Energy and GHG Emissions in British Columbia1990 - 2010
John Nyboer and Maximilian KniewasserCanadian Industrial Energy End-use Data and Analysis Centre (CIEEDAC)
Simon Fraser University
June 2012
Environment Canada, Natural Resources Canada, Aluminium Industry Association, Canadian Chemical Producers’ Association, Canadian Construction Association, Canadian Foundry Association, Canadian Gas Association, Canadian Petroleum Products Institute, Canadian Steel Producers Association, Cement Association of Canada, Forest Products Association of Canada, Mining Association of Canada, Pacifi c Institute for Climate Solutions.
Sponsors of CIEEDAC:
Pacific Institute for Climate SolutionsUniversity of VictoriaPO Box 1700 STN CSCVictoria, BC V8W 2Y2
Phone 250-853-3595 Fax 250-853-3597E-mail [email protected] pics.uvic.ca
The Pacific Institute for Climate Solutions gratefully acknowledges the generous endowment provided by the Province of British Columbia through the Ministry of Environment in 2008. This funding is enabling ongoing independent research aimed at developing innovative climate change solutions, opportunities for adaptation, and steps toward achieving a vibrant low-carbon economy.
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Executive Summary
The Canadian Industrial Energy End-‐use Data and Analysis Centre (CIEEDAC) prepared this report on energy in British Columbia for the Pacific Institute for Climate Solutions (PICS). The report is divided into three sections.
The first section provides an overview of information relating to energy supply and use, greenhouse gas emissions and energy efficiency in British Columbia. It includes total energy use and emissions data for all sectors and some industries from 1990 to 2010, as well as energy intensity indicators based on population and monetary production (Gross Domestic Product, GDP). Appendix A contains detailed data tables disaggregated by economic sectors, including Total Industrial (and its major sub-‐sectors), Residential, Commercial/Institutional and others.
The Statistics Canada (STC) publication Report on Energy Supply and Demand (RESD) is the primary data source for energy used in this report. It disaggregates data by province to the 3-‐digit level of the North American Industry Classification System (NAICS) for a limited number of industries. GHG emissions data were obtained from Environment Canada’s annual National Inventory Report (EC 2011). This report provided both the coefficients to calculate the GHG emissions generated in the various BC sectors and an absolute value of emissions against which the calculated data could be compared. Production and population data were both retrieved from the Canadian Socio-‐economic Information Management (CANSIM) system, an STC online database.
Between 1990 and 2010, total energy use in British Columbia rose 15%. In 2010, total use was 1,070 PJ. Over this time, population grew by 38% and GDP by 82%. Given the greater growth rates in population and GDP compared with energy use, energy intensity declined by 16% per person and 37% per dollar from 1990.
Natural gas, electricity and refined petroleum products (RPPs) are the major fuels of the BC economy. Use of natural gas in 2010 was 3% lower than it was in 1990 while electricity use increased 12% and RPP use 24%. Coal demand, although representing a small portion of total energy use, increased the most, about 232%.1 Hydroelectricity continued to dominate electricity production but lost ground to thermal generation, which was at its highest point since 1990 (16%). Electrical generation using heavy fuel oil (HFO) and diesel/light fuel oil (LFO) lost ground to “other” (a mix of fuels not defined in RESD). Natural gas’s share of generation decreased as well, but total generation from natural gas plants more than doubled.
Total Industrial energy use decreased by 1% and use in Total Manufacturing decreased 8%. Energy use in Transportation increased 43% while Agriculture increased 78% due to a greater use of natural gas. Energy use in the Commercial/Institutional sector stayed level compared to 1990 and in the Residential sector energy use rose 13%.
1 These data are under review and may change. Some provincial agencies indicate that coal data from STC do not currently correspond to what has been noted by these agencies.
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GHG emissions fluctuated over the study period, peaking in 2004 and finishing the period 21% above 1990. GHG emissions intensity per capita decreased by 12% since 1990 and GHG intensity based on GDP decreased 25% over that period. From 2009 to 2010, GHG emissions per capita decreased to 9.79 tonnes CO2e from 11.12 tonnes CO2e. An analysis of GHG emissions by sector reveals that emissions in the following sectors increased significantly: Electricity (24%), Transportation (44%) and Agriculture (63%). GHG emissions decreased noticeably in the following sectors: Residential (15%), Commercial/Institutional (27%) and Total Industrial (30%).
GHG emissions resulting from the production of electricity fluctuated greatly over the study period, mainly due to variations in the generation of electricity in the non-‐utility sub-‐sector.
The second section of this report summarizes the latest version of CIEEDAC’s cogeneration database as of March 2012.2 It identifies the size (electrical capacity, kWe
3) and system operator/thermal host of industrial, commercial/institutional and district energy cogeneration facilities in British Columbia. It also includes performance characteristics of cogeneration systems operating in British Columbia.
In the past, CIEEDAC relied on secondhand data sources such as Statistics Canada, corporate websites, private consultants and electric utilities to identify cogeneration facilities and compile data on their characteristics. For the last four years, CIEEDAC has gathered data on cogeneration systems directly from the system operators. A questionnaire goes out to each facility, seeking verification of existing data and requesting new information about each site. The resulting database is increasingly reliable and contains data that enhances understanding of the opportunities for and limitations of cogeneration in Canada and its provinces.
The CIEEDAC database currently contains information on 6.6 GWe of cogeneration capacity in Canada, with British Columbia contributing 1.02 GWe, or 16% of total national capacity. The Pulp and Paper sector accounts for 54% of total operational capacity in British Columbia and has a cogeneration level of 0.55 GWe.
The third section of this report presents information on renewable energy in British Columbia. A database of facilities was established in 2002, using data from Statistics Canada and other sources. The results are presented from the most recent data survey of two years ago, including data on the mix of renewable energy by resource/technology type, scale (capacity and annual generation), owner/operator, green certification status and vintage.
Renewable energy provided between 19% and 21% of the energy produced in BC in 2009 (based on extrapolations of data from survey respondents). The installed renewable electricity facilities represented almost 88% of the provincial total electricity capacity in that year. The installed renewable electrical capacity of 12.8 GW is
2 Refer to www.cieedac.sfu.ca for more information on cogeneration data. 3 1,000 W of electric capacity
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dominated by hydroelectricity at 96.6% and cogeneration from biomass wood residue at 3.3% of the total, with biogas and solar photovoltaic sources accounting for only about 0.1% of BC’s installed capacity.
Based on data from STC’s RESD and CANSIM databases, electricity generation in BC was the source of about 1.45 Mt of greenhouse gases (CO2e) in 2009. This is a relatively low value compared with many other provinces in Canada and is well below the national average. It results from BC’s high percentage of renewable sources of electricity. If these facilities were replaced with combined-‐cycle gas turbines, GHG emissions from electricity generation would likely be as high as 29.3 Mt CO2e.
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Acknowledgments
CIEEDAC wishes to thank the Pacific Institute for Climate Solutions, Natural Resources Canada and Environment Canada who support the work of CIEEDAC through their sponsorship and financial contributions, part of which funded this report.
This project was undertaken with the financial support of the Government of Canada. Ce projet été realisé avec l’appui financier du Gouvernement du Canada.
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Table of Contents
Executive Summary ...................................................................................................... ii
Acknowledgments ....................................................................................................... v
Table of Contents ........................................................................................................ vi
Introduction .............................................................................................................. viii
1 Energy Use and GHG Emissions in BC’s Economic Sectors, 1990 to 2010 ................ 1 1.1 Objectives ............................................................................................................... 1 1.2 Methodology .......................................................................................................... 1 1.2.1 Data Sources ..................................................................................................... 1 1.2.2 Sectors and Industries Included in This Section ................................................ 2 1.2.3 Intensity Indicators ........................................................................................... 3
1.3 Energy Intensity, 1990–2010 .................................................................................. 3 1.4 Energy Use by Fuel Type ......................................................................................... 5 1.5 Energy Use by Sector .............................................................................................. 6 1.5.1 Energy Use in Industry ...................................................................................... 7 1.5.2 Commercial and Residential Sectors .............................................................. 10
1.6 Electricity Production ........................................................................................... 10 1.6.1 Total Primary and Secondary Production ....................................................... 10 1.6.2 Utility and Non-‐utility Production .................................................................. 13
1.7 Greenhouse Gas Emissions, 1990–2010 ............................................................... 14 1.7.1 GHG Emissions by Fuel ................................................................................... 15 1.7.2 GHG Emissions by Sector ................................................................................ 17 1.7.3 GHG Emissions from Electricity Generation ................................................... 18
1.8 Conclusion and Summary ..................................................................................... 18
2 Cogeneration Facilities in British Columbia, 2010 .................................................. 20 2.1 Objectives ............................................................................................................. 20 2.2 Methodology ........................................................................................................ 21 2.2.1 Data Sources ................................................................................................... 21
2.3 Cogeneration Results, 2010 .................................................................................. 21 2.3.1 Sector Results ................................................................................................. 22 2.3.2 Cogeneration System Performance Characteristics ....................................... 22
2.4 Conclusion and Summary ..................................................................................... 23
3 Renewable Energy in British Columbia .................................................................. 25 3.1 Objectives ............................................................................................................. 25 3.2 Background on Renewable Energy Technologies ................................................. 25
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3.2.1 Hydroelectricity .............................................................................................. 26 3.2.2 Wind Power .................................................................................................... 26 3.2.3 Biomass and Biogas ........................................................................................ 26 3.2.4 Solar Photovoltaic ........................................................................................... 27 3.2.5 Geothermal and Earth Energy ........................................................................ 27 3.2.6 Others ............................................................................................................. 27
3.3 Methodology ........................................................................................................ 28 3.3.1 Data Sources ................................................................................................... 28
3.4 Renewable Energy in British Columbia, 1990–2009 ............................................. 30 3.4.1 Capacity .......................................................................................................... 30 3.4.2 Annual Generation of Energy ......................................................................... 32 3.4.3 Capacity Utilization ......................................................................................... 33 3.4.4 Characteristics of Electricity Generators ........................................................ 34 3.4.5 Characteristics of Thermal Energy Generators ............................................... 35
3.5 Comparison with the Rest of Canada ................................................................... 36 3.6 Conclusion and Summary ..................................................................................... 36
4 Bibliography ......................................................................................................... 37
List of Appendices ...................................................................................................... 39
Appendix A: Energy Use Data Tables .......................................................................... 40
Appendix B: Cogeneration Data Tables, 2010 ............................................................. 58
Appendix C: Renewable Energy Data, 2009 ................................................................ 59
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Introduction
The Canadian Industrial Energy End-‐use Data and Analysis Centre (CIEEDAC) prepared this report for the Pacific Institute for Climate Solutions (PICS). While CIEEDAC’s annual reports on energy efficiency, cogeneration and renewable energy contain some of the information presented here, this report provides information specific to British Columbia.
Both Canadian industry and regional Canadian governments increasingly see the need for accurate data on historic energy use and greenhouse gas (GHG) emissions. These data are used to:
1) determine trends in energy supply, energy use and GHG emissions within Canada as a method of determining the impacts of changes in technology, processes and attitudes about energy;
2) compare Canadian industrial, residential, commercial, transportation, agricultural and utility performance to that of other regions and countries; and
3) monitor the environmental impacts of energy use, such as levels of GHG emissions.
To draw proper conclusions from the data, industry and governments need to know that the values reflect reality as closely as possible. This report assesses the data and interprets it in a useful and accessible format in three overview sections: energy use and emissions in BC’s economic sectors, cogeneration in British Columbia and renewable energy in British Columbia.
The first section draws on Statistics Canada data to track energy supply and use, energy intensity and greenhouse gas emissions from 1990 to 2010. This section deals with fossil fuels and electricity generation for all sectors, with additional details provided for selected industries. The second section uses CIEEDAC’s cogeneration database to describe cogeneration in British Columbia from 2000 to 2010. The database draws on information from operators of cogeneration facilities, industry sources and Statistics Canada data. The third section describes the different types of renewable energy sources and then presents an overview of renewable resources and technology in British Columbia. The information is drawn from a survey of operators, along with data from Statistics Canada and other sources. However, owing to funding limitations, no survey was conducted this year. The most recent data in this section are for 2009.
About CIEEDAC
CIEEDAC focuses on energy information relevant to Canada’s industrial sector. One of CIEEDAC’s primary goals is to expand and improve the existing knowledge on energy supply and use, greenhouse gas emissions, cogeneration and renewable energy by establishing or enhancing processes for the regular and timely collection of reliable data. CIEEDAC provides a range of services to industry and government. It performs specific retrieval and analyses from its databases based on requests from interested parties. It also produces various reports each year, presenting the latest data on energy use and
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related information for the Canadian industrial sector. When doing provincial reports, CIEEDAC broadens its scope to include reviews of other sectors in addition to the industrial sector. These include the commercial, residential, agricultural and transportation sectors.
About PICS
PICS partners with governments, the private sector, other researchers and civil society to research, monitor and assess the potential impacts of climate change and to assess, develop and promote viable mitigation and adaptation options to better inform climate change policies and actions.
PICS is hosted and led by the University of Victoria in partnership with BC’s other research-‐intensive universities (Simon Fraser University, the University of British Columbia and the University of Northern British Columbia). Building on the strengths of its partner universities, PICS works to develop innovative climate change solutions, seek new opportunities for positive adaptation and lead the way to a vibrant low-‐carbon economy.
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1 Energy Use and GHG Emissions in BC’s Economic Sectors, 1990 to 2010 This first section of the report presents information available from Statistics Canada (STC) on energy use in British Columbia and various sectors of the BC economy. It includes a time series of gross energy use and provides energy and emissions intensity indicators using population and economic output (Gross Domestic Product [GDP]) as denominators in the intensity ratios. Detailed data are provided in Appendix A.
