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health magazine april 2011

Athabasca Oil Sands

History
The Athabasca oil sands are the Athabasca River to the designated cuts through the heart of the deposit, and the traces of heavy oil readily observed on the shore. Historically, the bitumen from the indigenous Cree and Dene aboriginal, waterproof their canoes used. The oil reserves are inside the Boundaries of the contract is 8, and several First Nations in the region are involved with the sand.
Athabasca oil sands on the banks of the river, c. 1900
The Athabasca oil sands first came to the attention of European fur traders in 1719, when Wa-pa-su, a Cree dealer, brought a sample of bituminous sands, the Hudson Bay Company post at York Factory on Hudson Bay where Henry Kelsey was the manager. In 1778, Peter Pond, fur trader and another one of the founders of the rival North West Company the first European to see Athabasca deposits, after the discovery of methylated Portage, the access to the rich fur resources of the Athabasca River system from the Hudson Bay Watershed permits.
In 1788, fur trader Alexander Mackenzie (who later discovered routes in both the Arctic and the Pacific from this area) wrote: "When about 24 miles (39 km) from the fork (the Athabasca and Clearwater Rivers) are some bituminous fountains into which a pole of 20 feet (6.1 meters) long, can, without the least resistance be inserted. The bitumen is in a liquid state and when mixed with glue, the resinous substance collected from the spruce, it serves to gum the Indians' canoes. "He in 1799 was followed by David Thompson and Map Maker in 1819 by British naval officer Sir John Franklin.
Sir John Richardson, the first geological evaluation of oil sands in 1848 on his way north to the lost Franklin expedition search. The first state-funded study of the oil sands was initiated in 1875 by John Macoun, and in 1883, GC Hoffman tried by the Geological Survey of Canada separates the bitumen from oil sand with the use of water and reported that it separated easily. In 1888, Dr. Robert Bell, Director of the Geological Survey of Canada reported that a Senate committee that "the evidence points to the existence … in the Athabasca and Mackenzie valleys of the largest petroleum Field in America, if not the world. "
In 1926, Dr. Karl Clark of the University of Alberta, a hot water separation process, the basis of today's thermal Extraction process was perfected. Several attempts to implement them had varying degrees of success, but it was 1967 before the first commercial operation began with the opening of Great Canadian Oil Sands (now Suncor) plant using surfactants in the separation procedure by Dr. Earl W. Malmberg developed by Sun Oil Company.
Oil sands production
The commercial production of oil from the Athabasca oil sands began in 1967 when large Canadian Oil Sands Limited (then a subsidiary of Sun Oil Company, but now an independent company known as Suncor Energy) opened the first mine, producing 30,000 barrels per day (4,800 m3 / d) of synthetic crude oil. The development was inhibited by the fall in oil prices on the world market, and the second mine, operated by the Syncrude consortium does not start until 1978, after the oil crisis of 1973 aroused the interest of investors. However, the oil price put later, in the 1979 energy crisis caused oil prices head back, discouraged the introduction of the National Energy Program of Pierre Trudeau foreign investment in the Canadian oil industry. In the 1980s the oil price dropped to a very low level, substantial reductions in the oil industry, and the third mine, operated by Shell Canada not begin until 2003. But as a result of rising oil prices since 2003, the existing Were greatly expanded and new mines are being planned.
According to the Alberta Energy and Utilities Board, 2005 production of crude bitumen in the Athabasca oil sands was as follows:
2005 Production
m3/day
bbl / day
Suncor mine
31 000
195 000
Syncrude Mine
41 700
262 000
Shell Canada Mine
26 800
169 000
In-situ projects
21 300
134 000
TOTAL
120 800
760 000
2006, as output from oil sands production 1.126 million Barrels per day (179,000 m3 / d) increases. Oil sands were the source for 62% of the total oil production and Alberta 47% of all oil produced in Canada. The Government of Alberta believes that this level of production could reach 3 Mbbl / d (480,000 m3 / d) by 2020 and possibly 5 Mbbl / d (790,000 m3 / d) in 2030.
Future Production
In December 2008, revised the Canadian Association of Petroleum Producers its 2008-2020 forecasts for crude oil project cancellations and reductions as a result of Price declines in the second half of the year statements for 2008. The revised forecast predicted that the Canadian oil sands production would continue to grow, but in a slower pace than previously predicted. It would be only minimal changes to 2008-2012 production, but by 2020 production was 300,000 barrels per day (48,000 m3 / d) less than its previous forecast. This would mean that the Canadian oil sands production will grow from 1.2 million barrels per day (190,000 m3 / d) at 2008-3300000 Barrels per day (520,000 m3 / d) in 2020, that total Canadian oil production to grow 2.7 to 4.1 million barrels per day (430000-650000 m3 / d) in 2020. Even if the project cancellations, Canada, this would be the four or five instead of the largest oil-producing countries in the world by 2020.
In early December 2007, London BP and Husky Energy in Calgary, Alberta announced a 50/50 joint venture to manufacture and refine bitumen from the Athabasca oil sands. BP would its Toledo, Ohio refinery to bring the joint venture, while his would contribute Husky Sunrise oil sands project. Sunrise had planned to produce 60,000 barrels per day (9,500 m3 / d) of bitumen in 2012 and may reach 200 000 bbl / d (30,000 m3 / d) from 2015-2020. BP would change its Toledo refinery to 170,000 bbl / d (27,000 m3 / process d) of bitumen directly to refined products. The joint venture would solve problems for both companies, as was briefly the Husky refinery capacity and BP had no presence in the oil sands. There was a change of strategy for BP, as the company downplayed the historical significance of oil sands.
Mid-December 2007 ConocoPhillips announced its intention to increase its oil sands production by 60,000 barrels per day (9,500 m3 / d), by 1 million barrels per day (160,000 m3 / d) the next 20 years it would be the largest private oil sands producer in the world. ConocoPhillips currently has the largest position in the Canadian oil sands with over 1 million hectares (4,000 km2) leased. Other major oil sands producers are planning to increase their production and Royal Dutch Shell (to 770,000 bbl / d (122,000 m3 / d), Syncrude Canada (to 550,000 bbl / d (87,000 m3 / d), Suncor Energy (to 500,000 bbl / d (79,000 m3 / d) and Canadian Natural Resources (to 500,000 bbl / d (79,000 m3 / d). If all these plans come to fruition, these five companies are producing over 3.3 million bbl / d (500,000 m3 / d) of oil from oil sands until 2028.
Large Athabasca Oil Sands Project (December 2007)
Project Name
Type
Major Partners
National
Membership
2007 Production
(Bbl / day)
Planned production
(Bbl / day)
Suncor
First and foremost mining
Suncor Energy
Canada
239 100
500 000
Syncrude
Mining
Syncrude
Canada (Some U.S.)
307 000
550 000
Albian Sands
Mining
Shell (60%), Chevron (20%), Marathon (20%)
UK / Netherlands, USA
136 000
770 000
MacKay River
SAGD
Petro-Canada
Canada
30 000
190 000
Fort Hills
Mining
Petro-Canada (60%), UTS Energy (20%), Teck (20%)
Canada

