19-12-02 Canada is a net exporter of oil, natural gas, coal, uranium, and hydropower. It is one of the most important sources of US energy imports.
Information contained in this report is the best available as of December 2002 and can change.

Canada's real gross domestic product (GDP) is expected to rise by approximately 3.4 % for 2002 to $ 724.6 bn, indicating the country's recovery from 2001's economic malaise, when GDP grew by only 1.5 %. Canada's economic slowdown in 2001, and subsequent recovery in 2002, were both largely impacted by the fluctuations of the US economy as both countries represent the other's largest trading partner. In 2002 approximately 85 % of Canadian exports went to the United States.
Canada's main exports are industrial goods, energy products, and forest products. US International Trade Administration statistics indicate that Canadian exports to the United States began showing monthly year-on-year increases in July 2002, after suffering declines throughout most of 2001 and the first half of 2002.

Between July and September 2002, Canadian exports to the United States totalled approximately $ 52 bn, a 3 % increase over last year's level for the same period. Canadian petroleum exports to the United States followed this general pattern for US-Canadian trade, beginning monthly year-on-year increases in April 2002.
In June 2002, Canadian Prime Minister Jean Chretien fired his finance minister of 9 years, Paul Martin, and replaced him with then Deputy Prime Minister, John Manley. Manley, who had previously served as the country's industry minister has pledged to continue the economic policies laid out under Martin. In August 2002, Canadian Prime Minster Jean Chretien announced that he plans to retire in February 2004. Prime Minister Chretien has served as leader of Canada's Liberal Party since 1990, and as the country's Prime Minister since 1993.

Energy overview
Canada was the fifth-largest energy producer in the world in 2000, behind the United States, Russia, China, and Saudi Arabia. Over the past two decades, Canada has become a significant net energy exporter. In 2000, about 30 % of Canadian energy production was exported, with the United States by far its main customer.
From January through August 2002, the United States imported more oil (including crude oil and petroleum products) from Canada than from any other country. The United States also imported about 2.2 tcf of Canadian natural gas in the first seven months of 2002, with 93 % of total US gas imports coming from Canada.
In 2000, about 36 % of Canada's primary energy production was natural gas, followed by oil (23 %), hydropower (20 %), coal (11 %), and nuclear power (4 %). Over two-thirds of Canada's energy is produced in the province of Alberta.
Besides being a major producer, Canada also is a significant energy consumer and a member of the International Energy Agency (IEA). Canada was the world's fifth-largest energy consumer in 2000, roughly on par with India in terms of total energy consumption. Canada has the highest energy intensity of any OECD country.

Oil
Canada has proven conventional oil reserves of 4.9 bn barrels, as of January 2002, a 152-mm-barrel increase over January 2001 reserves. Oil production averaged 2.9 mm bpd during 2002, with estimated consumption of 2.0 mm bpd. The province of Alberta, located in western Canada, is by far the country's leading oil producing region.
While Alberta's light oil reserves are declining (the province now contains an estimated 45 % of the country's total light oil reserves), the province also contains huge oil sands deposits. Meanwhile, projects and potential projects in other provinces are shifting the oil industry's focus to include the eastern and northern parts of the country.

Canada is a major source of US oil imports. From January through August 2002, the United States imported 1.89 mm bpd of oil from Canada (1.39 mm bpd of which was crude oil). This makes Canada the top petroleum supplier to the United States and the third-largest supplier of crude oil imports (behind Saudi Arabia and Mexico, and ahead of Venezuela).
Canada has been the top supplier to the United States of refined petroleum products, including gasoline, jet fuel, distillate, etc., over the past few years. The preponderance of US-bound Canadian oil exports go to the Midwest (PADD II). In 2001, Canada exported 1.08 mm bpd to PADD II, which accounted for approximately 64 % of the region's total oil imports.

Canadian oil exports also dominate in the Rocky Mountain region, (PADD IV) averaging 216,000 bpd in 2001, which represented 100 % of the region's total oil imports. Canada also exports its oil to the US East Coast (PADD I) -- 406,000 bpd in 2001--as well as, to a lesser extent, to the Gulf Coast region (PADD III) and the West Coast (PADD V).
Canada's oil sector has seen significant mergers and acquisitions in recent years, with US firms purchasing over $ 35 bn in Canadian oil and gas assets during 2001. In July 2001, Houston-based Conoco purchased Gulf Canada for $ 8.9 bn, marking the largest oil and gas deal in Canadian history.