1.1 Objectives The objectives of the first section of this report are to:
• demonstrate the quantity and quality of data available for all sectors and industries in British Columbia;
• identify trends in energy supply, use and greenhouse gas (GHG) emissions within aggregate sectors and industries in the region; and
• identify weaknesses with respect to data collection and the impact they have on portraying a consistent picture of energy supply, use and GHG emissions.
1.2 Methodology 1.2.1 Data Sources
Energy Data STC receives its energy supply and use data from a number of surveys. Each supplier of energy (oil products, natural gas, coal, electricity, etc.) provides data on energy used to prepare its product for sale. It also provides distribution data on who receives the energy product after processing. These data are collectively aligned in an energy-‐balanced Report on Energy Supply and Demand (RESD). Because of the significant use of energy in the industrial sector, STC obtains data from the Industrial Consumption of Energy (ICE) survey. Released in the summer of every year for the previous year, ICE data provides specific details on energy use in physical units.
Recently, STC has worked to harmonize the RESD and ICE data more completely. This has significantly affected the historic data as STC is updating data back to 1995 in the harmonization process. This report highlights some of the changes that have already occurred as a result of STC’s effort.
The RESD data are disaggregated by province, but industry disaggregations are not nearly as detailed as the North American Industry Classification System (NAICS) allows or as ICE provides.4 RESD data are used in this report because they form a balanced energy database. RESD attributes all energy produced and used to the various sectors in British Columbia and the other provinces.
4 ICE data are never released by province or any other region, only nationally.
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GHG Emissions Data Environment Canada (EC) publishes its National Inventory Report (EC 2011) annually, 17 months after the end of the year. This publication provides data on process emissions of GHGs, as well as coefficients that can be used to determine CO2, CH4 and N2O emissions based on fuels used. The coefficients are defined in units of emissions per physical unit of energy. In the analysis used in this report, physical units of energy are multiplied by these coefficients to determine the emissions generated in the use of the fuel.
There are a number of issues related to the analysis of GHG emissions. These include the definition/handling of process versus fuel-‐based GHG emissions; the degree to which the energy (and thus estimated GHG) data are considered confidential; the calculation of indirect emissions from the purchase of steam or electricity;5 the role of electricity production in the industry; and the difference in levels of energy use. Some of these are addressed throughout the section.
Economic Output Data The Canadian Socio-‐economic Information Management (CANSIM) system is a computerized database and information retrieval system updated weekly by STC. The database contains nearly 600,000 time series of data covering a wide variety of social and economic aspects of Canadian life that can be viewed in a number of different dimensions including geographical regions. CANSIM Table 379-‐0025 contains GDP in 2002 constant dollars, disaggregated by province, and organized according to the NAICS system. Data that populate this database come from a survey circulated annually by STC. Constant dollar data is derived by multiplying current-‐period quantities of production by their prices in the base year.
This report includes information on industry output in monetary units, which represents industry’s contribution to GDP and was used to calculate intensity ratios. CIEEDAC did not review or critique these data, unlike the energy and emissions data used in the report.
1.2.2 Sectors and Industries Included in This Section Table 1.1 lists the BC sectors and industries that are included in this section of the report. Energy use data are available for these sectors and industries and were used to calculate GHG emissions.
5 While data are available to calculate emissions per unit of electricity generated, determining the carbon content of imported energy and its role in the total energy picture increases the complexity of the calculation. Further, credit for exported electricity, if that is allowed to form part of the calculation, complicates the estimation even more.
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Table 1.1. British Columbia Sectors and Industries Included in This Report
Sector/Industry Sector/Industry Primary and Secondary Production of Electricity Total Industrial Total Manufacturing, cont. Total Mining, Oil and Gas Extraction Other Manufacturing Total Manufacturing Forestry
Pulp and Paper Construction Smelting and Refining, Non-‐ferrous Transportation Cement Agriculture Petroleum Refining Residential Chemicals Commercial, Institutional and Public Administration
1.2.3 Intensity Indicators Intensity ratios (energy over output, population over output) are useful for illustrating general trends over time. Indicators based on physical rather than monetary units tend to be a better proxy for technological or process innovations because monetary units are affected by many factors not associated with energy, such as costs of labour or selling price of the final product.6 However, monetary data are generally more available and provide a generic unit for estimating intensity of a combination of industries that have different physical units (e.g., tonnes of cement compared to numbers of cars). Although physical production values are available for some sectors, further research is required before these data can be used. Measures of energy intensity provided in this report should be viewed with caution as they are based on monetary measures of output.
1.3 Energy Intensity, 1990–2010 This section reports on changes in total energy use and GDP for BC industries from 1990 to 2010. It also includes a brief discussion of population growth in relation to these changes. Appendix A contains detailed tables of the data used.
Figure 1.1 presents BC’s energy use (PJ), population growth (millions) and GDP (in 2002 $billions) for 1990 to 2010. Total energy use includes confidential consumption, biomass used in the Pulp and Paper sector, and energy used to make secondary electricity.
6See An Assessment of Data on Output for Industrial Sub-‐Sectors (CIEEDAC, 1993) for more information on the issues of physical versus monetary units for calculating intensity indicators and on CIEEDAC's recommendations of appropriate units.
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Figure 1.1. Energy Use, Population and GDP for BC, 1990–2010
Sources: STC RESD; CANSIM Table 379-‐0025 and Table 051-‐0001
Total energy use increased steadily until 2000 and then appears to have levelled off somewhat from 2002 until 2007. Energy use decreased after 2007 when the economy (GDP) flattened and dropped. Energy use finished the period 15% above 1990 levels and 2.6% above 2009.
Both population and GDP grew consistently over the study period. Population increased with an average annual growth rate of just over 1.5%, ending the period at 37.6% above 1990. GDP had an average annual growth rate of just over 2.9% and ended the period at 82.4% above its 1990 level. The population grew 1.6% during 2010, while GDP rose by 3.2% (8% in industrial sectors).
CIEEDAC used GDP and population data to calculate the energy intensity indicators plotted in Figure 1.2. These values are ratios of energy use per unit of GDP or population. Intensities are presented as indices, normalized to 1990, which helps demonstrate changes from the base line. The indices show different rates of change, although both are trending downward (becoming less intense). Between 1990 and 2010, energy intensity based on population decreased 16%, while the intensity based on GDP decreased 37%. From 2009 to 2010, energy intensity based on population increased marginally (1%), while intensity based on GDP decreased marginally (<1%). These indicators suggest that, since 1990, energy use per person and per dollar produced both decreased but at different rates. This may, in fact, be true, but other factors may also have caused the change (e.g., changes in industry structure, changes in service economy versus manufacturing economy, changes to value-‐added that do not affect energy).
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Figure 1.2. Energy Intensity Indicators for BC, 1990–2010
Sources: Calculated from STC RESD; CANSIM Table 379-‐0025 and Table 051-‐0001
1.4 Energy Use by Fuel Type
Figure 1.3 presents energy use by fuel type. Refined petroleum product (RPP) use declined marginally during the 2008 downturn but increased in 2010 and is now 24% above 1990 levels. Of all energy sources, this one appears to have been the least affected by the economic changes in 2008 and 2009. That said, most RPPs dropped in 2008 but diesel and jet fuel were up, while in 2009 most RPPs were up while diesel and jet fuel dropped. Natural gas use in 2010 was 3% lower than it was in 1990, down nearly 5% from 2009. Electricity use increased steadily from 1990 to 2007, a peak year, and declined 10% in 2008, remaining relatively flat since then at a level 12% higher than 1990.
Figure 1.3. Energy Use by Fuel Type in BC, 1990–2010
Note: “Petroleum Products” (= RPPs) includes still gas, gasoline, kerosene, diesel, light and heavy fuel oil, petroleum coke, aviation gasoline and aviation turbo fuel; “Other” includes coal, coke, gas plant natural gas liquids (NGLs), steam, wood waste (hog fuel) and spent pulping liquor. Source: STC RESD
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Not visible in Figure 1.3 as a separate category, coal use increased dramatically between 1990 and 2010. Although proportionally smaller than RPPs and natural gas, it had the greatest increase (232%) over the period but declined nearly 35% from its peak in 2006.7 While RESD provides no indication of which industry uses this fuel type (due to confidentiality), it is likely the cement industry, which began using coal instead of natural gas at the beginning of the millennium. Appendix A contains a table of energy use by fuel type.
1.5 Energy Use by Sector Figure 1.4 presents a comparison of energy use in British Columbia’s major economic sectors. All sectors display some variation in use between 1990 and 2010. The impact of the economic downturn of 2008–2009 is most obvious in the Total Industrial and Commercial/Institutional sectors.
Figure 1.4. Energy Use in the Major Economic Sectors of BC, 1990–2010
Source: STC RESD
The Total Industrial sector’s variable but generally rising trend in energy use fell dramatically from 2007 to 2008. It showed signs of increase again in 2010 to a point 1% lower than 1990. The sector is an aggregation of Construction, Forestry, Total Manufacturing, and Mining/Oil and Gas Extraction. It increased energy use marginally in 2009 and 2010 but was still 18% below peak levels in 2000. The Commercial/Institutional sector also increased until the economic downturn where, like the Total Industrial sector, consumption fell to a point about the same as 1990. Sectors that showed relatively significant increases over the period were: Residential at 13%, Transportation at 43%, Electricity generation at 70% and Agriculture at 78%. The data for the Agriculture sector showed a significant increase in 2010 due to a 10-‐fold increase in the use of natural gas. Because of changes in STC’s methodology, these data should be treated with caution. Since 2000, energy use in the Agriculture sector has been quite flat. 7 We see various views on the increase in coal amongst reviewers of this report. These data will be reviewed.
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Energy use for secondary electricity generation fluctuated significantly, increasing by 64% over the report period and by 5% in 2010.8 In 2010, 16% of BC’s electricity came through thermal generation, representing a total increase in thermal-‐sourced electricity production of 168% over the study period.
1.5.1 Energy Use in Industry
Figure 1.5 presents the contributions of BC’s industrial sectors to Total Industrial energy use. Total Industrial use was 1.2% below 1990 levels at the end of 2010 but had increased 6.6% from 2009. Energy use by Total Manufacturing, which includes Pulp and Paper, by far its largest component, was 7.7% lower than 1990 levels, but increased 4% over 2009.
Figure 1.5. Energy Use by Industry in BC, 1990–2010
Source: STC RESD
The non-‐manufacturing industries are relatively tiny in comparison. They experienced changes in consumption over the period, but these are not obvious in Figure 1.5 because of the graph’s scale. For example, he Forestry and logging and support activities for forestry 9(hereafter “Forestry”) energy use increased fairly consistently until 2000 when a significant jump of 42% occurred in 2001. After that, it was relatively flat until 2008, when it dropped again to 2000 levels and then nearly doubled that level in 2010. It finished the period 243% higher than 1990. Most of the expansion occurred in diesel fuel. The shifts seem to have coincided with changes in STC data as mentioned earlier (reconciliation of ICE and RESD).
8 Secondary electricity production is mainly from burning fuels (natural gas, oil, diesel, coal or other fuels) to create steam in a thermal generation process. For Figure 1.4, we also included the electricity used by the industry during its production and distribution. 9 The industry designated Forestry and logging and support activities for forestry covers only the extraction of forest products and does not include any processing that would otherwise be defined as Wood Products (dimension lumber, panel board, plywood, shakes, and the like) or Pulp and Paper.
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Energy use in the Mining/Oil and Gas Extraction industry increased dramatically in recent years, finishing the period 92% above 1990 levels. The rapid expansion of the gas extraction industry in BC may be in part responsible for this increase.10
Energy use in the Construction industry rose nearly 17% in 2010 from 2009 (a very low year due to the economic decline of 2008–2009). Despite this rise, the Construction industry used 23% less energy than it did in 1990.
Figure 1.6 disaggregates use in Total Manufacturing by each manufacturing industry. Note that all or most of the data for Cement, Petroleum Refining (since 1999), Chemical Production and Metal Smelting are not available. These industries contain too few firms to allow for the release of the data. The aggregate of these in Total Manufacturing showed use levels 8% lower than 1990.
Figure 1.6. Energy Use in Manufacturing in BC, 1990–2010
Source: STC RESD
Pulp and Paper, the largest manufacturing industry by far, consumes significant amounts of biomass energy (spent pulping liquor and solid wood waste).11 Over the study period, Pulp and Paper showed cyclical energy use patterns until 2008, when the drop was considerable. Data for the last two years of the period seem to indicate some recovery. At the end of 2010, energy use in the Pulp and Paper industry was 7% below 1990 levels.
10 Data from the Annual Census of Mines, which looks at the extraction of metal ores, non-‐metallic ores, and sand and gravel pits/quarries, does not show any significant change in energy consumption in BC. While the data source is different than that used in the RESD, it is collected by STC on behalf of Natural Resources Canada and can be used to indicate trends. 11 There are some uncertainties regarding data for spent pulping liquor and solid wood waste for 1990 and 1991. Because of the impact on energy consumption levels, these data were extrapolated in order to present a more complete picture of energy consumption in British Columbia.
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With the most recent update of STC RESD data, natural gas use in the Other Manufacturing group (Food Processing, Textiles, Clothing, Printing, Furniture, Electronics, etc.) declined significantly. Electricity and RPP use rose. As this is the first assessment of the reconciliation of ICE and RESD data, a number of uncertainties arise. Currently, it appears that Other Manufacturing increased use by 14% over 1990 levels, rose 6% from 2009 but, at the end of 2010, was still 58% below the peak year of 2001. Data show that natural gas use in this sub-‐sector dropped by 66% in 2006 from 2007 while other fuels remained roughly at the same level.