140 000
Promote Creek Christina Lake
SAGD
EnCana Energy (50%), ConocoPhillips (50%)
Canada, United States
6000
400 000
Surmont
SAGD
Total SA (50%), ConocoPhillips (50%)
France, United States
193 000
Hangingstone
SAGD
Japan Canada Oil Sands (JACOS)
Japan
8000
30 000
Long Lake
SAGD
Nexen (65%), OPTI Canada (35%)
Canada
240 000
Horizon
Mining and in situ
Canadian Natural Resources Ltd.
Canada
500 000
Jackfish I and II
SAGD
Devon Energy
USA
?
70 000
Northern Lights
Mining
Total SA (60%), Sinopec (40%)
France, China
100 000
Kearl
Mining
Imperial Oil, ExxonMobil
USA
300 000
Sunrise
SAGD
Husky Energy (50%), BP (50%)
Canada, Great Britain
200 000
Tucker
SAGD
Husky Energy
Canada
?
30 000
Oil Sands Project
Mining and SAGD
Total SA (76%), Oxy (15%), Inpex (10%)
France, U.S., Japan
225 000
Ells Flow
SAGD
Chevron (60%), Marathon (20%), Shell (20%)
USA, UK / Netherlands
100 000
Terre de Grace
SAGD
Value Creation Inc
Canada
300 000
Kai Kos Dehseh
SAGD
Statoil
Norway
200 000
Black Gold Mine
Mining?
Korea National Oil Corporation
Korea
30 000
Total
726 100
5.068 million
Development
The main feature of the Athabasca deposit is that it is the only flat enough to be used for open pit mining. About 10% of the Athabasca oil sands are less than 75 meters (246 ft) of overburden covered. The mineable area defined by the Government of Alberta consists of 37 contiguous municipalities (about 3,400 km2 / 1,300 sq km) north of the city of Fort McMurray. The overburden consists of 1 to 3 meters waterproof logged muskeg on top of 0-75 Feet of clay and barren sand, while the underlying oil sands are typically 40 to 60 meters thick and sit on the relatively flat limestone rock. As a result of easy accessibility, the world's first oil sands mine was started by Great Canadian Oil Sands Limited (a predecessor company of Suncor Energy) in 1967. The Syncrude mine (the largest Mine in the world with 191 km2) [edit] followed in 1978, and the Albian Sands mine (operated by Shell Canada) in 2003. All three of these mines are bitumen with newcomers, the useless To convert bitumen into synthetic crude oil related shipping to refineries in Canada and the United States. At the Albian, the refiner at Scotford, 439 km from the south. The bitumen, diluted with a solvent, it is transferred into a 610 millimeter (24 inch) pipeline corridor.
Bitumen Extraction
Main article: Oil Sands # Extraction Process
The original procedure for the extraction of bitumen from the sand was developed by Dr. Charles Clark, in collaboration with the Alberta Research Council in the 1920s Years. Today, all the producers do mine, as Syncrude Canada, Suncor Energy and Albian Sands Energy, etc., use a variation of the Clark Hot Water Extraction (CHWE) to process. In this process the ores are mined by surface mining technology. The mined ore is then crushed crushing. Hot water at 50 80 C, is added to the ore and the formed Sludge is transported by hydraulic transport line to a primary separation vessel (PSV), where bitumen is recovered by flotation as bitumen froth. The recovered bitumen froth is to 60% bitumen, 30% water and 10% solids by weight. The recovered bitumen froth to be cleaned, refuse to be contained in the solids and water to meet the Requirement of downstream refining processes. May depend on the bitumen content in the ore, between 90 and 100% of the bitumen is recovered using modern hot-water extraction Techniques. After oil extraction the spent sand and other materials then in the mine, which is eventually released back.
More recently, in-situ methods such as steam assisted gravity drainage (SAGD) and cyclic steam stimulation (CSS) were developed to bitumen from deep deposits by injecting steam in the sand and heat reduce the bitumen viscosity so that it can be pumped out like conventional crude oil.
The standard extraction requires large amounts of natural gas. Currently the oil sands industry uses about 4% of the Western Canada Sedimentary Basin natural gas production. Until 2015, this 2.5-fold increase can.
According to the National Energy Board, requires it is about 1,200 cubic feet (34 m3) of natural gas to one barrel of bitumen produced in-situ projects and about 700 cubic meters (20 m3) for integrated projects. Since a barrel About 6,000 cubic meters of oil equivalent feet (170 m3) of gas, this means a large gain in energy. That being the case, it is likely that Alberta regulators are the exports of natural gas in the United States to reduce, to provide fuel to the oil sands plants. Exhausted the reserves of gas, oil transfer passengers, however, are likely turn bitumen gasification to produce their own fuel. In the same way, the bitumen can be converted into synthetic crude oil, it can also be converted into synthetic natural gas be.
In-situ extraction on a commercial scale has only just begun. A project nearing completion, the Long Lake Project is designed to provide its own fuel to supply extracted by on-site hydrocracking of the bitumen. Long Lake Phase 1 is to extract 13,000 barrels / day of bitumen in July 2008, ramps to a target of 72,000 in late 2009. and "Modernization" of bitumen to liquid oil in 2007, produces 60 000 bbl / day of usable oil. The hydrocracker is up to the commissioning of complete September 2008.
Impact on the environment
See also: Environmental issues surrounding oil sands exploitation
Mining operations in the Athabasca oil sands. Picture shows the Athabasca River, approximately 600m from the tailings pond. NASA Earth Observatory photo, 2009.