In October 2001, Devon Energy (US) acquired Canada's Anderson Exploration for $ 7.1 bn. In December, 2001, Burlington Resources (US) purchased Canada's Canadian Hunter Resources for $ 3.4 bn. In addition, Canadian firms also have been busy reorganizing the country's oil patch.
In April 2002, two of Canada's largest companies, Alberta Energy and PanCanadian, merged to create EnCana, the world's largest independent oil and natural gas producer (by market value). Other companies operating in Canada include Exxon's Imperial Oil, Shell's Shell Canada, Petro-Canada, and Suncor.

Exploration and production
Western Canada, and more specifically Alberta, remains the premier energy producing region in Canada. The Western Canadian Sedimentary Basin, underlying Alberta, Saskatchewan, and part of the Northwest Territories, has been the main source of Canadian oil production for the past 50years. An estimated 60 % of conventional oil production in 2000 came from Alberta.
However, conventional oil production has been declining in the West as it has been rising in the East in the last few years. Exploration and production activity on Canada's east coast is focused on the Jeanne d'Arc Basin, offshore Newfoundland. The climate demands technologically advanced offshore oil platforms, able to withstand extremely cold temperatures and high winds, which add to production costs.

The first project in the area, the Hibernia field, came onstream in 1997 and produces around 150,000 bpd of light (high API gravity), sweet (low sulphur) crude. Hibernia's development was subject to repeated delays, and grants totalling about $ 625 mm were provided by the federal government to keep the project moving ahead. ExxonMobil is the operator, with joint venture partners Chevron Canada Resources, PetroCanada, Canada Hibernia Holding Corporation, Murphy Oil, and Norsk Hydro.
The second project in the Jeanne d'Arc Basin, Terra Nova, began production in January 2002 after several delays. The Terra Nova field is about 30 miles away from the Hibernia field and has a production capacity of about 115,000 bpd over six years. Crude oil extracted from Terra Nova's reservoir on the ocean floor is routed upward to the Terra Nova floating production storage and offloading vessel (FPSO), a storage vessel which processes the crude oil on deck.
The petroleum is then transferred to shuttle tankers which take the oil to market. Terra Nova is owned by PetroCanada (operator), ExxonMobil, Husky Oil Operations, Norsk Hydro, Murphy Oil Company, Mosbacher Operating, and Chevron Canada Resources.

There are two more Jeanne d'Arc fields: White Rose and Hebron. The White Rose field is expected to be the third Grand Banks development, beginning production in 2004, although concerns remain that development will be prohibitively expensive. The field could reach a projected 90,000 bpd at peak production. In February 2002, Chevron Canada Resources decided to defer development at the Hebron field for financial reasons. Hebron contains heavier oil than Hibernia and Terra Nova.
On the west coast, a provincial British Columbia agency plans to review a 30-year-old ban on exploration in the Pacific Ocean. The area near Queen Charlotte Island is thought to hold as much as 10 bn barrels of oil as well as significant reserves of natural gas. This has the potential to make the area a larger oil and gas producer than the Jeanne d'Arc Basin.

Synthetic crude oil
Much of the exploration in Alberta in coming years likely will be for heavy crude and oil sands, as conventional oil reserves are being depleted. Unlike conventional oil, oil sands contain a mixture of bitumen, sand, water and clay. Bitumen, which is a thick and tar-like hydrocarbon, surrounds the sand and water.
To develop oil sands, bitumen is separated from the sand, water and clay. Once separated, bitumen can be upgraded into a high-quality oil called "synthetic crude." One of the largest synthetic crude producers, Syncrude (a joint venture of Alberta Energy, Canadian Oil Sands Investments, Conoco, Imperial, Mocal Energy, Murphy Oil, Nexen, and Petro-Canada), reported an average production cost of about $ 11.50 per barrel in 2001.