Figure 1.7 presents indicators of energy intensity by sector based on GDP, indexed to 1990. Between 1990 and 2010, energy intensity in the Total Industrial sector decreased by 28.5%. Within the sector, Total Manufacturing decreased by 24%, and Construction decreased by 54%. The energy intensities for Forestry and Mining/Oil and Gas Extraction increased. The rapid increase in the energy intensity in Forestry was due to very large changes in diesel fuel use without any commensurate change in GDP. Forestry’s energy intensity climbed dramatically between 1995 and 2001 and again from 2009 onwards, finishing the period 313% above 1990 levels. 12
Figure 1.7. Industrial Energy Intensity Based on GDP in BC, 1990–2010
Sources: STC RESD; CANSIM Table 379-‐0025 — Gross Domestic Product (GDP) at basic prices, by NAICS
As noted in the methodology section 1.2, the intensity indicators provided here should be treated with caution because they are based on monetary measures of output. As such, any decreases in intensity may not be a consequence of efficiency improvement but, for example, may be due to shifts in industry structure.
12 The rather significant rise in intensity is not well understood. Further review with industry specialists is warranted.
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1.5.2 Commercial and Residential Sectors
To calculate energy intensity indicators, measures of production are necessary. However, no STC or Natural Resources Canada (NRCan) series (i.e., 1990 to present) data on production, could be found for BC’s commercial and residential sectors.13 There are GDP data associated with commercial and residential activities that can be used as a surrogate. The former BC Ministry of Energy, Mines and Petroleum Resources provided information from BC Hydro billing statistics as a single point estimation of intensity based on floor space for the commercial sector and number of housing units for the residential sector. In 2001, the energy intensity levels for the commercial sector, based on 51.94 million m2 of commercial floor space and 134 PJ consumed, was 2.58 GJ/m2.
The first Commercial and Institutional Building Energy Use Survey (CIBEUS) of 2001, providing 2000 data, showed much less floor space in the commercial sector (about 27 million m2) and lower energy use (45 PJ), resulting in a significantly lower energy intensity. CIEEDAC is investigating the definition of both floor space and energy use in this sector.
For the residential sector, energy intensity in 2001 based on 1.47 million residential units and 141 PJ consumed was 95.86 GJ/unit.
Energy use levels in these two sectors are shown in Figure 1.4 above.
1.6 Electricity Production
1.6.1 Total Primary and Secondary Production Electricity production is classified as primary or secondary. Primary electricity production is from natural sources, such as hydro, wind and solar power. Secondary electricity production is mainly from burning fuels (natural gas, oil, diesel, coal, biomass or other fuels) often to create steam in a thermal generation process.
Figure 1.8 shows that hydro electricity dominates BC’s generation system. Total electricity production fluctuated over time and, in 2010, reached a level 4.3% higher than in 1990. Between 2009 and 2010, primary electricity production decreased by 4.9%, and secondary production increased by 16%.
13 STC does have data on number of mortgages approved by month by region on existing and new homes but there are no readily available data on house numbers or area, commercial area or the like.
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Figure 1.8. Primary and Secondary Electricity Production in BC, 1990–2010
Source: STC RESD
Figure 1.9 compares the mix of fossil and biomass fuels used to generate secondary electricity in BC between 1990 and 2010. Over that period, the major changes were the increased use of “Other” fuels and the decreased use of the remaining fuels for thermal generation. “Other” includes manufactured gases, other petroleum products including refinery fuel gas, and other fuels not defined by STC. The figure indicates that natural gas share decreased considerably. In spite of the reduced share, total generation from natural gas still doubled to 3,400 GWh in 2010, rising marginally from 2009. The market share of wood-‐ and spent pulping liquor-‐fired electricity plants decreased from 42% in 1990 to 28% in 2010. Even so, total electricity from wood and spent pulping liquor (SPL) increased 28% from 2009 (indicating increased activity in the industry) and 79% from 1990. The market share of heavy and light fuel oil-‐fired (HFO, LFO) plants decreased significantly. The market share of HFO-‐fired plants was less than 0.5% and that of diesel/LFO-‐fired plants was only 1% of thermal generation in 2010.
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Figure 1.9. Electricity Generation Mix by Fossil and Biomass Fuels in BC, 1990 and 2010
Note: HFO: heavy fuel oil; LFO: light fuel oil; NG: natural gas; SPL: spent pulping liquor Source: STC RESD, supplemented by STC Electricity Power Statistics
Figure 1.10 shows annual production of electricity from these secondary sources by utilities and by industry. Generation of this type has been increasing over time in both sectors.
Figure 1.10. Generation of Secondary Electricity from Fossil and Biomass Fuels in BC, 1990 and 2010
Note: Data for 1997 were not published by STC. Source: STC RESD, supplemented by STC Electricity Power Statistics
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1.6.2 Utility and Non-utility Production
Figure 1.11 shows annual production of electricity by utilities from 1990 to 2010. During this period, utility production ranged from 74% to 82% of total grid-‐connected electricity generation in British Columbia. Fluctuations in utility production reached a peak in 200714 and then decreased in 2010 to a point 7% above 1990. Hydroelectric generation dominated BC’s utility generation mix; its share fluctuated between 87% and 98% during the study period. Total utility generation decreased 1.2% from 2009, and total hydro generation decreased by 4%.
Wind generation and independent power producers (IPPs) have increasingly contributed to the province’s electricity generation, first appearing in 2009. IPPs generated 5% of total electricity produced in the province in 2010. STC considers them part of the utility classification.
Figure 1.11. Utility Electricity Production in BC, 1990–2010
Note: Comb Turbine: combustion turbine, ICE: internal combustion engine. Source: STC CANSIM Table 127-‐0007, Electric power generation, by class of electricity producer, annual (megawatt hour)
Figure 1.12 shows that non-‐utility production fluctuated over the study period and reached its lowest level in 2001. In 2010, total non-‐utility production was 4% lower than 1990. Between 2009 and 2010, total non-‐utility generation decreased 6%. The dominance of hydroelectricity in non-‐utility generation diminished over time, from 84% in 1990 to 74% in 2010. Conventional steam plants, however, increased in share over the study period and by 2010 provided 26% of total electricity.
14 Figure 1.8 and Figure 1.10 are based on different STC publication series; data discrepancies may exist.
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Figure 1.12. Non-‐utility Electricity Production in BC, 1990–2010
Note: Comb Turbine: combustion turbine, ICE: internal combustion engine. Source: STC CANSIM Table 127-‐0007, Electric power generation, by class of electricity producer, annual (megawatt hour)
According to STC’s RESD, BC’s non-‐utility electricity generation by fossil fuels and wood fuel in 2010 was 6,090 GWh. Most of this electricity was cogenerated at industrial plants (e.g., pulp production plants) and roughly corresponds to the CIEEDAC database on cogeneration.
1.7 Greenhouse Gas Emissions, 1990–2010 This section reports on changes in fuel-‐sourced GHG emissions and GDP for BC economic sectors from 1990 to 2010. It also includes a brief discussion of population growth in relation to these changes. Appendix A contains detailed tables of the data used.
CIEEDAC compared data calculated using RESD values and the values provided by Environment Canada in their National Inventory Report (EC 2011). The values differed by an average of about 2.7% with a range of 0 to 9%.
Figure 1.13 compares BC’s population growth (millions), GDP (2002 $billions) and GHG emissions (Mt) for the period 1990 to 2010. Total energy use from which the emissions are calculated includes estimates of confidential consumption, biomass used in the Pulp and Paper sector15 and energy used to generate secondary electricity.
As noted earlier, population and GDP grew consistently over the study period. Population increased by 38%, growing annually at a rate of 1.5%, while GDP increased by 82%, with an annual growth rate of 2.9%. GHG emissions fluctuated over time, peaking in 2004 and finishing the period 21% above 1990 levels. Emissions in 2010 were 13% higher than in 2009.
15 Biomass data are used to calculate non-‐CO2 GHG emissions. CO2 emissions from biomass are not included because they are considered neutral by convention.
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Figure 1.13. Population, GDP and GHG Emissions for BC, 1990–2010
Sources: STC RESD energy data converted to GHGs with EC coefficients. (EC 2011); CANSIM Table 379-‐0025 and Table 051-‐0001
CIEEDAC used GDP and population data to calculate the GHG emission intensity indicators plotted as an index in Figure 1.14. These values are an index of the ratios of emissions generated per capita or unit of GDP and help to demonstrate changes from the base year. The indices show different rates of change. Between 1990 and 2010, the GHG emissions intensity indicator based on population decreased 12% and the indicator based on GDP decreased 25%. These data suggest that, while considerably less GHG emissions were generated per unit of value added, emissions per person did not change as much. It is difficult to speculate on the reasons for these changes as the link between energy and GHG emissions is not always straightforward. As noted earlier, issues related to the analysis of GHG emissions include the definition of process versus fuel-‐based GHG emissions, confidentiality of energy and estimated GHG data, and the estimation of indirect emissions from steam or electricity purchases.
Figure 1.14. GHG Intensity Indices for BC, 1990–2010
Sources: STC RESD; CANSIM Table 379-‐0025 and Table 051-‐0001
1.7.1 GHG Emissions by Fuel
Figure 1.15 presents GHG emissions by fuel type between 1990 and 2010. Coal emissions, although proportionally smaller than those from RPPs and natural gas, showed the greatest
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increase (596%). Coal-‐based GHG emissions stand out in that they appear to be negative. This is due to the method used to determine net supply for coal, which takes into account exports and imports as well as use. In years when exports exceed availability (e.g., shipment of previous year’s stock), the value becomes negative.16 Natural gas emissions increased 3% in that period but were 4% below 2009. RPP emissions increased 15%, with a 5% increase from 2009 to 2010.
Figure 1.15. GHG Emissions by Type of Energy in BC, 1990–2010
Source: STC RESD energy data converted to GHG emissions using EC coefficients (EC, 2011)
Figure 1.16 shows the contributions of the different types of fuels to GHG emissions in 2010, highlighting the contributions of RPPs.
16 CIEEDAC is still reviewing these negative values with STC.
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Figure 1.16. Fuel Types Contributing to GHG Emissions in BC, 2010
Note: HFO: heavy fuel oil; LFO: light fuel oil; Pet coke: petroleum coke; Ref LPG: refined liquid petroleum gas Source: STC RESD
1.7.2 GHG Emissions by Sector Figure 1.17 compares GHG emissions in BC’s major economic sectors. Most sectors displayed noticeable changes in energy use and thus in GHG emissions between 1990 and 2010. The following sectors showed relatively significant increases in GHG emissions: Electricity (24%), Transportation (44%) and Agriculture (63%). Sectors that showed appreciable decreases included Residential (15%), Commercial/Institutional (28%), and Total Industrial (30%).
Figure 1.17. GHG emissions in Major Sectors of BC, 1990–2010
Source: STC RESD energy data converted to GHG emissions using EC coefficients (EC, 2011)
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1.7.3 GHG Emissions from Electricity Generation All RESD data on energy used by utility and non-‐utility electricity generators have not yet been updated or are under review by STC. While some data have been extrapolated for overall generation, the data for 2010 (and some other years) are suspect. Because of the level of uncertainty and the current restructuring of the ICE and RESD data sets, CIEEDAC advises caution in using these data.
Figure 1.18 shows that CO2 emissions resulting from the production of electricity have fluctuated greatly over the study period. This was primarily because of changes in fossil fuel use by electricity utilities. Emissions show peaks in various years, the highest in 2001. Since 2002, levels have been fairly consistent, roughly equivalent to 1990 values. In 2009, emissions levels dropped appreciably but rose again in 2010 to a point 24% higher than 1990 levels. Although there was a 12% decrease in intensity of CO2 emissions per unit of electricity generated between 2008 to 2010, the intensity was 18% higher in 2010 than it was in 1990.
Figure 1.18. CO2 Emissions from Electricity Generation in BC, 1990–2010
Source: STC CANSIM Table 127-‐0007, Electric power generation, by class of electricity producer, annual (megawatt hour); RESD, energy consumed by fuel type converted to CO2e using EC coefficients (EC, 2011)
1.8 Conclusion and Summary In 2010, BC’s total energy use (including energy used to make secondary electricity) reached 1,070 PJ, an increase of 15% above 1990. With both GDP and population growing faster than energy use, intensity indicators based on these two measures diminished (GDP by 37% and population by 16%).
Use of most fuels in 2010 was considerably higher than in 1990. Electricity and RPPs are the major fuels of the BC economy. Use of electricity was up by 12%, and use of RPPs was 24% higher. Coal use increased the most but was an extremely small portion of total energy use. Natural gas, with a drop of 3%, was the only major fuel type to show a lower consumption in 2010 than in 1990.
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Hydroelectricity continued to dominate electricity production, although generation of thermal secondary electricity increased significantly. In 2010, secondary generation provided 16% of electricity, a greater share than in any other year since 1990. In thermal electricity generation, the market shares of HFO-‐ and diesel/LFO-‐fired sources declined significantly over the study period and the share of natural gas-‐fired plants also decreased. “Other” fuel (manufactured gases, other petroleum products and other fuels not defined in the data source) grew significantly.
Total Industrial energy use decreased 1.2% since 1990 but increased 7% from 2009. Energy use in Total Manufacturing was down 8% from 1990 but increased 5% from 2009. Relatively significant consumption increases occurred in the Residential (13%), Transportation (43%) and Agriculture (78%) sectors between 1990 and 2010.