Critics claim that the government and industry measures to minimize environmental and health risks provided by large-scale mining are inadequate, resulting in damage to the natural environment. Objective discussion of the impact on the environment has often clouded polarized Arguments from the industry and stakeholders.
Country
About 20% of the Alberta oil sands recoverable from surface mining, while 80% require in-situ extraction technologies ( mainly because of their depth). Surface mining destroys the boreal forest and muskeg. The Alberta government requires companies to restore the land to "equivalent land capability ". This means that the country's ability to support various land-reclamation after similar to what uses exist, but that the individual Uses need not necessarily be identical. In some special circumstances the government considers agricultural land to be equivalent to forest land. Oil sands companies have mined land as grazing land for wood bison use, rather than reclaimed the restoration to the original boreal forest and muskeg. Syncrude has said it 22% of their disturbed land reclaimed.
Water
A Pembina Institute report stated: "To produce one cubic meter (m3) of synthetic crude oil (SCO) (upgraded bitumen) in a mining operation requires about 24.5 m3 of water (net figures). Approved oil sands mining license is currently 359 million m3 from the Athabasca River, or more than twice the volume of water needed to divert the annual meet local needs of the City of Calgary. "And went on to say:" … the net water requirement to produce one cubic meter of oil in situ (emphasis added) production may be as little as 0.2 m3, depending on how much recycled ". Jeffrey Simpson of the Globe and Mail, paraphrasing the report as saying: "One cubic meter of oil removed from the oil sands, needs two to 4.5 cubic meters of water.
The Athabasca River flows 1231 km from the Athabasca Glacier in west-central Alberta to Lake Athabasca in northeastern Alberta. The average annual flow directly below Fort McMurray is 633 cubic meters per second with the highest daily average of 1,200 cubic meters per second.
Water license allocations totaling approximately 1% of the Athabasca River average annual flow. Actual use in 2006 was about 0.4%. In addition, the Alberta government sets strict limits on how much water oil sands companies can to remove from the Athabasca River. According to the Water Management Framework for the Lower Athabasca River, during periods of low stream flow water consumption from the Athabasca River is limited to 1.3% of the average annual flow. The province of Alberta studied in cooperative agreements between oil sands operators retreat.
Natural gas use and greenhouse gases
The processing of bitumen into synthetic crude oil requires energy and this energy is currently generated by burning natural gas, the carbon dioxide releases. In 2007, used the oil sands around 1 billion cubic feet of natural gas per day, approximately 40% of total consumption in Alberta. Based on gas purchases, natural gas requirements by Canadian Energy Resource Institute as 2.14 GJ (2.04 mcf) per barrel given for cyclic steam stimulation projects, 1.08 GJ (1.03 mcf) per barrel for SAGD projects, 0.55 GJ (0.52 mcf) per barrel of bitumen extraction in the mining industry not including the modernization or 1.54 GJ (1.47 mcf) per barrel for the extraction and the modernization of the mining industry.
The forecast growth in synthetic oil production in Alberta also threatens Canada's international obligations. In ratifying the Kyoto Protocol, Canada agreed to reduce by 2012 their greenhouse gas emissions by 6% compared to 1990. In 2002, Canada had increased total greenhouse gas emissions by 24% compared to 1990. Oil Sands Production contributed 3.4% of Canada's greenhouse gas emissions in 2003.
Ranked as the world's eighth largest emitter of greenhouse gases, Canada is a relatively large emitter in the face its population and do not have Kyoto targets. A major Canadian initiative called the Integrated CO2 Network (ICO2N) has a system for large scale capture, transport and storage of carbon dioxide (CO2) is proposed. ICO2N members represent a group of industry participants, providing a framework for carbon capture and storage development in Canada, first use, to increase oil production. Nuclear power has been as a means to generate the required energy release without the proposed green Greenhouse gases.
Population
Lies the Athabasca oil sands in the northeastern part of the Canadian province of Alberta, near the town of Fort McMurray. The area is sparsely populated, and in the late 1950s, it was primarily a wilderness outpost of a few hundred people, included the most important economic activity Fur trapping and salt mining. Of a population of 37 222 in 1996 grew the boomtown Fort McMurray and the surrounding region (the so-called Regional Municipality of Wood Buffalo) around 79 810 people since 2006, including a "shadow population" of 10 442 live in labor camps, struggling to leave the community to services and Housing for migrant workers, many of them offer from Eastern Canada, especially Newfoundland. Fort McMurray becoming a city built in 1995 and today is an urban service area in Wood Buffalo.
Estimated oil reserves