Canada holds between 1.7 and 2.5 tons barrels of oil sands. The Athabasca Oil Sands deposit, in northern Alberta, is one of the two largest oil sands deposits in the world (the other is in the Orinoco Belt, Venezuela). There are also oil sands deposits on Melville Island, in the Canadian Arctic, and there are three smaller deposits in northern Alberta.
Current output of synthetic crude and bitumen is estimated at 600,000 bpd. A new oil sands project, the Muskeg River Mine, located on the Athabasca oil sands and operated by Shell Canada, Western Oil Sands and Chevron Canada, is scheduled to begin production in early 2003. The Muskeg River mine will produce an additional 155,000 bpd. Construction also is nearing completion at Petro-Canada's MacKay River oil sands project.
Petro-Canada expects production of 30,000 bpd in 2003. According to the Canadian government, synthetic oil and bitumen production is expected to reach 1.2 mm bpd by 2010.

Pipelines
Although most Canadian oil is produced in western Canada (mainly Alberta), oil is consumed primarily in central and eastern Canada. As a result, Canada exports mostly crude oil from Alberta and imports crude oil and petroleum products on the east coast, explaining why Canada exports approximately 1.89 mm bpd (gross) to the United States, but net exports are slightly lower (1.78 mm bpd).
An extensive pipeline system transports western oil to eastern Canadian and US markets. There are two major pipeline networks. The first is Enbridge Pipelines Inc. (formerly Interprovincial Pipe Line-IPL), an 8,700-mile network of piping and terminals, delivering oil from Edmonton, Alberta, east to Montreal, Quebec and eastern Canada as well as the US Great Lakes region.

Enbridge is one of the largest crude oil and petroleum liquids pipeline systems in the Western Hemisphere, and the company is currently expanding its US export capacity through its three-phase Terrace Expansion program.
The first two phases of the program, which links Kerrobert, Saskatchewan to Clearbrook, Minnesota, were completed in January 2002, adding approximately 210,000 bpd capacity to the Enbridge network. Construction of phase three of the Terrace Expansion began in 2002 and will extend the line further into Minnesota, adding 140,000 bpd of capacity.
Completion of phase three is expected by mid-2003. The other major pipeline system is the Trans Mountain Pipe Line (TMPL) system, which delivers oil mainly from Alberta west to refineries and terminals in the Vancouver, British Columbia area, as well as to the Puget Sound area of Washington state.

Development of Alberta's massive oil sands has necessitated new pipelines to transport diluted bitumen from the mine to downstream processors andeventually to market terminals. In the near term, Canadian pipeline companies have focused on taking the Athabasca oil sands southward, to processing facilities in the Edmonton area. The first of these pipelines, the 340-mile Athabasca pipeline (Enbridge), was completed in April of 1999 and connects Suncor's oil sands operations to the Enbridge network.
Construction of another similar pipeline, the Corridor Pipeline (TransMountain) connects the nearly completed Muskeg River Mine (Shell Canada, Chevron Canada, Western Oil Sands) to Shell's Scotford Refinery, located in the Edmonton area, near market terminals. The company expects oil to begin flowing through the Corridor Pipeline in early 2003.

In January 2002, BC Gas announced that it intends to build a new pipeline in conjunction with TransMountain, called the Bison Pipeline, to transport diluted bitumen from mines and refineries near Fort McMurray to pipelines and processing plants in the Edmonton area. The Bison Pipeline would cover about 320 miles and cost about $ 625 mm. BC Gas predicts that if regulatory approval is granted in early 2003, the pipeline could come onstream by 2005.

Natural gas
Canada holds about 59.7 tcf of proven natural gas reserves. Canada produced about 6.5 tcf of natural gas in 2000, making it the world's third largest natural gas producer (after the United States and Russia) and second largest natural gas exporter (after Russia). Canada's natural gas exports go almost exclusively to the United States.
Canadian natural gas consumption is projected to grow significantly in coming decades, largely for use in electricity generation. As natural gas production and infrastructure grow, there is a potential for emergence of a unified North American natural gas market.

Exploration and production
Like the oil industry, Canada's natural gas industry is based primarily in the province of Alberta, which in recent years has accounted for nearly 80 % of the country's natural gas output. Some analysts, however, forecast little growth potential for natural gas in Alberta, causing many industry players to shift their focus to newer projects in British Columbia, Atlantic Canada and the Arctic.
Canada's most significant natural gas discovery in recent years is the Ladyfern natural gas field, discovered in north-eastern British Columbia through a series of exploration projects led by Murphy Oil, Apache Canada, Alberta Energy (now EnCana) and Canadian Natural Resources during 2000 and 2001.