Total GHG emissions increased steadily before 2000 and then rose and fell with a peak in 2004 at 46.8 Mt. In 2010, emissions rose to a level of 44.4 Mt, 21% above 1990 but down from the peak.
British Columbia’s major economic sectors showed different energy use patterns and therefore GHG emission trends. Transportation, Electricity and Agriculture had increasing levels of emissions compared to 1990 levels, while the Residential, Commercial/Institutional and Total Industrial sectors showed decreasing GHG emission trends. Coal showed the greatest increase in emissions, reflecting its growth in use as a fuel. Even though the increase is significant, coal plays a minor role in total emissions generation because its consumption is such a small part of total consumption in British Columbia. The bulk of GHG emissions come from RPPs, of which gasoline has the largest share. Among all the various petroleum products, natural gas, and coal, RPP combustion generates the greatest amount of CO2 in the province, about 64%.
In the future, CIEEDAC will continue to update this section with the objective of improving and refining the accuracy of the data. Thus far, our analysis has only concerned itself with highly aggregated economic sectors as the data are not available for more disaggregated analyses. This is especially true of industry, where it is clear from ICE data that further disaggregation might be possible. As with all reports published by CIEEDAC, we encourage and appreciate any feedback from our readers.
As noted at the beginning of this report, the RESD has undergone a significant update to allow it to reflect more closely the data obtained from industry using the ICE survey. These changes have altered historic trends in BC’s industrial sector and have affected data in other sectors as well. Because the process of updating the RESD is ongoing, the values as represented here should be used with caution.
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2 Cogeneration Facilities in British Columbia, 2010 CIEEDAC defines cogeneration as the simultaneous generation of electricity and useful thermal energy from a single fuel.17 Cogeneration is also referred to as combined heat and power (CHP) generation. By making use of the waste from one process in the production of the other, cogeneration realizes substantial gains in energy efficiency compared with the independent production of both products. The efficiency of cogeneration in converting primary energy into electrical and thermal energy places the technology at the forefront of many CO2 emission reduction strategies. National and international commitments to reducing CO2 emissions have increased interest in cogeneration.
The thermal energy from cogeneration can be used in heating or cooling applications. Heating applications include generation of steam or hot water. Cooling applications require the use of absorption chillers that convert heat to cooling. A range of technologies can be used to achieve cogeneration, but the system must always include a power generator (either electric power or drive power) and a heat recovery system. The heat-‐to-‐power ratio, overall efficiency and characteristics of the heat output are key attributes of cogeneration systems.
Cogeneration systems are classified by the type of prime mover used to drive the electrical generator. The five main types currently in use in Canada are steam turbines, gas turbines, reciprocating engines, microturbines and combined-‐cycle gas turbines. New systems currently under development include fuel cells and Stirling engines.
The attributes and prime movers referred to here and the information in the following sections (as well as a copy of the survey) are described in more detail in CIEEDAC’s report, A Review of Existing Cogeneration Facilities in Canada (www.cieedac.sfu.ca).
2.1 Objectives CIEEDAC’s Canadian Cogeneration Database aims to provide a comprehensive list of cogeneration projects in Canada’s provinces and present unbiased data on the performance of cogeneration systems. To date, no other comprehensive list of Canadian cogeneration projects has been identified. This task is becoming increasingly challenging as cogeneration capacity expands rapidly under deregulation. Future updates of this report will continue to refine existing data and include new additions.
This report contains the following sections: • The methodology used to identify cogeneration projects in British Columbia; • A summary of cogeneration facilities in British Columbia by sector and system average
performance characteristics; and • Conclusions.
17 A Review of Existing Cogeneration Facilities in Canada, CIEEDAC, 2012
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2.2 Methodology Since 2004, CIEEDAC has gathered data on Canadian cogeneration systems by means of a survey sent to all facilities listed in our database. Through this process, we are able to identify cogeneration systems across the country that are no longer operational, sites that were never cogeneration facilities and duplicate listings. We also gather new data on the performance characteristics of cogeneration systems operating in Canada’s provinces and territories. The resulting database has become more reliable each year. In addition, we identify new cogeneration systems through websites, industry contacts and utility personnel. Thus, the database contains data that enhances understanding of the opportunities for and limitations of cogeneration in Canada and, for this report, British Columbia.
2.2.1 Data Sources The key sources of data for this year’s update of the Canadian Cogeneration Database are the completed questionnaires received from cogeneration facilities across Canada. New cogeneration systems were identified through websites and industry contacts. Historical sources of data include: the Canadian Gas Association, EC, consultants, independent associations, electric and gas utilities, STC, corporate and government websites, cogeneration equipment manufacturers’ brochures and industry journals.
2.3 Cogeneration Results, 2010 This section summarizes the results of the current cogeneration database survey for British Columbia, which updates data to 2010. Table 2.1 presents BC’s known cogeneration capacity from 2000 to 2010 and compares BC’s share in Canada. In 2010, the total electrical cogeneration capacity in British Columbia dropped to 1,018 MWe, 16% of Canada total. This was due to the closing of a number of paper mills. BC’s thermal capacity was 4,848 MWt, about 24% of Canada’s total. Despite the drop in electrical capacity, BC still had the third largest electrical and thermal cogeneration capacity in Canada, after Alberta and Ontario.
Note that not all survey respondents provided all information. As a result, thermal capacities for both BC and Canada are deemed to be underestimated.
Table 2.1. Cogeneration Capacity in BC, 2000–2010
Region 2000 2001 2002 2004 2005 2006 2007 2008 2009 2010
Electrical Capacity (MWe) British Columbia 1,373 1,408 1,408 1,408 1,408 1,468 1,468 1,468 1,468 1,018 Canada 4,525 5,267 6,352 6,743 6,789 6,936 7,007 7,007 7,007 6,553 % BC of Total 30.3 26.7 22.2 20.9 20.7 21.2 21.0 21.0 21.0 15.5
Thermal Capacity (MWt) British Columbia 4,156 4,433 4,433 4,433 4,433 4,433 4,433 4,433 4,433 4,848 Canada 27,200 27,846 28,937 29,063 29,127 29,159 29,473 29,473 29,473 20,056 % BC of Total 15.3 15.9 15.3 15.3 15.2 15.2 15.0 15.0 15.0 24.2
Source: Canadian Cogeneration Database, CIEEDAC. Current values for all components are still under review.
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2.3.1 Sector Results In Figure 2.1, cogeneration capacity is allocated according to system operator/thermal host. The facilities are coded using the NAICS system. At least one facility in BC provides district energy as a result of its cogeneration activity — Metro Vancouver’s water treatment facility on Iona Island is listed as providing this service.
Figure 2.1. Cogeneration Capacity by System Operator/Thermal Host in BC, 2010
Source: Canadian Cogeneration Database, 2010, CIEEDAC
2.3.2 Cogeneration System Performance Characteristics The data presented in Table 2.2 are from the most recent cogeneration database and are based on data from 22 sites. We have data on average annual electricity generation from 16 sites, data on heat rate18 from 9 sites and data on heat-‐to-‐power ratio from 15 sites. The data on heat rate were not found to be reliable and are under review. Forthcoming editions of this report may contain more data on heat rate.
Table 2.2 displays the average performance characteristics of cogeneration systems currently in operation in British Columbia. The average amount of electricity generated per kWe of installed capacity is 5,098 kWh/kW/y. The highest rate of electricity production occurs in the Utilities sector. These levels of output give an indication of capacity utilization of cogeneration systems in the various sectors.
18 In this study, heat rate is defined as the energy content of fuel used in kilojoules (KJ), divided by the sum of the electricity output in kWh and the thermal output in kWh.
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Table 2.2. Cogeneration System Performance Characteristics in BC, 2010
Sector Electricity Generation (kWh/kW per year)
Average Efficiency Heat-‐to-‐Power Ratio
Oil and Gas Extraction 0 0.0% 0.0 Utilities 5,862 48.1% 0.3 Food Manufacturing 1,333 n/a 4.4 Wood Products Manufacturing 4,785 51.2% 5.4 Pulp and Paper Manufacturing 5,681 61.3% 7.6 Waste Management and Remediation Services 3,210 n/a 1.0 Average 5,098 57.4% 6.0
Source: Canadian Cogeneration Database, CIEEDAC
The average heat-‐to-‐power ratio of systems operating in BC is 6.0. This means that for every kWh of electricity that could be produced by cogeneration systems, 6 kWh of useful thermal energy would be produced (i.e., these are not based on actual production figures but on system design). Table 2.2 shows that the Pulp and Paper Manufacturing sector has the highest average heat-‐to-‐power ratio of all sectors. The Wood Products Manufacturing sector has the second highest ratio. These industries demand high quality thermal energy, leaving less energy available to produce electricity. The Utilities and Food Manufacturing sectors have low heat-‐to-‐power ratios. Utilities have low heat-‐to-‐power ratios because their systems are designed to maximize electrical output.
Table 2.3 presents known and estimated annual cogenerated electricity generation by sector. The values shown for known electricity generation include only those data reported by system operators. Using these data, CIEEDAC derived an average capacity utilization factor. Applying this factor, we estimated the electricity generation for all cogenerators. Total electricity generation in 2010 in BC was 63,637 GWh, of which 12,429 GWh was non-‐utility. The bulk of this (9,000 GWh) was from hydro. The remainder, roughly 3,500 GWh, can be accounted for in cogeneration by the industries other than Utilities in Table 2.3.
Table 2.3. Cogenerated Electricity Generation in BC, 2010
Sector Known Electricity Generation (MWh/year)
Estimated Electricity Generation (MWh/year)
Oil and Gas Extraction 0 601,565 Utilities 1,700,000 1,745,882 Food Manufacturing 4,000 4,000 Wood Products Manufacturing 234,592 234,592 Pulp and Paper Manufacturing 2,608,388 2,949,954 Waste Management and Remediation Services 13,000 53,274 British Columbia 4,559,980 5,589,267
Source: Canadian Cogeneration Database, 2010, CIEEDAC
2.4 Conclusion and Summary CIEEDAC defines cogeneration as the simultaneous production of electrical and useful thermal energy from a single fuel. By making use of the waste from one process in the production of the other, substantial gains in energy efficiency can be realized compared with the independent production of both products. The thermal energy can be used in heating or cooling applications.
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A range of technologies can be used to achieve cogeneration, but the system must always include a power generator (either electric power or drive power) and a heat recovery system.
CIEEDAC has completed seven annual reviews of cogeneration in Canada. The database contains information on 6,553 MWe of cogeneration capacity in Canada.
Currently, British Columbia has the third largest electrical cogeneration capacity, 1,018 MWe, after Alberta and Ontario. British Columbia accounts for 16% of total electrical cogeneration capacity in Canada. When classified by system operator, the Pulp and Paper Manufacturing sector has the most cogeneration, 545 MWe, or almost 54% of total operational capacity in British Columbia. The Utilities sector has the next highest cogeneration capacity of 299 MWe, which represents about 29% of capacity.
Because not all survey respondents provided information on thermal capacity, our estimates of thermal capacity for both BC and Canada are likely too low. According to the data collected, British Columbia has at least 4,848 MWt, about 24% of Canada’s total of 20,000 MWt.
CIEEDAC will continue to track and update this database with the objective of improving and refining the accuracy of the data. Given sufficient funding, a revised report will be released annually. We encourage and appreciate any feedback from our readers.
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3 Renewable Energy in British Columbia CIEEDAC normally surveys renewable energy facilities for their data but was able to complete this task for 2010 due to lack of funding. Therefore the discussion in this section has not been updated to include data for 2010; the most recent data are for 2009.
Renewable energy resources are derived from naturally regenerating energy resources such as the sun, wind, moving water, earth energy and biomass (i.e., hog fuel, wood waste, black liquor, etc.). The majority of renewable energy forms are ultimately derived from the sun with the exception of geothermal and tidal energy.19
These resources can be used for electricity generation, heating and cooling services, and other purposes. Both low and high temperature thermal energy can be produced, depending on the resource. Some technologies can be used for cogeneration. In addition, renewable power can be used in water electrolysis technologies to generate hydrogen that would be used as a mobile (i.e., transportation) or stationary fuel through fuel cells or direct combustion. Renewable energy resources can also be used to produce liquid bio-‐fuels such as ethanol or biodiesel, both of which can serve as mobile or stationary fuels.
3.1 Objectives This section of the report considers renewable resources and technologies used for power generation or cogeneration, heating systems, hydrogen generation and transportation fuels.
The purpose of this part of the report is to:
• provide a comprehensive database of renewable energy facilities in British Columbia. • provide summary information on the mix of renewables by resource/technology type, scale
(capacity and annual generation), owner/operator, green certification status and vintage.
3.2 Background on Renewable Energy Technologies Renewable energy technologies convert naturally regenerating resources into useful energy “currencies” such as electricity, thermal energy, hydrogen or bio-‐fuels. These currencies can then be used to produce energy services. This section provides an overview of renewable power generating technologies.
These renewable energy technologies are found at a variety of scales, from a household level for supplying a proportion of a household load to power plants that can supply a large proportion of an electrical grid’s power.
Several renewable energy technologies are technically mature and have been extensively commercialized, having been used in industrial and pre-‐industrial societies for hundreds of years. Many Canadian electricity companies started with hydroelectricity plants at the turn of the 20th century, generating electricity from moving water in rivers. Some other technologies,
19 Tides are somewhat associated with the sun in that they are the result of an interaction between solar and lunar gravity.
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such as those capturing tidal or wave energy, are in early stages of commercialization with cost levels being higher than competing sources of energy.