The Government of Alberta Energy and Utilities Board (EUB) estimated in 2007 that about 173 billion barrels (27.510 ^ 9 m3) of crude bitumen economically recoverable from the three Alberta oil sands areas to benchmark WTI market-based prices of $ 62 per barrel in 2006, rising to a projected $ 69 per barrel in 2016, with the current technology. This represents about 10% of the estimated 1,700 billion barrels (27 010 ^ 9 m3) of bitumen in place. In fact, WTI prices topped $ 133 May 2008. Alberta estimated that the Athabasca deposits alone contain 35 billion barrels (5.610 ^ 9 m3) of surface mineable bitumen and 98 billion barrels (15.610 ^ 9 m3) of bitumen recoverable by in situ methods. These estimates of Canada's reserves were doubted when they first released have been, are now widely accepted by the international oil industry. This volume places Canadian proven reserves second in the world behind those of Saudi Arabia.
Syncrude Mildred Lake mine and plant
The method of calculating economically recoverable reserves, that these estimates were produced chosen because conventional methods of accounting accruals were always meaningless numbers. They made it appear that Alberta was the oil from a time when a rapid increase oil sands production were more than offset declines in conventional oil and in fact most of Alberta's oil production is now unconventional oil. Conventional Estimates of oil reserves are really calculations of the geological risk of drilling for oil, but in the oil sands there is very little geological risk because they are on the Surface disintegration and are easy to find. With the rise in oil prices since 2003, the economic risks of low oil price was reduced.
The Alberta estimates only assume a recovery of approximately 20% of the bitumen-in-place report, while oil companies with the Steam Assisted Gravity Drainage (SAGD) process for the extraction of bitumen, that them back over 60% with little effort.
Were only 3% of the original reserves established Rohbitumen since commercial production began in 1967. At the rate of production projected for 2015, some 3 million barrels per day (48 010 ^ 3 m3 / d), the Athabasca oil sands reserves would last over 170 years. However, the production levels require an influx of workers into an area that was largely uninhabited until recently. By 2007 this need in northern Alberta, drove unemployment in Alberta and British Columbia next to the lowest in history. As far as the Atlantic provinces, where workers leave to work were in Alberta, the unemployment rate fell looking at the lowest level in more than 100 years.
Venezuela's Orinoco Oil Sands site may contain more than Athabasca oil sands. However, while the Orinoco deposits are less viscous and more easily with conventional techniques (the Venezuelan government prefers to call them "extra-heavy oil"), they are too deep to access by surface mining.
Economy
Despite the large reserves, the cost of extracting oil from bituminous sands is historically derived from the Production of oil sands unprofitablehe cost of selling the extracted crude would not cover the direct costs of recovery; work on the sand and fuel to extract me the raw.
Oil prices 1996-2008 (not adjusted for inflation)
In mid-2006, the National Energy Board of Canada estimates the cost of a new mining operation in the Athabasca oil sands to C $ 9 to C $ 12 per barrel, while the costs would be for an in-situ SAGD operation (with dual horizontal wells) to C $ 10 C $ 14 per barrel. In comparison, the operating costs for conventional oil wells, which may less than a dollar per barrel range in Iraq and Saudi Arabia at about six in the United States and Canada's conventional oil reserves.
The capital cost of the equipment needed to mine the sand and haul it to processing is an important consideration in the production. The NEB estimates that the cost of capital to increase the overall cost of production to C $ 18 to C $ 20 per barrel for a new mining operation and C $ 18 to C $ 22 per barrel for a SAGD operation. This does not include the cost of refurbishing the Rohbitumen into synthetic crude oil, which makes the final cost C $ 36 to C $ 40 per barrel for a new mining operation.
Therefore, although the high crude oil prices, the cost of a very attractive, sudden price sheets Producers are not able to restore its capital costslthough the company well financed and can tolerate over a long period of low prices as the capital already was issued, and they can usually cover incremental operating costs.
However, the development of commercial production, facilitated by the fact that exploration costs are very low. Such costs are an important factor when assessing the economics of drilling in a traditional oil field. The location of oil deposits in the oil sands are well known, and an estimate of recovery costs can easily be made into a rule. There is no other region in the world with energy deposits of comparable Magnitude, where it is less likely that the plants would benefit from a hostile government would be confiscated, or threatened by war or revolution.
As a result of rising oil prices since 2003, the economics of oil sands have improved dramatically. With a world market price of 50 dollars per barrel, the estimated NEB an integrated mining operation would be a return rate of 16 to 23%, while a SAGD operation would return 16 to 27%. Prices have risen since 2006, more 2008 as U.S. $ 145 Mitte. As a result, investment in oil sands announced for the period 2006 to 2015 is expected to be C $ 100 billion, which is twice the amount to exceed expected until 2004. But due to an acute shortage of manpower that has developed in Alberta, it is not likely that all these projects completed can be.