Ladyfern is situated in the northwest corner of Canada's prolific West Canada Sedimentary Basin and could contain up to 1 tcf of natural gas, making it Canada's largest natural gas find in 15 years. Ladyfern currently is producing at a rate of about 550 mm cfpd, with an expected life span of about five to six years.
The field's major owners have worked out production sharing agreements to manage the field's output into the future. Almost all of Ladyfern's natural gas output is routed to TransCanada's Alberta pipeline network. Off the eastern shores of Nova Scotia, Sable Island Offshore Energy, a consortium led by Mobil Canada and including Shell Canada, ExxonMobil, Imperial Oil, Nova Scotia Resources and Mosbacher Operating, began production in January 2000.

Currently, about 550 mm cfpd of natural gas is pumped from three reservoirs at Sable Island's Thebaud platform. The gas is then routed through an underwater pipeline to the consortium's onshore processing facilities in Goldboro, Nova Scotia, and distributed to the Canadian provinces of Nova Scotia and New Brunswick and to the US Northeast.
By some estimates, New England consumes up to 70 % of Sable Island's production. The consortium plans to develop three more fields by 2007, pending governmental approval. Shell had originally estimated Sable reserves to hold 1.1 tcf, but in January 2002 that estimate was revised downwards to 0.8 tcf.

Another natural gas project located off the Scotian shelf, Deep Panuke, is currently being developed by EnCana. The Deep Panuke field holds an estimated 0.9 tcf of natural gas, and is expected to produce 400 mm cfpd by 2005. Similar to the Sable Island project, natural gas from Deep Panuke will be routed to onshore facilities in Goldboro, and then connected to mainland distribution lines.
The Arctic Northwest Territories and the Yukon are thought to hold great potential for new gas discoveries. While the territories are unlikely to exceed Alberta's production, as Alberta becomes increasingly mature the territories represent a major potential new source of natural gas. Three proven, but undeveloped, natural gas fields in Canada's Mackenzie Delta, Imperial's Taglu field, (estimated 3 tcf), Conoco's Parsons Lake (estimated 1.8 tcf) and Shell's Niglintgak (estimated 1 tcf), could support shipments of up to 1 bn cfpd once production begins, and have spurred a race to develop pipeline capacity to take Arctic gas southward (see pipelines).

Pipelines
There has been considerable progress in recent years on natural gas interconnections between Canada and the United States. The $ 2.5 bn Alliance Pipeline, at 1,875 miles, is the longest pipeline ever built in North America. Alliance is designed to carry about 1.3 bn cfpd of natural gas from western Canada (Fort St John, British Columbia) to the Chicago area. The pipeline entered into commercial service on December 1, 2000. The US-based utility Pacific Gas & Electric, imports natural gas from British Columbia via the Alliance pipeline.
The Maritimes and Northeast Pipeline (M&NE) came onstream in January 2000. M&NE is designed to deliver natural gas from Canada's Sable Island area to New England. The pipeline currently is in the midst of two expansion projects. Construction is underway on Phase III expansion, which will extend the pipeline further into Massachusetts, connecting it with the US Algonquin pipeline system in 2003. Phase IV expansion began in January 2002, when M&NE submitted an application to the Federal Energy Regulatory Commission (FERC) for consideration of the company's plan.

Phase IV expansion entails boosting the pipeline's current capacity to allow for natural gas from EnCana's Deep Panuke field to be exported to the United States beginning in 2005. The Phase IV expansion plan calls for all of the output from Atlantic Canada's burgeoning offshore natural gas industry to be exported.
The commitment of Atlantic Canada's natural gas resources to US markets has been contentious. In February 2002, Enbridge shelved plans to build a pipeline connection between Sable Island and Quebec following an announcement that Sable Island's natural gas reserves were to be directed to the US east coast.
In March 2002, the province of New Brunswick petitioned Canada's National Energy Board to alter existing export rules to give Canadians first access to Sable Island's natural gas. In September 2002, the National Energy Board rejected New Brunswick's proposition.