3.2.1 Hydroelectricity Hydroelectric technologies generate electricity from moving water through a turbine and generator to produce power. The water may be flowing in a river or stream or may be transferred through a pipeline from a lake to a lower elevation. The water upstream of the project could be free flowing (i.e., run-‐of-‐river hydro) or stored behind a dam in a reservoir (i.e., storage hydro) to permit flexibility to meet varying electrical loads. Hydroelectricity projects are located in areas where large volumes of water are available, in mountainous areas or where there is abundant rainfall. Storage hydroelectricity facilities are fully dispatchable, meaning that they can provide power consistently for 8,760 hours of the year, following loads with great precision if the reservoir is large enough and full enough. Run-‐of-‐river facilities, where water is used at a rate no greater than the river’s flow, are also dispatchable at times of year when water flows are sufficient. In our report, we have distinguished between large hydro (greater than 50 MW) and small hydro.
3.2.2 Wind Power Wind power is the generation of electricity from the kinetic energy of winds. Wind passes through turbine blades that turn a shaft connected to an electricity generator. Wind energy facilities are common in areas with consistent winds with high average wind speeds or areas with substantial gusts of wind on a predictable basis. These facilities tend to be located in coastal areas, at high elevations or in valleys or plains near mountainous areas. Wind power facilities are not readily dispatchable, although their output is often predictable based on daily wind patterns. They require back up through electrical grids with dispatchable supplies online or energy storage devices such as batteries.
3.2.3 Biomass and Biogas Biomass energy is derived from the combustion of organic matter such as the waste products in a forestry operation or other plant matter. Biomass can be combusted in a boiler to produce steam for turbines to produce power. In cogeneration applications, the residual heat (thermal energy) is used as energy for other end-‐uses, such as heating buildings. Biomass power generation is primarily connected to the Pulp and Paper Manufacturing and Wood Products Manufacturing sectors through the combustion of wood residue products from those industries. Biomass power plants are fully dispatchable provided that wood resources are available, although there is a lagged start up time (the start up is not “instant” as it is with hydro power). Burning biomass may cause air pollution, but technologies can be used to minimize particulate matter release.
Biogas energy is derived from biomass but is combusted as a gas composed primarily of methane, also the most common constituent of natural gas. Biogas is commonly generated from biomass waste products at sewage treatment plants and solid waste landfills and through forest sector activities and agricultural operations. Biogas can be produced through a biological process that “digests” the biomass in a chamber with no oxygen, through a chemical process or through heating in the absence of oxygen (destructive distillation). The biomass products are
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converted to a gaseous fuel. This biogas is then combusted in a boiler to produce steam for power generation through a steam turbine or through a combustion turbine directly. In both instances, under cogeneration applications, the residual heat is used as energy for other applications (thermal energy). Biogas generators are fully dispatchable provided that resources are available.
3.2.4 Solar Photovoltaic Solar photovoltaic (PV) technologies use semiconductor devices to generate electricity directly from solar radiation. They produce direct current electricity that can be converted to alternating current through inverters. Solar PV is used throughout Canada on many different types of buildings. Solar modules are installed as attachments on rooftops or through building-‐integrated configurations. Solar electricity is available only during daylight hours and is reduced under cloudy conditions so it is not dispatchable. Thus solar PV modules require a connection to an electrical grid with dispatchable supplies online or energy storage devices such as batteries to back them up.
3.2.5 Geothermal and Earth Energy The earth is naturally heated by the decay of radioactive elements in its mantle. Geothermal energy and earth energy make use of this heat source. CIEEDAC’s renewable database uses “geothermal” to define operations that use steam or hot water in the earth’s crust (either from drilled wells or natural fissures) to power turbines that generate electricity. This is only possible where there is a high temperature gradient, generally in areas with recent volcanic activity such as the BC coast. “Earth energy” installations, on the other hand, use the earth for direct heating (such as for hot water or space heating) or cooling. A medium or low temperature gradient is adequate for earth energy.
3.2.6 Others Other renewable technologies and resources are not currently used commercially in British Columbia or are not included in the database. Many exist or are under development in BC or elsewhere in Canada. These include:
• Tidal energy: Use of moving seawater to generate electricity. Tidal energy is abundant in coastal areas, particularly on the BC coast when there are narrow passages with large volumes of water.
• Wave power: Conversion of the kinetic energy of ocean waves into electricity.
• Solar thermal: Use of the sun’s energy to heat water or air directly. This technology is well established. There are installations in BC but these are not yet recorded in the renewables database.
• Biodiesel fuel: A fuel derived from renewable sources such as vegetable oil. Biodiesel has been sold in BC since 2005; it is typically blended with regular diesel. The source of the biodiesel is waste vegetable oil from food preparation facilities such as restaurants; CIEEDAC has no records of commercial production of biodiesel from oil crops such as canola.
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• Ethanol fuel: An alcohol fuel that can be mixed with or used instead of gasoline. It is made by distilling fermented sugars derived from biomass sources such as corn or wheat.
• Hydrogen fuels and fuel cell systems: Hydrogen fuel is only renewable when the electricity used for electrolysis to produce the hydrogen is from a renewable source. Renewable hydrogen generation is being proposed at several locations in Canada and is currently being tested in British Columbia by BC Transit, using hydrogen-‐fuelled buses.
Certain types of renewable energy technologies that produce few environmental and social impacts are often categorized as “green energy” sources. These supplies are being used to meet regulatory requirements connected with environmental policy goals or sold to consumers as a premium product for a higher price than conventional energy supplies. Green energy is typically defined through facility certification standards such as those applied by the federal government-‐sanctioned Environmental Choice Eco-‐Logo Program,20 BC Hydro21 and the Canadian Electricity Association.22 In British Columbia, “clean energy” is defined in a set of guidelines entitled BC Clean Electricity Guidelines, published in 2005 and available from the BC Ministry of Energy and Mines.
3.3 Methodology This section provides an overview of the methodology used for the development of the data on BC’s renewable energy. The BC data are part of a larger database containing information on renewable energy facilities throughout Canada. This database aims to bring together information on all renewable power operations in Canada over a scale of 100 kW of rated capacity. In the case of run-‐of-‐river hydro and earth, wind and solar power, smaller applications have also been included, provided they are connected to a regional or community electrical grid or an industrial load. In 2009, there were 1,228 records for renewable energy facilities in Canada, 191 of which were in British Columbia.
The following information is provided in the database for each facility: renewable resource type (e.g., wind, hydro, biomass); capacity (electrical, thermal, litre production, etc.); number of generating/production units; average annual electricity or thermal heat generation if applicable; start year and capacity upgrades; grid connection; green certification status; conversion technology; market; installation and operating costs; employment; annual revenue; government incentives used; tax payments; and responses to questions on energy policy.
3.3.1 Data Sources The original data were collected from a number of sources, including the following:
20 See http://terrachoice.com and the “Renewable Low-‐Impact Electricity” label 21 BC Hydro Green Criteria. See http://www.bchydro.com/energy_in_bc/energy_technologies.html 22 CEA’s Environmentally Preferable Electricity Portfolio certification system is based on the methodology developed by Scientific Certification Systems (SCS), based in Oakland, California.
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• Renewable energy industry association publications and statistics (i.e., Canadian Wind Energy Association, Canadian Hydropower Association, Canadian Bioenergy Association, Independent Power Producers of Ontario);
• Renewable energy publications from government and institutional sources; • STC report, Electric Power Generating Stations: 2000 (Catalogue No. 57-‐206-‐XIB), which
provided by far the bulk of the initial data on specific sites; • Communications with and materials from power plant owners and developers; • Electrical utility and retailer information sources; and • The authors’ personal knowledge of power plants in Canada.
The survey is conducted online at CIEEDAC’s website. The information automatically enters into a Microsoft Access database. A report generator prints the database information in the tables that appear in Appendix C of this report.
The database has several limitations and sources of error, including the following:
• Despite efforts to make the database comprehensive, it may be missing several power plants. In particular, hydroelectricity, biomass, and biogas plants built after the year 2000 may not be present, given that the STC source included information only up to that year and the industry associations for those sources of energy do not publish a power plant listing. In contrast, the Canadian Wind Energy Association has an up-‐to-‐date list of wind generation facilities in Canada and the STC releases data annually on wind and solar power plants (by special request).
• Distributed energy sources such as solar photovoltaics, solar thermal and geothermal are by nature small and difficult to track. The database currently does not accurately reflect their contribution to renewable energy generation in British Columbia. In the future, efforts will be made to obtain records from those selling and installing these systems.
• Annual electricity generation data are incomplete, as many companies chose not to reveal this information. The response rate will likely improve as a level of trust is built with survey respondents.
• For those biomass and biogas facilities that mix renewable fuels (e.g., spent pulping liquor) with non-‐renewable fuels (e.g., natural gas), renewable capacity and annual generation were calculated by simply multiplying the total energy or power by the proportion of renewable fuel. For example, a 10 MW total capacity with 60% of the combusted fuel from renewable spent pulping liquor and 40% from natural gas would be recorded as 6 MW of renewable capacity. This simplification disregards differences in boiler types and efficiencies and any interdependencies between the fuel sources.
The tables and figures in the remainder of this section are generated directly from the data contained in the CIEEDAC Renewable Energy Database as described above.
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3.4 Renewable Energy in British Columbia, 1990–2009 Because funding was limited this year, CIEEDAC could not perform its usual survey of renewable energy generation. The data, therefore, are only up to 2009.
3.4.1 Capacity BC currently has an installed renewable capacity to produce electricity and heat of 14.2 GW. About 90% of renewable energy capacity was electrical capacity with the remainder being thermal capacity (10%). Although we also collect information on generators of renewable liquid fuels such as ethanol and biodiesel, the database does not list any for British Columbia. Figure 3.1 below divides renewable energy capacity by resource types. The figure shows that hydroelectricity dominates BC’s renewable energy power market, with large hydro contributing about 83% of BC’s renewable energy power capacity and small hydro contributing about 4.1%. About 12% of renewable energy power capacity is derived from biomass wood residue sources (both electrical and thermal), and about 1% is from biogas, municipal solid waste and solar (both electrical and thermal). Renewable energy sources provide about 85% of BC’s total installed electrical capacity (non-‐renewable and renewable) of 15.2 GW.
Figure 3.1. Total Renewable Energy Capacity (kW) by Resource Type, BC, 2009
Source: CIEEDAC Renewable Energy Database, 2010
It is worthwhile to look more carefully at those resources considered lower impact. Figure 3.2 illustrates the capacity share of the different resources with large hydroelectric facilities excluded. We note that there are also small-‐scale facilities using earth energy and landfill gas about which we have no information on capacity levels. They are assumed to make up a very small proportion of renewable energy capacity.
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Figure 3.2. Total Renewable Energy Capacity (kW) by Resource Type, Excluding Large Hydro, BC, 2009
Source: CIEEDAC Renewable Energy Database, 2010
Figure 3.3 illustrates the total quantity of new electrical generating capacity added in British Columbia during each decade of the last century, broken down by renewable resource type. Each decade up to the 1970s saw increasing levels of capacity expansion (except during the 1920s). Since then, capacity additions have dropped off dramatically. Since 1991, new capacity has come primarily from sources such as biomass and small hydro.
Figure 3.3. New Renewable Energy Capacity by Project Start Year, BC
Source: CIEEDAC Renewable Energy Database, 2010
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It should be noted that the composite chart of Figure 3.3 includes only one entry for each power plant based on the original year of operation. It therefore allocates upgraded capacity to the start year. Nevertheless, it provides us with a useful overview of installation activity.
Figure 3.4 presents the number of facilities built rather than their capacity. It highlights recent efforts to add lower impact energy facilities. The “Other” category consists primarily of solar and earth energy installations. Many of these new facilities are small; it indicates a move toward increasingly distributed generation.
Figure 3.4. Number of Renewable Energy Facilities Installed by Project Start Year, BC
Source: CIEEDAC Renewable Energy Database, 2010
3.4.2 Annual Generation of Energy The survey asked facility operators to report their annual energy generation. The sums of these figures are listed in the first column of Table 3.1 below (in GWh). However, some facilities reported only their rated capacity and not their annual energy generation. Thus, data from 39.5% of the facilities in the database that provide information on both their rated capacity and annual energy generation are used to calculate capacity factors for each renewable resource type. These capacity factors are then applied to all of the facilities in the database that have reported their capacity to generate the second column in Table 3.1.
The 2009 renewable energy survey for British Columbia revealed that at least 19% of the energy produced in the province was from renewable resources and estimates show it could have been as high as 21%.23
The associated quantities of GHG emissions avoided are also listed in Table 3.1 (in CO2 equivalent). These calculations assume that the alternative to renewable electricity generation 23 Based on 2009 renewable energy generation and 2009 total primary energy production for BC from STC’s Report on Energy Supply and Demand taken from CANSIM.
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would be combined-‐cycle gas turbines and that the alternative to burning wood residue for thermal energy would be burning natural gas in a boiler. As the estimated figures below might deviate significantly from real energy generation and GHG emissions avoided in 2009, they should be cited with caution.