Currently the area around Fort McMurray has seen the most from the increased activity in the oil sands. Although jobs are plentiful, housing is the scarce and expensive. People often come looking for work in the area without arranging accommodation, driving the price of temporary accommodation. The area is isolated and only a two-lane Link road with the rest of the province, and there is pressure on the government of Alberta to improve road links as well as hospitals and other infrastructure.
Despite the best efforts of companies, so much of the work as possible to move from the Fort McMurray region and even from Alberta, the shortage of skilled labor about the rest of the province to spread .. Even without the oil sands, the Alberta economy would be very strong, but the development of oil sands in the strongest period of economic consequence Growth ever recorded by a Canadian province.
Geopolitical significance
The Athabasca Oil Sands are now featured prominently in international trade talks with Energy rivals China and the United States, negotiations with Canada for a larger share of the oil sands' rapid exit. Performance in the oil sands is expected to quadruple 2005-2015, reaching four million barrels / day, increasing their political and economic importance. Currently, most of the oil sands production is in the United States exports.
An agreement between PetroChina and Enbridge has been signed to a 400,000 barrel per day (64,000 m3 / d) pipeline from Edmonton, Alberta, the west coast port of Kitimat to build, British Columbia, into synthetic crude oil from oil sands exports to China and elsewhere in the Pacific, and a 150-million-barrel-per-day (24 million m3 / d) pipeline the other way to import condensate to dilute the bitumen so it will flow. Sinopec, China's largest refining and chemical company, and China National Petroleum Corporation have bought or plan shares in major oil sands development to buy.
On 20 August 2009, the U.S. State Department a presidential permit for an Alberta Clipper pipeline that will run from Hardisty, Alberta to Superior, Wisconsin. The pipeline will be capable of up to 450,000 barrels Crude oil per day from the Athabasca Oil Sands U.S. refineries.
Indigenous peoples of the area
Indigenous peoples of the region include the Fort McKay First Nation. The oil sands within the boundaries of Treaty 8 are located, signed in 1899. The Fort McKay First Nation has established several companies around the oil sands industry and the service development a mine on their territory. Opposition still in the First Nation will focus on environmental issues.
Oil sands companies
Planned oil production from various mining operations Companies. Data from the table below.
There are currently three large oil sands mining in the area of ​​Syncrude Canada Limited, Suncor Energy and Albian Sands Shell Canada, Chevron and Marathon Oil Corp. owned run
Substantial manufacturer or planned developments in the Athabasca Oil Sands include the following projects:
Suncor Energy Steepbank and Millennium Mines are currently producing 263 000 barrels per day (41 800 m3 / d) and its Firebag in-situ project produces 35 000 bbl / d (5,600 m3 / d). It intends to spend 3.2 billion around its mining to 400,000 bbl / d (64,000 m3 / d) to expand and its in-situ production to 140,000 bbl / d (22,000 m3 / d) up to 2008.
Syncrude Mildred Lake and Aurora mines can currently produce 360 ​​000 bbl / d (57,000 m3 / d).
Shell Canada currently operates its Muskeg River mine produced 155 000 bbl / d (24 600 m3 / d) and the Scotford Upgrader in Fort Saskatchewan, Alberta. Shell intends to open its new Jackpine mine and expand total production to 500,000 bbl / d (79,000 m3 / d) over the next Years.
Nexen is produced in-situ Long Lake SAGD project is now 70 000 bbl / d (11,000 m3 / d). Plans, made it to 240,000 bbl / d (38,000 m3 / d) to expand were. Expansion plans were postponed in early 2009.
CNRL Horizon Mine is the $ 8000000000 planned, to 110,000 bbl / d (17,000 m3 / d) at start producing mid-2009 and grow to 300,000 bbl / d (48,000 m3 / d) until the year 2010.
Total SA's subsidiary Deer Creek Energy is operating a SAGD project on its Joslyn lease, producing 10 000 bbl / d (1,600 m3 / d). She wants to build the mine to the year 2010 its production by 100,000 bbl / d to expand (16,000 m3 / d).
Imperial Oil is 5 to 8 billion Kearl Oil Sands Project is projected to begin construction in 2008 and produce 100,000 bbl / d (16,000 m3 / d) until the year 2010. Imperial also operates a 160,000 bbl / d (25,000 m3 / d) in-situ operation in the Cold Lake oil sands region.
Synenco Energy and Sino-Canada Petroleum Corp., a subsidiary of Sinopec, China's largest oil refinery had agreed to 3.5 billion Northern Lights mine, projected at 100,000 bbl / d create (16,000 m3 / d) to produce up to 2009. This project has now been indefinitely Time-shifted (as of 2007).
North American Oil Sands Corporation (NAOSC), a subsidiary of Statoil, it is expected that in the Kai Kos Dehseh project around 100,000 bbl / d production (16,000 m3 / d) until 2015. It is expected to increase production capacity to around 100,000 barrels per day (16,000 m3 / d) by the year 2015.
Mining Projects
Operator
Project
Phase
Capacity
Start-up
Regulatory Status
Royal Dutch Shell
Jackpine
1A
100,000 bbl / d (16,000 m3 / d)
2010
Under construction

