has been developing over the past decade as the amount of crude oil transported by rail has increased.

It was invigorated in 2013 after the deadly in Quebec when a freight train derailed and spilled 5.56 million litres of crude oil, which resulted in explosions and fires that destroyed much of the town's core. That same year, a train carrying propane and crude derailed near Gainford, Alberta, resulting in two explosions but no injuries or fatalities. These, among other examples, have raised concerns that the regulation of rail transport is inadequate for large-scale crude oil shipments.

Pipeline failures also occur, for instance, in 2015 a pipeline ruptured and leaked 5 million litres of crude oil over approximately 16,000 m 2 at the company's oilsands facility south of Fort McMurray. Although both pipeline and rail transportation are generally quite safe, neither mode is without risk.

Numerous studies, however, indicate that pipelines are safer, based on the number of occurrences (accidents and incidents) weighed against the quantity of product transported. Between 2004 and 2015, the likelihood of rail accidents in Canada was 2.6 times greater than for pipelines per thousand barrels of oil equivalents (Mboe).

Natural gas products were 4.8 times more likely to have a rail occurrence when compared to similar commodities transported by pipelines. Critics question if pipelines carrying diluted bitumen from Alberta's oil sands are more likely to corrode and cause incidents, but evidence shows the risk of corrosion being no different than that of other crude oils. Costs A 2017 study by the found that contrary to popular belief, the sum of air pollution and (GHG) emissions costs is substantially larger than accidents and spill costs for both pipelines and rail.

For crude oil transported from the North Dakota, air pollution and greenhouse gas emission costs are substantially larger for rail compared to pipeline. For pipelines and rail, the 's (PHMSA) central estimate of spill and accident costs is US$62 and US$381 per million-barrel miles transported, respectively.

Total GHG and air pollution costs are 8 times higher than accident and spills costs for pipelines (US$531 vs US$62) and 3 times higher for rail (US$1015 vs US$381).Finally, transporting oil and gas by rail is generally more expensive for producers than transporting it by pipeline. On average, it costs between US$10-$15 per barrel to transport oil and gas by rail compared to $5 a barrel for pipeline. In 2012,16 million barrels of oil were exported to USA by rail. By 2014, that number increased to 59 million barrels. Although quantities decreased to 48 million in 2017, the competitive advantages offered by rail, particularly its access to remote regions as well as lack of regulatory and social challenges compared with building new pipelines, will likely make it a viable transportation method for years to come.

Both forms of transportation play a role in moving oil efficiently, but each has its unique trade-offs in terms of the benefits it offers.Regulatory agencies in Canada See alsoThe jurisdiction over the petroleum industry in Canada, which includes energy policies regulating the petroleum industry, is shared between the. Provincial governments have jurisdiction over the exploration, development, conservation, and management of such as petroleum products. Federal jurisdiction in energy is primarily concerned with regulation of inter-provincial and (which included pipelines) and commerce, and the management of non-renewable resources such as petroleum products on. Natural Resources Canada (NRCan) 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) National Energy Board The petroleum industry is also regulated by the (NEB), an independent federal. The NEB regulates inter-provincial and international oil and gas and; 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 and not covered by provincial/federal management agreements.In 1985, the federal government and the provincial governments in, and agreed to the prices of crude oil and natural gas.

Offshore oil is administered under joint federal and provincial responsibility in. Provincial regulatory agencies There were few regulations in the early years of the petroleum industry.

In, 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 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 ) 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 to 1945. See also.