Table 3.1. Annual Renewable Energy Generation (GWh) and Avoided Greenhouse Gas Emissions (1000 tonnes CO2 equivalent), BC, 2009
Fuel Type Known Energy
Generation
Estimated Energy
Generation
Potential Total Energy Generation
Confirmed GHG
Emissions Avoided
Estimated GHG
Emissions Avoided
Potential Total GHG Emissions Avoided
Biogas 16 89 105 3 29 33 Biomass 4,997 1,980 6,976 1,415 636 2,051 Large Hydro 60,090 2,022 62,112 26,440 890 27,329 Small Hydro 3,058 137 3,195 1,345 60 1,406 Solar 0 0 0 0 0 0 Other 1 43 44 1 19 19 Total 68,161 4,271 72,432 29,204 1,634 30,838
Source: CIEEDAC Renewable Energy Database, 2010
Due to the high proportion of renewable electricity generation, British Columbia emitted only 1.45 Mt of CO2 from the production of electricity in 2009. If these renewable energy facilities were replaced with combined-‐cycle gas turbines, CO2 emissions from electricity would be as high as 29.3 Mt.24
3.4.3 Capacity Utilization By obtaining both capacity and annual generation data, we were able to estimate the average capacity utilization of each resource type, presented in Figure 3.5. Capacity utilization represents annual generation as a percentage of what could be generated if the plant ran constantly. Barriers to obtaining 100% capacity utilization could include an inconsistent supply of fuel (biomass), sunlight (solar) or water (hydro); planned downtime for maintenance; mechanical failure; and/or a lack of demand during non-‐peak hours.
24 Assume greenhouse emissions intensity for marginal electricity production is 0.44 t CO2e/MWh
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Figure 3.5. Capacity Utilization by Resource Type, BC, 2009
Source: CIEEDAC Renewable Energy Database, 2010
3.4.4 Characteristics of Electricity Generators Figure 3.6 shows the breakdown of renewable electrical capacity by resource type. Hydroelectricity dominates BC’s renewable energy generation market, with 92.3% from large hydro facilities and 4.6% from small hydro facilities. The average facility capacities are 62 MW for large hydro and 3 MW for small hydro. Large hydro is the province’s largest producer of renewable electricity.
Hydroelectricity can also be broken into hydro storage, hydro run-‐of-‐river and hydro other. The dominant form of hydroelectricity is hydro storage, with a total capacity of 10.7 GW and an average facility capacity of 56.5 MW. Run-‐of-‐river is the second most common type of hydroelectricity in BC, with a total capacity of 1.2 GW and an average facility capacity of 6.7 MW. There are 62 hydro facilities, including 32 hydro storage facilities, in our database, which represent about 97% of installed renewable electrical capacity in British Columbia.
Figure 3.6. Renewable Electrical Capacity (kW) by Resource Type, BC, 2009
Source: CIEEDAC Renewable Energy Database, 2010.
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Figure 3.7 illustrates the electrical capacity share when excluding large hydro facilities.
Nine of the 62 hydro facilities in our database are certified “green” by BC Hydro or the Environmental Choice EcoLogo program.
Although solar photovoltaics are shown here to represent a miniscule share of electrical capacity, this technology is likely underrepresented in our database due to the difficulty of tracking down facilities for such a distributed energy source. Of the 10 installations listed, one is owned by a diversified electricity generator, one by a renewable electricity generator, one by a telecommunications firm, one by an academic research facility and one by a private homeowner. None of them sell electricity to the grid. Eight of them were installed in the last five years.
Figure 3.7. Renewable Electrical Capacity (kW) by Resource Type, Excluding Standard Hydro and Standard Hydro Storage, BC, 2009
Source: CIEEDAC Renewable Energy Database, 2010
3.4.5 Characteristics of Thermal Energy Generators In 2009, 59 facilities reported production of renewable thermal energy, with a total capacity of 1,422 MW. Of this total thermal capacity, 91.5% was derived from wood waste in Pulp and Paper and Wood Products Manufacturing establishments. The remainder came from landfill gas used by the utilities (7.7%) and earth energy (0.8%).
Nine thermal energy producers also reported generating their own electricity but only five facilities reported selling electricity to the grid. Five of the nine thermal energy producers reported that they purchased electricity from the grid. In general, these facilities produced a relatively small amount of electricity compared to thermal energy, with an average of only 13 kW of electrical capacity per 100 kW of installed thermal capacity with a total installed electrical capacity of 163 MW.
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There are 52 earth energy facilities listed in the database. Of these facilities, 32 have an average capacity of 337 kW, comprising a total of 10.7 MW. The largest facility is 2,321 kW and the smallest is 18 kW.
3.5 Comparison with the Rest of Canada Table 3.2 below illustrates Canada’s renewable electrical capacity and total electrical capacity in kilowatts in place in 2005 by province (data not available for thermal capacity).25 Quebec had 49% of Canada’s renewable power capacity, while British Columbia had about 17%.
Table 3.2 illustrates the percentage of total provincial and territorial installed capacity that is provided by renewable energy. Quebec had the highest proportion at 95%. BC ranked fourth at 88%, after Québec, Newfoundland and Labrador, and Manitoba.
Table 3.2. Capacity and Percentage of Provincial Supply from Renewable Energy, 2005
Fuel Type Total Renewable Electrical Capacity (kW)
Total Installed Electrical Capacity (kW)
% of Provincial Electrical Capacity
% of Canadian Renewable Electrical Capacity
Alberta 1,405,099 11,396,860 12% 1.9% British Columbia 12,794,488 14,558,909 88% 17.4% Manitoba 5,014,623 5,532,173 91% 6.8% New Brunswick 1,072,762 4,433,208 24% 1.5% Newfoundland & Labrador 6,961,710 7,494,309 93% 9.5% Nova Scotia 541,830 2,413,235 22% 0.7% Nunavut & Northwest Territories 59,253 198,466 30% 0.1% Ontario 8,520,514 32,930,188 26% 11.6% Prince Edward Island 16,280 121,110 13% 0.0% Québec 35,916,670 37,768,726 95% 49.0% Saskatchewan 943,705 3,796,920 25% 1.3% Yukon 77,815 122,260 64% 0.1% Total 73,324,749 120,766,364 60.7% 100%
Source: CIEEDAC Renewable Energy Database, 2010; STC “Electric Power Generation, Transmission, and Distribution,” special distribution to CIEEDAC from STC
3.6 Conclusion and Summary Renewable energy resources could provide a significant amount of energy, contributing to goals of energy sustainability. With concerns about climate change, interest in this area has expanded, especially in terms of the smaller, more distributed generation sites (e.g., installations of less than 500 kW). CIEEDAC believes that focusing on this area now will be important in future assessments of energy utilization.
Renewable energy was estimated to provide between 19% and 21% of energy produced in British Columbia in 2009. The installed renewable electricity facilities represent almost 90% of
25 Based on 2005 renewable electrical capacity and 2004 total installed electrical capacity.
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the province’s total electricity capacity in that same year. The installed renewable electrical capacity of 12.77 GW is dominated by hydroelectricity at 96.6% and cogeneration from biomass wood residue at 3.1%, with biogas and solar photovoltaic sources accounting for about 0.1% of BC’s installed capacity.
Capacity was rapidly added throughout the 20th century, but after 1970, new installations dropped off dramatically. Since the 1990s the focus has been on lower impact, smaller scale operations. Capacity utilization is highest among biomass thermal operations, followed by biogas thermal generation and biomass electricity generation.
BC electricity generation emitted only 1.45 Mt of GHGs (CO2e) in 2009 due to the high percentage of renewable sources. If these were replaced with combined-‐cycle gas turbines, GHG emissions from electricity would be as high as 23.8 million tonnes of GHGs.
In terms of the proportion of installed electrical capacity that is renewable, British Columbia ranked fourth after Quebec, Newfoundland and Labrador, and Manitoba.
4 Bibliography Canadian Electricity Association and Natural Resources Canada. 2000. Electric Power in Canada
1998–99. Minister of Public Works and Government Services Canada.
Canadian Electricity Association (CEA). 1997. Climate Change and Electricity Sector Emissions. Ottawa, ON: CEA.
Canadian Gas Association (CGA). 1996. Canadian Gas Fired Co-‐Generation Data Base — Systems in Operation. December 31, 1995.
Canadian Geothermal Energy Association. No date. What is Geothermal Energy? Available from http://www.cangea.ca/what-‐is-‐geothermal/
Canadian Wind Energy Association. No date. http://www.canwea.ca/
CIEEDAC. 1993. An assessment of data on output for industrial sub-‐sectors. Prepared for the Canadian Industry Program for Energy Conservation. Prepared by J. Nyboer, A. Bailie, CIEEDAC.
CIEEDAC. 1994. Industrial energy data collection in Canada: Existing system and proposed future development. Prepared for Natural Resources Canada. Prepared by J. Nyboer, A. Bailie, CIEEDAC and P. S. Sandhu, P. Willis, Willis Energy Services Ltd.
CIEEDAC. 2012a. A review of existing cogeneration facilities in Canada. Prepared for the Canadian Industry Energy End-‐use Data and Analysis Centre. Prepared by J. Nyboer.
CIEEDAC. 2012b. Development of energy intensity indicators in industry: 1990–2010. Burnaby, BC: Simon Fraser University.
CIEEDAC. 2012c. Greenhouse Gas intensity indicators in industry: 1990–2010. Burnaby, BC: Simon Fraser University, Burnaby.
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CIEEDAC. 2012d. A Review of Energy Consumption and Production Data: Canadian Electricity Generation Industry 1990 to 2010. Burnaby, BC: Simon Fraser University.
Energy and Geoscience Institute. 2002. Geothermal energy. Salt Lake City: University of Utah.
Environment Canada. 2011. National Inventory Report, 1990–2009 — Greenhouse Gas Sources and Sinks in Canada. Ottawa: EC.
The European Association for the Promotion of Cogeneration. 2001. A guide to cogeneration. Belgium: EAPC.
Jaques, A.P., F. Neitzert, and P. Boileau. 1997. Trends in Canada’s greenhouse gas emissions 1990-‐1995. Ottawa: Environment Canada.
Klein, M. 2002. Database of Canadian gas turbine cogeneration and GTCC Installations. Ottawa: Environment Canada.
Natural Resources Canada. 2001. Canada’s Emissions Outlook: 1997–2020. Ottawa: Natural Resources Canada.
Phylipsen, G., K. Blok, and E. Worrell. 1996. Handbook on international comparisons of energy efficiency in the manufacturing industry. Department of Science, Technology and Society, Utrecht University.
Pulp and Paper Canada. 2012. Pulp and Paper Canada Annual Mill Directory. Available at http://www.pulpandpapercanada.com/
Statistics Canada. [various years]. Report on energy supply and demand in Canada. No. 57-‐003-‐XPB, Ottawa, Ontario.
Statistics Canada. 1990–2006. Electric power generation, transmission and distribution. No. 57-‐202 XIB, Ottawa, Ontario.
Statistics Canada. 1990–2010a. Table 127-‐0001. Electric power statistics, monthly (Megawatt hour). CANSIM series (database).
Statistics Canada. 1990-‐2010b. Table 128-‐0009. Supply and demand of primary and secondary energy in terajoules, annual. CANSIM (database).
Statistics Canada. 1990–2010c. Table 379-‐0025. Gross domestic product (GDP) at basic prices, by North American Industry Classification System (NAICS). CANSIM series (database).
Statistics Canada. 2011. Electric power generating stations, 2009. No. 57-‐206-‐XPB, Ottawa, Ontario.
UNESCAP. 2000. Part 1: Overview of cogeneration and its status in Asia, in Guidebook on Cogeneration as a Means of Pollution Control and Energy Efficiency in Asia. Available at http://www.unescap.org/publications/detail.asp?id=759.
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List of Appendices
Appendix A: Energy Use Data Tables, 1990–2010
Appendix B: Cogeneration in British Columbia, 2010
NOTE: Data updating and review are not complete; data reflect previous assessments and do not reflect current systems.
Appendix C: Renewable Energy Facilities in British Columbia, 2010
NOTE: Data updating and review are not complete; data reflect previous assessments and do not reflect current systems.