1B
100,000 bbl / d (16,000 m3 / d)
2012
Approved

2
100,000 bbl / d (16,000 m3 / d)
2014
Applied for
Muskeg River
Existing
155 000 bbl / d (24 600 m3 / d)
2002
Operating

Expansion
115 000 bbl / d (18,300 m3 / d)
2010
Approved
Pierre River
1
100,000 bbl / d (16,000 m3 / d)
2018
Applied for

2
100,000 bbl / d (16,000 m3 / d)
2021
Applied for
Canadian Natural Resources
Horizon
1
135 000 bbl / d (21 500 m3 / d)
2009
Operating

2 and 3
135 000 bbl / d (21 500 m3 / d)
2011
Approved

4
145 000 bbl / d (23,100 m3 / d)
2015
Announced

5
162 000 bbl / d (25 800 m3 / d)
2017
Announced
Imperial Oil
Kearl
1
100,000 bbl / d (16,000 m3 / d)
2010
Approved

2
100,000 bbl / d (16,000 m3 / d)
2012
Approved

3
100,000 bbl / d (16,000 m3 / d)
2018
Approved
Petro Canada
Fort Hills
1
165 000 bbl / d (26 200 m3 / d)
2011
Approved

Bottlenecks
25 000 bbl / d (4,000 m3 / d)
TBD
Approved
Suncor Energy
Millennium

294 000 bbl / d (46,700 m3 / d)
1967
Operating

Bottlenecks
23 000 bbl / d (3,700 m3 / d)
2008
Under construction
Steepbank
Bottlenecks
4000 bbl / d (640 m3 / d)
2007
Under construction

Extension

2010
Approved
Voyageur South
1
120 000 bbl / d (19,000 m3 / d)
2012
Applied for
Syncrude
Mildred Lake & Aurora
1 and 2
290 700 bbl / d (46 220 m3 / d)
1978
Operating

3 Expansion
116 300 bbl / d (18 490 m3 / d)
2006
Operating

3 bottlenecks
46 500 bbl / d (7390 m3 / d)
2011
Announced

4 Expansion
139 500 bbl / d (22 180 m3 / d)
2015
Announced
Synenco Energy
Northern lights
1
57 250 bbl / d (9102 m3 / d)
2010
Applied for
Total SA
Joslyn
1
50 000 bbl / d (7,900 m3 / d)
2013
Applied for