A pipeline designed to connect Canadian natural gas fields to southern New York and Pennsylvania – Millennium -- is currently awaiting approval by Canadian regulators who are reviewing the pipeline's upstream suppliers. If approved, construction on the Millennium Pipeline will begin after almost six years of regulatory review.
The pipeline would replace an older, smaller line already in place. The project is sponsored by two Canadian firms, Westcoast Energy and TransCanada, and two American firms, Columbia Gas Transmission and MCN Energy Group. The Millennium Pipeline won final US regulatory approval in September 2002, when FERC authorized the pipeline's final leg into New York.
Exploration and production activity in the Mackenzie Delta, Beaufort Sea, and Alaskan North Slope has sparked interest in an Arctic pipeline. Combined Alaskan and Canadian assets in the area stand at about 40 tcf of proven reserves, with far more probable reserves.

Alaskan officials, Canadian provincial governments, and international investors have all supported different pipeline routes in recent months, with two distinct options emerging as the front-runners. The Alaska Highway route would run from Alaska's Prudhoe Bay, southward through the Canadian provinces of Yukon and British Columbia, where the natural gas could tie into western Canada's distribution network.
The other option entails two separate projects, the first extending from Prudhoe Bay southward across the Beaufort Sea to Canada's Northwest Territories, where it would link to the second component, the Mackenzie Delta pipeline, continuing southward into British Columbia.

A consortium of companies active in the region, known as the Mackenzie Delta producers group, have moved quickly in support of the Mackenzie Delta pipeline. In May 2002, the Mackenzie Delta Producers Group (Imperial Oil, Conoco, Shell, ExxonMobil and the Mackenzie Valley Aboriginal Pipeline Corp.) awarded conceptual and preliminary engineering contracts for construction of the pipeline, and in June 2002 announced an open season to gather non-binding commitments from potential pipeline customers.
The group plans to submit a formal development application for construction of the pipeline to Canada's National Energy Board in 2003, and expects the pipeline to come online between 2007 and 2010.

Coal
Canada is a major coal producer and consumer, with estimated 2000 output of 76.2 mm short tons, consumption of about 67 mmst, and reserves of 7.2 bn short tons.
Alberta accounts for about half of Canada's coal production, while British Columbia and Saskatchewan account for about 30 % and 15 %, respectively. Bituminous coal makes up about half of Canada's coal output, with sub-bituminous (about one-third) and lignite the rest. Canadian coal consumption is primarily (90 %) for electricity generation, with the remainder mainly used for steel-making. About 80 % of Canada's coal exports are for metallurgical purposes, with Japan and South Korea representing the country's largest customers.

Electricity
Canadian electricity generation in 2000 totalled 567.1 bn kWh, of which 60 % was hydropower, 26 % was conventional thermal power (oil, gas, and coal), 12 % was nuclear generation, and 1 % was derived from other renewable sources. Canada was the largest producer of hydropower in the world in 2000, and hydro sources are not yet believed to be fully exploited.
Trends in coming years are expected to favour thermal power generation, mainly from natural gas. Canadian nuclear output has declined to 69.8 bn KWh in 2000, compared to its peak of 102.4 bn KWh in 1994. Ontario contains the bulk of Canadian nuclear capacity.

Canada exported about 38 bn KWh of electricity (gross) to the United States in 2001, mostly from Quebec, Ontario, and New Brunswick to New England and New York. Smaller volumes are exported from British Columbia and Manitoba to Washington state, Minnesota, California, and Oregon. There is considerable reciprocity between the Canadian and US power markets, as the United States also exports smaller volumes of electricity to Canada (18 bn KWh in 2001).
Natural gas-fired power plant construction is on the rise in Canada, with a threefold increase in gas power generation predicted by the Canadian Energy Research Institute over the coming decade. PanCanadian Petroleum, TransAlta, EPCOR, and ATCO Power are all in various stages of developing new (mostly cogeneration) gas-fired plants in Alberta and Saskatchewan.