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Appendix A: Energy Use Data Tables
Table 1. Total Energy Use by Major Sector in British Columbia (PJ)
1990 2000 2001 2002 2003 2004 2005 2006 2007 2008 2009 2010
Total Energy Used 931 1,184 1,163 1,114 1,102 1,155 1,147 1,127 1,150 1,089 1,043 1,071
Total Industrial 409 491 458 440 443 472 473 458 449 384 379 404
Transportation 254 348 344 336 340 352 335 325 341 340 348 362
Agriculture 10 16.2 18.1 14.5 13.7 13.4 11.2 11.5 13.4 12.7 11.8 18.0
Residential 121 143 141 142 136 138 145 147 163 152 153 136
Comm., Instit. & Public Admin 116 122 120 147 131 140 142 142 145 152 106 105
Electric Power Generation 21 44 60 23 26 29 29 31 26 35 33 35
Note: “Total Energy Used” includes all hidden and confidential values, as well as total energy used to make secondary electricity. Source: STC RESD
Table 2. Industrial Energy Use by Industry Sub-sector in British Columbia (PJ)
1990 2000 2001 2002 2003 2004 2005 2006 2007 2008 2009 2010
Total Industrial 409 491 458 440 443 472 473 458 449 384 379 404
Total Mining, Oil & Gas Extraction 29.5 28.8 26.7 25.6 23.3 28.0 26.9 37.2 43.4 43.0 41.4 56.6
Total Manufacturing 367 451 419 401 406 429 432 405 389 325 325 338
Pulp and Paper 276 317 282 274 268 294 292 311 292 236 244 256
Smelting and Refining X X X X X X X X X X X X
Cement X X X X X X X X X X X X
Petroleum Refining 23.4 X X X X X X X X X X X
Chemical Manufacturing 15.2 12.7 7.9 8.7 8.9 7.8 8.5 10.0 8.1 7.7 6.9 6.4
Other Manufacturing 35.3 81.2 95.5 82.9 90.8 86.1 91.1 46.8 51.4 38.7 37.9 40.2
Forestry 3.0 5.5 7.8 7.6 7.2 7.6 7.2 8.6 8.0 7.1 6.0 10.2
Construction 9.8 5.7 5.1 5.8 6.5 6.9 7.0 458 449 384 379 404
Note: “Total Manufacturing” includes the confidential and hidden values of the Smelting and Refining and Cement sub-sectors; Pulp and Paper consumption includes biomass fuels (spent pulping liquor and solid wood waste). Source: STC RESD
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Table 3. Energy Used to Make Secondary Electricity (TJ)
1990 2000 2001 2002 2003 2004 2005 2006 2007 2008 2009 2010
Coal 0 0 0 0 0 0 42 23 15 0 0 0
Natural Gas 16,589 42,857 58,251 22,382 24,968 27,377 28,045 30,600 25,614 33,789 31,908 33,620
Petroleum Products 4,491 1,183 1,467 805 1,114 1,326 729 314 578 734 879 965
Diesel Fuel Oil 2,209 663 724 563 613 506 440 295 567 647 812 617
Light Fuel Oil 0 27 3.88 0 0 0 3.88 0 0 0 0 0
Heavy Fuel Oil 2,283 493 740 242 502 820 285 19 11 87 67 348
Total 21,080 44,039 59,718 23,187 26,082 28,703 28,816 30,937 26,207 34,524 32,787 34,585
Secondary Electricity Generated* 13,340 30,515 34,564 23,245 23,234 26,376 26,808 26,461 27,155 26,543 30,940 35,853
*Note: This electricity includes that generated from biomass but data on quantity of biomass used to make electricity are not available. Source: STC RESD
Table 4. Energy Used to Make Steam (TJ)
1990 2000 2001 2002 2003 2004 2005 2006 2007 2008 2009 2010
Coal - 289 188 36 36 7,537 187 187 395 388 288 108
Natural Gas - 207 353 5 11 20 8 13 - 4 - -
Total - 496 541 41 47 7557 195 200 395 392 288 108
Source: STC RESD
Table 5. Population, GDP and Energy Intensity Indicators
1990 2000 2001 2002 2003 2004 2005 2006 2007 2008 2009 2010
Population (‘000) 3,292 4,039 4,076 4,098 4,122 4,155 4,197 4,244 4,310 4,384 4,460 4,531
Intensity (TJ/Pop) 0.316 0.315 0.285 0.272 0.267 0.278 0.273 0.265 0.267 0.248 0.234 0.236
Index (1990=1) 1.0 0.997 1.009 0.961 0.946 0.983 0.966 0.939 0.944 0.878 0.827 0.836
GDP(2002 $billion) 100.7 131.4 122.8 126.8 130.0 135.0 141.3 146.8 150.9 151.7 148.3 153.1
Intensity (TJ/$mil) 10.3 9.7 9.5 8.8 8.5 8.6 8.1 7.7 7.6 7.2 7.0 7.0
Index (1990=1) 1 0.938 0.854 0.792 0.764 0.771 0.732 0.692 0.687 0.647 0.634 0.631
Sources: STC CANSIM Table 379-0025 — Gross Domestic Product (GDP) at basic prices, by North American Industry Classification System (NAICS) and province, annual (dollars).
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Table 6. Energy Use by Fuel Type (TJ)
Fuel Type 1990 2000 2001 2002 2003 2004 2005 2006 2007 2008 2009 2010
Coal 3,293 9,803 12,243 10,754 11,243 14,280 11,358 17,109 15,800 14,091 11,109 10,937
Natural Gas 211,772 291,148 287,781 282,449 256,140 253,714 251,805 216,689 226,245 226,001 216,511 205,312
Gas Plant NGLs 18,027 11,351 11,930 11,102 10,616 10,007 12,286 31,476 33,413 33,758 29,744 31,796
Electricity 188,313 219,414 211,434 212,953 214,635 222,096 226,072 214,895 240,186 216,922 212,214 211,670
Steam - 2,865 2,680 201 297 2,031 1,978 1,808 2,241 2,155 383 540
Coke 813 254 205 223 230 - - - - - - -
Coke Oven Gas
Petroleum Products 318,692 387,251 381,911 381,519 394,262 414,059 402,862 399,115 406,638 404,909 372,888 395,602
Still Gas
Motor Gas 123,636 161,847 158,725 158,796 161,608 171,236 162,332 160,353 161,973 158,470 161,970 163,804
Kerosene 1,907 946 870 823 776 846 651 445 705 422 381 313
Diesel Fuel Oil 96,275 119,971 119,979 122,402 125,078 132,527 131,715 129,734 130,871 141,293 110,503 124,471
Light Fuel Oil 16,079 9,343 9,750 8,220 7,776 8,006 7,589 7,263 6,227 3,407 3,042 2,262
Heavy Fuel Oil 45,390 29,903 39,695 31,342 44,256 45,175 41,966 39,903 46,895 37,659 38,620 39,857
Petroleum Coke 205 426 538 529 486 488 461 416 426 361 343 235
Aviation Gasoline 1,083 513 503 548 545 1,156 908 3,712 3,153 3,349 3,245 2,475
Aviation Turbo Fuel 34,119 64,302 51,851 58,859 53,737 57,015 57,240 57,289 56,388 59,948 54,784 62,185
Total Energy (PJ) 931 1,180 1,158 1,113 1,102 1,155 1,149 1,148 1,172 1,109 1,062 1,092
Source: STC RESD. An anomaly occurs when summing fuels (this table) or when estimating fuels based on supply (see Table 1). STC and CIEEDAC are investigating this variation.
Table 7. Production (GDP) and Energy Intensity Indicators, All Sectors (Million $2002)
1990 2000 2001 2002 2003 2004 2005 2006 2007 2008 2009 2010
GDP 83,920 121,546 122,848 126,761 130,026 135,021 141,339 146,762 150,874 151,695 148,300 153,085
Intensity (Energy/TJ/GDP) 11.1 9.7 9.5 8.8 8.5 8.6 8.1 7.7 7.6 7.2 7.0 7.0
Index (1990 = 1) 1.0 0.879 0.854 0.792 0.764 0.771 0.732 0.692 0.687 0.647 0.634 0.631
Source: STC CANSIM Table 379-0025 — Gross Domestic Product (GDP) at basic prices, by NAICS and province, annual (dollars).
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Table 8. Energy Use, Mining and Oil and Gas Extraction (TJ)
Fuel Type 1990 2000 2001 2002 2003 2004 2005 2006 2007 2008 2009 2010
Coal 453 3,669 4,658 4,636 3,681 3,683
Natural Gas 3,755 3,937 2,703 3,730 1,137 3,751 2,513 11,478 16,328 22,086 23,058 25,038
Gas Plant NGLs 480 1,295 x 746 672 604 1,166 1,152 1,369 1,539 1,210 1,230
Electricity 13,619 10,806 11,953 11,377 9,718 9,333 9,362 7,385 8,960 3,595 3,310 3,543
Coke
Coke Oven Gas
Petroleum Products 11,690 12,721 11,199 9,729 11,799 11,759 13,432 13,468 12,035 11,169 10,189 14,531
Still Gas
Motor Gas
Kerosene 237 165 186 115 138 174 314 298 301
Diesel Fuel Oil 11,194 12,155 10,537 9,180 10,984 10,907 179 117 83 68 8 8
Light Fuel Oil 259 401 476 434 677 678 12,591 12,206 11,337 10,502 8,357 12,880
Heavy Fuel Oil 663 629 283 268 322 237
Petroleum Coke
Aviation Gasoline
Aviation Turbo Fuel
Total Energy 29,542 28,760 26,685 25,581 23,329 27,977 26,927 37,152 43,351 43,027 41,449 56,608
Source: STC RESD
Table 9. Production (GDP) and Energy Intensity Indicators, Mining and Oil and Gas Extraction (Million $2002)
1990 2000 2001 2002 2003 2004 2005 2006 2007 2008 2009 2010
GDP 2,015 3,344 4,252 4,383 4,298 4,270 4,643 4,645 4,422 4,598 4,293 4,595
Intensity (Energy/TJ/GDP) 14.7 8.6 6.3 5.8 5.4 6.6 5.8 8.0 9.8 9.4 9.7 12.3
Index (1990 = 1) 1 0.587 0.428 0.398 0.370 0.447 0.396 0.546 0.669 0.638 0.658 0.840
Source: STC CANSIM Table 379-0025 — Gross Domestic Product (GDP) at basic prices, by NAICS and province, annual (dollars).
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Table 10. Energy Use, Pulp and Paper (TJ)
Fuel Type 1990 2000 2001 2002 2003 2004 2005 2006 2007 2008 2009 2010
Coal 121 614 565 338 603 788 491 (0) 15
Natural Gas 28,040 40,151 31,937 32,232 25,132 26,602 19,042 22,738 22,790 19,167 19,684 18,216
Gas Plant NGLs
Electricity 47,835 52,439 48,012 46,578 48,226 52,547 54,735 46,700 42,293 36,467 33,787 33,764
Coke 201 297 2,031 1,978 1,808 2,241 2,071 304 432
Coke Oven Gas
Petroleum Products 30,948 7,749 9,487 4,312.0 5,723.0 4,953.0 2,434.0 2,817.0 2,550.0 838.0 2,746.0 2,514.0
Still Gas
Motor Gas x x x x
Kerosene x x x
Diesel Fuel Oil 3,241 532 486 487 486 483 467 126 X x x x
Light Fuel Oil 77 140 4 5 4 43 4
Heavy Fuel Oil 27,629 8,815 3,829 3,820 3,821 5,198 4,484 2,308 2,291 1,798 x x
Petroleum Coke
Aviation Gasoline
Aviation Turbo Fuel x x x x
Solid Wood Waste 42,152 63,612 57,456 61,138 68,287 80,621 89,182 103,503 96,917 83,203 79,918 90,809
Spent Pulping Liquor 126,673 150,430 132,454 129,727 120,213 127,140 124,669 132,595 124,192 93,482 107,139 110,733
Total Energy 275,649 314,382 279,333 274,309 268,491 294,458 292,378 310,764 291,771 235,718 243,578 256,483
Source: STC RESD
Table 11. Production (GDP) and Energy Intensity Indicators, Pulp and Paper (Million $2002)
1990 2000 2001 2002 2003 2004 2005 2006 2007 2008 2009 2010
GDP 1,510 1,484 1,241 1,316 1,334 1,411 1,527 1,488 1,583 1,367 1,172 1,200
Intensity (Energy/TJ/GDP) 182.5 213.8 227.3 208.5 201.3 208.6 191.4 208.8 184.3 172.4 207.8 213.7
Index (1990 = 1) 1.00 1.171 1.245 1.142 1.103 1.143 1.049 1.144 1.010 0.944 1.138 1.171
Source: STC CANSIM Table 379-0025 v382-7717
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Table 12. Production (GDP), Non-ferrous Smelting and Refining (Million $2002)1
1990 2000 2001 2002 2003 2004 2005 2006 2007 2008 2009 2010
GDP 959 x x 1,509 1,523 1,678 1,718 1,775 1,843 1,666 1,458 1,448
Note: 1. Energy use, and thus intensity indicators are not available. Source: STC CANSIM Table 379-0025 — Gross Domestic Product (GDP) at basic prices, by NAICS and province, annual (dollars).