2
50 000 bbl / d (7,900 m3 / d)
2016
Applied for

3
50 000 bbl / d (7,900 m3 / d)
2019
Announced

4
50 000 bbl / d (7,900 m3 / d)
2022
Announced
UTS / Teck Cominco
Equinox
Lease 14
50 000 bbl / d (7,900 m3 / d)
2014
Disclosure
Border
1
100,000 bbl / d (16,000 m3 / d)
2014
Disclosure
Royal Dutch Shell – misleading advertising
In August In 2008, the British Advertising Standards Authority (ASA) ruled that Royal Dutch Shell was the public by claiming that its oil sands project was conducted in Alberta, a "sustainable energy source" is misleading. Although widespread, "sustainable" was "vague" and "ambiguous" Term as, in the light of DEFRA's advice that companies should avoid vague ecological conditions simply a good impression. They concluded, was the need for sustainability misleading "[b] ecause we had no data, how Shell was effectively managing carbon dioxide emissions from oil sands projects in order to limit climate change showed seen. "
See also
Canadian Centre for Energy Information
History of the petroleum industry in Canada (oil sands and heavy oil)
Mackenzie Valley Pipeline
Utah Oil Sands Joint Venture
References
^ IHS CERA (May 18, 2009). "Move from the Oil Sands' Fringe center" energy security ". Rigzone. Http://www.rigzone.com/news/article.asp?a_id=76219. Retrieved 05/19/2009.
^ From Andy Burrowes, Rick Marsh, Nehru Ramdin, Curtis Evans (2007) (PDF). Alberta Energy Reserves 2006 and Supply / Demand Outlook 2007-2016. ST98. Alberta Energy and Utilities Board. http://www.ercb.ca/docs/products/STs/st98_current.pdf. Retrieved 2008-04-12.
^ "Alberta Oil Sands 2006" (PDF). Government of Alberta. 2007th http://www.energy.gov.ab.ca/OilSands/pdfs/osgenbrf.pdf. Retrieved 17/02/2008.
^ Mackenzie, Sir Alexander (1970). "The Journals and Letters of Alexander Mackenzie" Edited by W. Kaye Lamb Cambridge: … Hakluyt Society, p. 129, ISBN 0521010349
^ From Hein, Francis J (2000). "Historical Overview of the Fort McMurray Area and Oil Sands industry in northeastern Alberta" (PDF). Earth Sciences Report 2000-05. Alberta Geological Survey. http://www.ags.gov.ab.ca/publications/ESR/PDF/ESR_2000_05.pdf. Retrieved 17/02/2008.
^ "Oil Sands History." Unlocking the potential of Oil Sands. Syncrude. 2006th http://www.syncrude.ca/users/folder.asp?FolderID=5657. Retrieved 17/02/2008.
^ "Oil Sands". Alberta Energy. Alberta Government. 2008th http://www.energy.gov.ab.ca/OurBusiness/oilsands.asp. Retrieved 30/01/2008.
^ "Western Canadian oil sands and conventional production, December 2008 Interim Update". Canadian Association of Petroleum Producers. 12/11/2008. http://www.capp.ca/. Retrieved 03/01/2009.
^ Franklin, Sonja; Gismatullin, Edward (2007-12-05). "BP, Husky Energy agree, oil sands partnership form ". Bloomberg. http://www.bloomberg.com/apps/news?pid=20601082&sid=a18oTMnaz4zQ&refer=canada. Retrieved 12/12/2007.
^ Dutta, Ashok (12/12/2007). "ConocoPhillips is aiming high." Calgary Herald. Retrieved 12/12/2007.
^ Alberta Employment, Immigration and Industry (December 2007). "Alberta Oil Sands Industry Update "(PDF). Http://www.alberta-canada.com/energyCommodities/files/pdf/oilSandsUpdate_December_2007.pdf Government of Alberta.. Retrieved 04/01/2008.
^ Albian Sands announces the operating agreement, Press Release, 18 November 2008
^ Fort Hills project site – Petro-Canada website
^ EnCana Oilsands Projects website
^ From ConocoPhillips – Canadian Operations
^ Jaco's Homepage
^ Opti sold 15 percent of the shares of Oilsands joint venture for $ 735 million Nexen Yahoo Finance, 17 December 2008
^ Nexen Long Lake brings additional interest for $ 735 mm – Rigzone, January 27, 2008
^ Horizon project homepage
^ Devon Energy Obtains Approval for Second Jackfish Oil Sands Production Project – Oilvoice.com, 8 September 2008
^ Synenco & Sinopec Enter Deal for Canadian Oil Sands Project Rigzone – 31 May 2005
^ Synenco side of Sino Canada
^ [Http: / www.total-ep-canada.com/press/documents/2008-04-28-Synenco.pdf purchase / agreement for Synenco Energy Inc. - Total strengthens Position in the Canadian Heavy Oil] – Total E & P Canada press release, 28 April 2008
^ Kearl project proposed on the spot – Imperialoil.ca
^ From BP closes Canadian oil sands with Husky Energy – BP press release, 5 December 2007
^ Tucker project site
^ Chevron drilling completed Ells River – Heavyoilinfo.com (by Schlumberger), 30th March 2007
^ Terre de Grace Project Page – Value Creation Inc website
^ Major investments – Statoil is in the oil sands – WoodMackenzie, upstream Insight, May 2007
^ S. Korea buys Canadian oil sands properties – redorbit.com, 24 July 2006
^ "Operational excellence: .. the land that we borrow" http://www.syncrude.ca/users/getdownload.asp?DownloadID=311 Retrieved 27/02/2009.
^ "Alberta Inventors and Inventionsarl Clark." Http: / / www.abheritage.ca / abinvents / inventors / karlclark_biography.htm. Retrieved 03/29/2006.
^ Gu G, Xu Z, Nandakumar K, Masliyah JH. (2002) "Influence of water-soluble and water insoluble natural surface active components on the Stability of water-in-toluene-diluted bitumen emulsion, "Fuel, 81, pages 18,591,869th
^ RJ Mikula, O. Omotoso and WI Friesen (2007) "Interpretation Bitumen recovery of data from batch extraction tests, "Canadian Journal of Chemical Engineering, v 85 n 5, pages 765-772.
^ "Canada Energy Future: Reference Case and Scenarios to 2030 "pages 45-48 ISBN 978-0-662-46855-4
^ "Questions and Answers". Canada's Oil Sandspportunities and challenges to 2015: An update. National Energy Board of Canada. 2007-06-30. Retrieved 23/08/2007.
^ Long Lake Project
^ "Operationsthabasca Oil Sand Lake Song Projectroject Overview." Nexen Inc.. http://www.nexeninc.com/Operations/Athabasca_Oil_Sands/Long_Lake/project_overview.asp. Retrieved 03/29/2006.
^ "Nexen Nods Positive reservoir performance on Long Lake "Nexen, 17 July 2008
^ "Alberta Plan fails Protect Athabasca River." http://www.oilsandswatch.org/media-release.php?id=1182.
^ "Alberta oil sands are absorbing too much water." The Globe and Mail (Dogwood Initiative). 05/07/2006. http://www.dogwoodinitiative.org/newsstories/oilandwaterdonotmix.