Under Canada's constitution, electricity regulatory authority falls under the jurisdiction of the provinces. In most provinces, the bulk of generation, transmission, and distribution is provided by a few dominant utilities. Although some of these utilities are privately owned, most are owned by the provinces. There is also limited independent power producer (IPP) generation, mostly for sales to the larger utilities.
Alberta and Ontario, which together account for about half of Canada's electricity market, have made efforts to deregulate their power sectors. Full deregulation began in Alberta in January 2001, and in Ontario in May 2002. In both provinces, electricity prices spiked shortly following initial deregulation, causing provincial governments to freeze the electricity prices charged to consumers, and to pay the difference to electric companies out of the government budget.
Quebec and British Columbia do allow third party access to their electricity grids as the result of trade agreements with the United States, but neither province has plans to break up its utility monopoly.

Environment
Canada's energy abundance has encouraged the development of a highly fuel-intensive economy based on natural resource extraction and processing. This heavy reliance on energy-intensive industries has led to serious environmental concerns, primarily regarding air pollution and climate change.
In 2000, Canada consumed 13 quadrillion Btu of energy and emitted 158 mm tons of carbon. The industrial sector was the primary emitter of carbon dioxide and within the sector, six energy intensive industries accounted for over 80 % of these emissions. Per capita energy consumption ranks fourth among OECD countries, and per capita carbon emissions rank third.
Canada is proving to be a leader in addressing environmental concerns. Renewable energy sources, such as wind, are beginning to gain more attention as Canada works toward meeting international obligations to reduce greenhouse gas emissions.

Country overview
Prime Minister: Jean Chretien (since 11/4/93)
Independence: July 1, 1867 (from UK)
Population (July 2001E): 31.6 mm
Location/size: Northern North America/3.85 mm sq. miles (slightly larger than the United States)
Administrative divisions: 10 provinces and 3 territories*; Alberta, British Columbia, Manitoba, New Brunswick, Newfoundland, Northwest Territories*, Nova Scotia, Nunavut*, Ontario, Prince Edward Island, Quebec, Saskatchewan, Yukon Territory*
Major cities: Toronto, Montreal, Vancouver, Ottawa (capital), Edmonton, Calgary, Winnipeg, Quebec
Languages: English (official), French (official)
Ethnic groups: British Isles origin (40 %), French origin (27 %), other European (20 %), indigenous Indian, Eskimo (1.5 %)
Religions: Roman Catholic (45 %), Protestant (41 %)
Defence (8/98): Army (20,900), Navy (9,000), Air Force (14,000), Other (15,700)

Economic overview
Exchange rate (12/12/02): $ 1 = C$ 1.56
Gross Domestic Product (GDP, 2002E, $ US): $ 724.6 bn
Real GDP growth rate (2001E): 1.5 % (2002E): 3.4 % (2003F): 3.6 %
Inflation rate (consumer prices, 2002E): 1.4 %
Unemployment rate (2002E): 7.6 %
Merchandise exports (2002E, $ US): $ 273 bn
Merchandise imports (2002E, $ US): $ 238 bn
Merchandise trade balance (2002E, $ US) $ 35 bn
Current account balance (2002E, $ US): $ 13.5 bn
Major export products: Motor vehicles and parts, newsprint, wood pulp, timber, crude petroleum, machinery, natural gas, aluminium, telecommunications equipment, electricity
Major import products: Machinery and equipment, crude oil, chemicals, motor vehicles and parts, durable consumer goods, electricity
Major trading partners: United States, European Union

Energy overview
Minister of Natural Resources: Herb Dhaliwal
Conventional crude oil reserves (2002E): 4.9 bn barrels
Oil sands reserves (2002E): 1.75 - 2.5 tn barrels
Oil production (2002E): 2.9 mm bpd, of which 2.0 mm bpd was crude oil
Oil consumption (2002E): 2.0 mm bpd
Net oil exports (2002E): 0.9 mm bpd
Oil exports to the United States (January-September 2002): 1.9 mm bpd, 1.4 mm bpd of which was crude oil
Oil imports from the United States (January-September 2002): 105,000 bpd
Total gross oil imports (2001): 1.15 mm bpd
Natural gas reserves (1/1/02): 59.7 tcf
Natural gas production (2000): 6.5 tcf
Natural gas consumption (2000): 3.2 tcf
Net natural gas exports (2000): 3.3 tcf
Coal reserves (2000): 7.2 bn short tons
Coal production (2000): 76.2 mm short tons
Coal consumption (2000): 67 mmst
Electric generation capacity (1/1/00): 111 mm kW
Electricity generation (2000): 567.1 bn kWh (60 % hydro, 26 % thermal, 12 % nuclear, 1 % geothermal and other)