^ "'Conspiracy of silence" on tarsands says group. "CTV News. Retrieved 16/02/2008.
^ "Tar not stick." Edmonton Journal. Retrieved 02/16/2008.
^ "Stop time for Ottawa to Alberta Oilsands toes sensitivity." Oil Week. 15/02/2008. http://www.oilweek.com/news.asp?ID=14357. Retrieved 02/16/2008. (Journal)
^ "Environmental Protection and Enhancement." Alberta Environment. http://www3.gov.ab.ca/env/protenf/landrec/definitions.html # Equiv_land_capability.
^ "Syncrude's land reclamation". Syncrude Canada. 2006th http://www.syncrude.ca/users/folder.asp?FolderID=5909. Retrieved 08/07/2009.
^ "Troubled Waters, Troubling Trends." The Pembina Institute. May 2006. Http: / / pubs.pembina.org / reports / TroubledW_Full.pdf. (Advocacy)
^ "Primer". Environment Canada. http://www.ec.gc.ca/water/images/info/pubs/primer/prim08-e.htm.
^ "Athabasca River Water Management Framework". http://www.environment.alberta.ca/1547.html.
^ "Typical River Flows." Environment Canada. http://www.ec.gc.ca/water/images/nature/prop/a2f5e.htm. Retrieved 12/13/2008.
^ "Environmental Aspects of Oil Sands Development Background Information "(PDF). Canadian Association of Petroleum Producers. Http://www.capp.ca/raw.asp?x=1&dt=PDF&dn=105401. Retrieved 12/13/2008.
^ "Athabasca River Water Management Framework". Alberta Environment. http://www3.gov.ab.ca/env/water/Management/Athabasca_RWMF/index.html.
^ "Resilience in a Changing Climate, Water Supply for Canada's Oil Sands". Natural Resources Canada. http://ess.nrcan.gc.ca/ercc-rrcc/theme1/t7_e.php?p=1.
^ McColl, David; Slagorsky, Martin (November 2008). Canadian oil sands supply cost and development projects. Canadian Energy Research Institute. ISBN 1,896,091,830th
^ "Section 2 Crude Bitumen" Alberta Energy Resources Board data and graphics (PowerPoint file)
^ Top 50 countries by greenhouse gas emissions, Reuters
^ "Carbon Capture and Storage" 30 November 2007.
^ Planning and Development (2006). "Communal Census 2006" (PDF). Regional Municipality of Wood Buffalo. http://www.woodbuffalo.ab.ca/business/demographics/pdf/2006_census.pdf. Retrieved 02/06/2008.
^ "Urban Service Areas". Unincorporated places. Alberta Population. 2008th http://www.altapop.ca/unincorp.htm. Retrieved 02/06/2008.
^ Department of Energy, Alberta (June 2006). "Oil Sands Fact Sheets". http://www.energy.gov.ab.ca/oilsands/954.asp. Retrieved 11/04/2007.
^ Canada, Statistics (April 5, 2007). "Latest release from the Labour Force Survey". http://www.statcan.ca/english/Subjects/Labour/LFS/lfs-en.htm. Retrieved 11/04/2007.
^ From NEB (June 2006) (PDF). Canada's Oil Sands Opportunities and Challenges for 2015: An update. National Energy Board of Canada. Retrieved 30/10/2006.
^ Nikiforuk, Andrew (04/06/2006). "The downside of boom: Alberta labor shortage." Canadian Business magazine. http://www.canadianbusiness.com/managing/employees/article.jsp?content=20060522_77876_77876. Retrieved 30/10/2006.
^ Statistics Canada (2006-09-14). Study: The Alberta economic juggernaut. Statistics Canada. http://www.statcan.ca/Daily/English/060914/d060914c.htm. Retrieved 30/10/2006.
^ Enbridge and PetroChina Sign Gateway Pipeline Cooperation Agreement | Business Wire | Find Articles at BNet
^ Http: / / www.state.gov/r/pa/prs/ps/2009/aug/128164.htm
^ Http://albertaclipper.state.gov/clientsite/clipper.nsf?Open
^ Financial Post Articleboriginal implication in the project
^ Oil Sands Discovery Oilsands Projects
^ Synenco Proceedings
^ Wojciech Moskwa (2007-04-27). "Statoil to North American Oil Sands for 2 billion buy". Financial Post. http://www.financialpost.com/story.html?id=fc2c62db-792e-44e9-9819-3480d41ddcbf&k=99838&p=1. Retrieved 09/12/2007.
^ Shell by ASA for 'greenwash' ad rapped – guardian.co.uk, 13 August 2008
External Links
Alberta Oil Sands: Key Issues and impact
OnEarth Magazine Canadian Highway to Hell
Mud, Sweat and Tearsuardian Zeitung, 2007
Hugh McCullum, Fuelling Fortress America: A Report on the Athabasca and U.S. demands for Canada Energy (The Parkland Institute) download report summary UMMARY
Canadian Oil Sands Historyyncrude
Oil Sands Discovery Centreort McMurray Tourism
The Trillion-Barrel Tar Pitrticle from December 2004, Wired.
Oil Sands Reviewister publication Oilweek Magazine
Alberta Oil Sandslberta Department of Energy
Alberta Reserves 2005 and Supply / Demand Outlook 2006-Energy and Utilities Board 2015lberta 15/06/2006
Canada's Oil Sandspportunities and challenges for 2015: A Updateune 2006ational Energy Board of Canada
Oilsands overview-Canadian Centre for Energy Information
Alberta plan fails Protect Athabasca River
Mega Projects
"Energy Statistics Handbook" (February 2008) Statistics Canada ISSN 1496-4600
Alastair Sweeny, History of the oilsands by 1914
(French) Du sable dans l'engrenage tv document by Guy Gendron and Jean-Luc Paquette description of the Athabasca Oil Sands questions.
Further Reading
Kunzig, Robert (March 2009). "The Canadian oil boom: Scraping Bottom." National Geographic 215 (3): 3859th http://ngm.nationalgeographic.com/2009/03/canadian-oil-sands/kunzig-text. Accessed 29th May 2009.
vde
Western Canadian sedimentary basin
Hydrocarbon history
Frontier Oil sands and heavy oil exploration and development of Natural gas liquids, natural gas
Depositional environments regions
Southern Alberta Central Alberta North Western Plains South Central Alberta Canadian Rockies foothills north-east Plains north-central foothills of Liard River, Fort Nelson Fort St. John Northern Rocky Mountains, western Saskatchewan Manitoba
Oil and gas fields
Athabasca Larger Sierra Hamburg Leduc Pembina Wabasca
Categories: Athabasca Oil Sands | Oil fields of Alberta | Bituminous sands Canada | History of the petroleum industry | Petroleum production Canada | Economic history of Canada | Oil companies in Canada | History of Alberta | Industry Canada | planned or proposed energy project hidden categories: All articles with Unsourced statements | Articles with Unsourced statements from March 2009

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