Environmental overview
Minister of Environment: David Anderson
Total energy consumption (2000): 13.07 quadrillion Btu* (3.3 % of world total energy consumption)
Energy-related carbon emissions (2000): 157.95 mm tons of carbon (2.5 % of world carbon emissions)
Per capita energy consumption (2000): 425 mm Btu (vs. US value of 351.0 mm Btu)
Per capita carbon emissions (2000): 5.2 tons of carbon (vs. US value of 5.6 tons of carbon)
Energy intensity (2000): 18,542 Btu/ $ 1995 (vs. US value of 10,918 Btu/ $ 1995)**
Carbon intensity (2000): 0.22 tons of carbon/thousand $ 1995 (vs. US value of 0.17 tons/thousand $ 1995)**
Sectoral share of energy consumption (1998): Industrial (48.0 %), residential (17.7 %), transportation (18.9 %), commercial (15.5 %)
Sectoral share of carbon emissions (1998): Industrial (40.3 %), transportation (33.0 %), residential (14.0 %), commercial (12.7 %)
Fuel share of energy consumption (2000): Oil (30.9 %), natural gas (25.7 %), coal (11.4 %), hydro (28 %), nuclear (6 %)
Fuel share of carbon emissions (2000): Oil (44.9 %), natural gas (31.4 %), coal (23.7 %)
Renewable energy consumption (1998): 3,850 t Btu*
Number of people per motor vehicle (1998): 1.8 (vs. US value of 1.3)

Status in climate change negotiations: Annex I country under the United Nations Framework Convention on Climate Change (ratified December 4th, 1992). Under the negotiated Kyoto Protocol (signed on April 29th, 1998, but not yet ratified), Canada has agreed to reduce greenhouse gases 6 % below 1990 levels by the 2008-2012 commitment period.
Major environmental issues: Air pollution and resulting acid rain severely affecting lakes and damaging forests; metal smelting, coal-burning utilities, and vehicle emissions impacting on agricultural and forest productivity; ocean waters becoming contaminated due to agricultural, industrial, mining, and forestry activities
Major international environmental agreements: A party to Conventions on Air Pollution, Air Pollution-Nitrogen Oxides, Air Pollution-Sulphur 85, Air Pollution-Sulphur 94, Antarctic Treaty, Biodiversity, Climate Change, Desertification, Endangered Species, Environmental Modification, Hazardous Wastes, Marine Dumping, Nuclear Test Ban, Ozone Layer Protection, Ship Pollution, Tropical Timber 83, Tropical Timber 94, Wetlands and Whaling. Has signed, but not ratified, Air Pollution-Volatile Organic Compounds, Antarctic-Environmental Protocol, Law of the Sea and Marine Life Conservation

* The total energy consumption statistic includes petroleum, dry natural gas, coal, net hydro, nuclear, geothermal, solar, wind, wood and waste electric power. The renewable energy consumption statistic is based on International Energy Agency (IEA) data and includes hydropower, solar, wind, tide, geothermal, solid biomass and animal products, biomass gas and liquids, industrial and municipal wastes. Sectoral shares of energy consumption and carbon emissions are also based on IEA data.
**GDP based on EIA International Energy Annual 2000.

Oil and gas industries
Organization: Private sector (major companies: ExxonMobil's Imperial Oil, Shell's Shell Canada, Petro-Canada, Suncor, EnCana).
Major oil and gas producing provinces: Alberta; British Columbia; Saskatchewan
Major oil pipelines: Trans Mountain; Enbridge
Oil refining capacity, (January 2002): Ontario (560,200 bpd); Alberta (435,550 bpd); Quebec (394,900 bpd); New Brunswick (250,000 bpd); British Columbia (62,250 bpd); Newfoundland (105,000 bpd); Nova Scotia (84,000 bpd); Saskatchewan (52,000 bpd)
Major gas pipeline companies: Enbridge, TransCanada PipeLines