Table 13. Production (GDP), Cement (Million $2002)
1990 2000 2001 2002 2003 2004 2005 2006 2007 2008 2009 2010
GDP x 240 213 239 281 311 319 355 461 390 274 264
Note: 1. Energy use, and thus intensity indicators are not available. Source: STC CANSIM Table 379-0025 — Gross Domestic Product (GDP) at basic prices, by NAICS and province, annual (dollars)
Table 14. Energy Use, Petroleum Refining (TJ)1
Fuel Type 1990 2000 2001 2002 2003 2004 2005 2006 2007 2008 2009 2010
Coal x x x x x x x x x x x
Natural Gas 4,466 x x x x x x x x x x x
Gas Plant NGLs x x x x x x x x x x x
Electricity 1,331 x x x x x x x x x x x
Coke x x x x x x x x x x x
Coke Oven Gas
Petroleum Products 17,624 x x x x x x x x x x x
Still Gas 13,473 x x x x x x x x x x x
Motor Gas 10 x x x x x x x x x x x
Kerosene x x x x x x x x x x x
Diesel Fuel Oil 170 x x x x x x x x x x x
Light Fuel Oil 8 x x x x x x x x x x x
Heavy Fuel Oil 405 x x x x x x x x x x x
Petroleum Coke 3,554 x x x x x x x x x x x
Aviation Gasoline x x x x x x x x x x x
Aviation Turbo Fuel 4 x x x x x x x x x x x
Total Energy 23,420 x x x x x x x x x x x
Note: 1. Energy use data are confidential after 1998. Source: STC RESD
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Table 15. Production (GDP) and Energy Intensity Indicators, Petroleum Refining (Million $2002)
1990 2000 2001 2002 2003 2004 2005 2006 2007 2008 2009 2010
GDP x x x 75 77 74 x x x x x X
Intensity (Energy/TJ/GDP) - - - 0.0 0.0 0.0 - - - - - -
Source: STC CANSIM Table 379-0025 — Gross Domestic Product (GDP) at basic prices, by NAICS and province, annual (dollars)
Table 16. Energy Use, Chemical Manufacturing (TJ)
Fuel Type 1990 2000 2001 2002 2003 2004 2005 2006 2007 2008 2009 2010
Coal X x x x x x x x x x
Natural Gas 8,731 6,033 2,007 2,335 2,349 1,689 2,215 1,879 1,784 x x x
Gas Plant NGLs
Electricity 6,387 6,657 5,917 6,398 6,546 6,081 6,193 7,926 6,258 5,542 5,311 4,937
Steam x x
Coke Oven Gas
Petroleum Products 105.75 38.25 0.2 0.21 0.2 0.6 0.6 0.9
Still Gas
Motor Gas
Kerosene
Diesel Fuel Oil 35 x x x x x x x x X
Light Fuel Oil x x x x x x x x X
Heavy Fuel Oil 71 38 x x x x x x
Petroleum Coke x x x x X
Aviation Gasoline
Aviation Turbo Fuel
Total Energy 15,224 12,728 7,924 8,733 8,895 7,769 8,487 9,960 8,136 7,681 6,870 6,399
Source: STC RESD
Table 17. Production (GDP) and Energy Intensity Indicators, Chemical Manufacturing (Million $2002)
1990 2000 2001 2002 2003 2004 2005 2006 2007 2008 2009 2010
GDP 139 170 181 225 x 220 236 158 142 127 112 106
Intensity (Energy/TJ/GDP) 109.4 74.9 43.8 38.8 - 35.3 36.0 63.0 57.3 60.5 61.5 60.5
Index (1990 = 1) 1.00 0.684 0.400 0.355 - 0.323 0.329 0.575 0.523 0.553 0.562 0.553
Source: STC CANSIM Table 379-0025
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Table 18. Energy Use, Other Manufacturing (TJ)
Fuel Type 1990 2000 2001 2002 2003 2004 2005 2006 2007 2008 2009 2010
Coal 271 x x x x x x x x x x
Natural Gas 26,722 66,346 77,894 63,824 70,872 67,089 70,659 23,518 25,949 19,074 16,337 17,357
Gas Plant NGLs 449 952 1,394 x x x x x x x x x
Electricity 6,760 11,431 13,534 14,405 14,839 14,306 14,597 17,627 18,813 13,559 15,881 16,935
Coke x x x x x x 0 0 0
Steam - - - - - 84 79 108
Petroleum Products 1,387 2,190 1,998 2,330 2,963 2,793 2,440 2,262 2,540 1,715 2,085 2,161
Still Gas
Motor Gas - - - x x x x x
Kerosene 45 8 - - - x x x x x
Diesel Fuel Oil 940 1,708 1,674 x x x x 1,881 1,808 1,203 1,612 1,704
Light Fuel Oil 147 256 140 140 124 124 39 113 109 85 27 -
Heavy Fuel Oil 255 43 115 208 - - 4 4 x x x
Petroleum Coke 176 70 x x x x x x x x x
Aviation Gasoline - - - x x x x x
Aviation Turbo Fuel - - - x x x x x
Total Energy 35,318 81,194 95,460 82,908 90,773 86,079 91,089 46,772 51,352 38,747 37,891 40,179
Source: STC RESD
Table 19. Production (GDP) and Energy Intensity Indicator, Other Manufacturing (Million $2002)
1990 2000 2001 2002 2003 2004 2005 2006 2007 2008 2009 2010
GDP 7,473 8,553 7,896 8,881 7,214 9,696 10,115 10,964 11,138 9,211 8,084 8,618
Intensity (Energy/TJ/GDP) 4.7 9.5 12.1 9.3 12.6 8.9 9.0 4.3 4.6 4.2 4.7 4.7
Index (1990 = 1) 1.00 2.008 2.558 1.975 2.662 1.878 1.905 0.903 0.975 0.890 0.992 0.986
Sources: STC CANSIM Table 379-0025 — Gross Domestic Product (GDP) at basic prices, by NAICS and province, annual (dollars)
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Table 20. Energy Use, Total Manufacturing (TJ)
Fuel Type 1990 2000 2001 2002 2003 2004 2005 2006 2007 2008 2009 2010
Coal 3,283 9,069 9,538 10,754 11,243 11,751 10,379 10,392 12,214 10,291 7,426 x
Natural Gas 73,905 124,322 107,711 102,428 101,490 98,700 95,317 52,592 55,336 45,662 42,250 42,411
Gas Plant NGLs 449 952 1,394 1,823 1,713 1,539 2,971 x x x x x
Electricity 86,608 97,398 87,721 87,763 92,983 98,969 101,729 91,975 87,530 81,309 76,881 76,226
Coke 813 254 205 201 297 2,031 1,978 1,808 2,241 2,155 383 540
Coke Oven Gas 223 231 0 0 0 0 0 0 0
Petroleum Products 32,824 10,309 11,994 7,043 9,061 8,584 5,613 8,900 8,100 5,853 8,119 7,319
Still Gas 0 0 0 0 0 0 0 0
Motor Gas 0 0 0 x x x x x
Kerosene 45 8 0 0 0 x x x x x
Diesel Fuel Oil 4,375 3,474 2,248 2,531 2,941 2,815 2,359 2,493 2,290 1,566 1,988 2,045
Light Fuel Oil 236 349 283 144 167 128 39 113 109 85 31 0
Heavy Fuel Oil 27,963 6,052 8,925 3,820 5,406 4,484 2,308 2,295 1,802 x 2,253 2,112
Petroleum Coke 205 426 538 548 547 1,154 908 3,926 3,323 3,523 3,245 2,475
Aviation Gasoline 0 0 0 x x x x x
Aviation Turbo Fuel 0 0 0 x x x x x
Total Energy 366,705 451,077 418,535 401,101 405,515 429,336 431,839 404,698 389,174 325,034 325,201 338,426
Note: Total includes Pulp and Paper, Smelting and Refining, Cement, Petroleum Refining, Chemicals, Other Manufacturing, and confidential/hidden consumption. Source: STC RESD
Table 21. Production (GDP) and Energy Intensity Indicators, Total Manufacturing (Million $2002)
1990 2000 2001 2002 2003 2004 2005 2006 2007 2008 2009 2010
GDP 10,834 14,990 13,667 13,687 13,884 14,723 15,904 15,885 14,546 12,657 13,156 15,904
Intensity (Energy/TJ/GDP) 33.8 30.1 30.6 29.3 29.2 29.2 25.4 24.5 22.3 25.7 25.7 25.4
Index (1990 = 1) 1.00 0.889 0.905 0.866 0.863 0.861 0.752 0.724 0.660 0.759 0.760 0.752
Source: STC CANSIM Table 379-0025 — Gross Domestic Product (GDP) at basic prices, by NAICS and province, annual (dollars)
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Table 22. Energy Use, Forestry (TJ)
Fuel Type 1990 2000 2001 2002 2003 2004 2005 2006 2007 2008 2009 2010
Coal
Natural Gas
Gas Plant NGLs
Electricity
Coke
Coke Oven Gas
Petroleum Products 2,978 5,523 7,848 7,585 7,206 7,555 7,246 8,621 7,970 7,111 5,988 10,206
Still Gas
Motor Gas - - - - 1,436 1,635 1,732 901 1,667
Kerosene 26 8 4 4 4 8 4 4 4 4 4 4
Diesel Fuel Oil 2,696 5,373 7,733 7,511 7,105 7,357 7,009 6,971 6,178 5,259 4,987 8,460
Light Fuel Oil 147 23 81 50 31 190 167 163 151 113 81 8
Heavy Fuel Oil 108 119 30 21 64 0 68 47 0 4 13 68
Petroleum Coke
Aviation Gasoline
Aviation Turbo Fuel
Total Energy 2,978 5,523 7,848 7,585 7,206 7,555 7,246 8,621 7,970 7,111 5,988 10,206
Source: STC RESD
Table 23. Production (GDP) and Energy Intensity Indicators, Forestry (Million $2002)
1990 2000 2001 2002 2003 2004 2005 2006 2007 2008 2009 2010
GDP 3,030 2,638 2,647 2,713 2,761 3,129 3,102 3,022 2,855 2,463 2,168 2,514
Intensity (Energy/TJ/GDP) 1.0 2.09 2.97 2.80 2.61 2.41 2.34 2.85 2.79 2.89 2.76 4.06
Index (1990 = 1) 1.00 2.129 3.015 2.842 2.653 2.454 2.375 2.900 2.838 2.936 2.808 4.127
Source: STC CANSIM Table 379-0025 — Gross Domestic Product (GDP) at basic prices, by NAICS and province, annual (dollars)
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Table 24. Energy Use, Construction (TJ)
Fuel Type 1990 2000 2001 2002 2003 2004 2005 2006 2007 2008 2009 2010
Coal
Natural Gas 4,258 1,109 1,006 1,135 1,379 1,735 1,829 1,921 2,058 1,817 853 1,406
Gas Plant NGLs 677 125 119 91 78 71 76 73 89 99 78 78
Electricity
Coke
Coke Oven Gas
Petroleum Products 4,835 4,422 4,020 4,612 5,044 5,112 5,141 5,309 6,476 6,417 5,507 6,021
Still Gas
Motor Gas 0 0 0 0 268 433 422 593 935
Kerosene 15 4 4 4 4 4 4 4 4 0 0 11
Diesel Fuel Oil 4,158 4,251 3,845 4,458 4,937 4,983 4,990 4,899 5,929 5,952 4,703 4,998
Light Fuel Oil 654 167 171 151 105 124 147 136 109 47 89 70
Heavy Fuel Oil 8 0 0 0 0 0 0 0 119 9
Petroleum Coke
Aviation Gasoline
Aviation Turbo Fuel
Total Energy 9,770 5,656 5,144 5,840 6,501 6,917 7,045 7,303 8,634 8,333 6,438 7,506
Source: STC RESD
Table 25. Production (GDP) and Energy Intensity Indicators, Construction (Million $2002)
1990 2000 2001 2002 2003 2004 2005 2006 2007 2008 2009 2010
GDP 5,778 5,795 6,021 6,328 6,927 7,675 8,115 8,936 9,097 9,501 8,617 9,673
Intensity (Energy/TJ/GDP) 1.7 1.0 0.9 0.9 0.9 0.9 0.9 0.8 0.9 0.9 0.7 0.8
Index (1990 = 1) 1.00 0.577 0.506 0.546 0.555 0.533 0.513 0.483 0.561 0.519 0.442 0.459
Source: STC CANSIM Table 379-0025 — Gross Domestic Product (GDP) at basic prices, by NAICS and province, annual (dollars)
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Table 26. Energy Use, Total Industry (TJ)
Fuel Type 1990 2000 2001 2002 2003 2004 2005 2006 2007 2008 2009 2010
Coal 3,283 9,069 X 10,754 11,243 14,457 10,996 14,225 17,056 15,081 11,267 11,095
Natural Gas 81,918 130,150 111,398 107,296 104,007 104,187 99,660 65,991 73,632 69,564 66,157 68,855
Gas Plant NGLs 1,606 2,372 2,650 2,660 2,465 2,215 4,212 4,158 4,948 5,556 4,374 4,444
Electricity 100,227 108,203 99,399 99,139 102,701 108,302 111,091 99,360 96,490 84,904 80,190 79,770
Coke 813 254 205 201 297 2,031 1,978 1,808 2,241 2,155 383 540
Coke Oven Gas 222 231 0 0 0 0 0 0 0
Petroleum Products 52,323 32,980 35,060 28,968 33,111 33,010 31,432 36,299 34,573 30,558 29,797 38,077
Still Gas
Motor Gas 0 0 0 0 x x x x x
Kerosene 324 185 192 121 147 185 185 124 317 170 143 121
Diesel Fuel Oil 22,427 25,255 24,363 23,681 23,681 23,681 23,681 23,681 23,681 23,681 23,681 23,681
Light Fuel Oil 1,292 943 1,009 780 982 1,121 1,017 1,040 892 613 695 539
Heavy Fuel Oil 28,076 6,171 8,959 3,842 5,474 4,484 2,372 2,542 1,836 408 2,444 2,223
Petroleum Coke 205 426 538 547 547 1,154 908 3,926 3,323 3,523 3,245 2,475
Aviation Gasoline 0 0 0 0 x x x x x
Aviation Turbo Fuel 0 0 0 0 494 868 969 408 602
Total Energy 408,996 491,015 458,216 440,106 442,550 471,785 473,057 457,776 449,123 383,513 379,067 404,165
Note: Total includes Forestry, Construction, Total Manufacturing and confidential/hidden consumption. Source: STC RESD
Table 27. Production (GDP) and Energy Intensity Indicators, Total Industry (Million $2002)
1990 2000 2001 2002 2003 2004 2005 2006 2007 2008 2009 2010
GDP 21,656 26,768 26,587 27,111 27,871 29,798 31,294 32,507 32,258 31,108 27,735 29,938
Intensity (Energy/TJ/GDP) 18.9 18.3 17.2 16.2 15.9 15.8 15.1 14.1 13.9 12.3 13.7 13.5
Index (1990 = 1) 1.00 0.971 0.913 0.860 0.841 0.838 0.800 0.746 0.737 0.653 0.724 0.715
Source: STC CANSIM Table 379-0025 — Gross Domestic Product (GDP) at basic prices, by NAICS and province, annual (dollars)
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Table 28. Energy Use, Transportation (TJ)
Fuel Type 1990 2000 2001 2002 2003 2004 2005 2006 2007 2008 2009 2010
Coal
Natural Gas 16,846 32,360 36,521 26,370 20,639 21,955 19,233 15,059 18,095 17,488 16,998 16,463
Gas Plant NGLs 12,237 4,914 4,829 4,596 4,166 4,153 3,052 3,014 3,589 4,027 3,169 3,222
Electricity 557 619 607 719 752 698 712 616 750 1,304 1,599 1,992
Coke
Coke Oven Gas
Petroleum Products 223,952 310,403 302,514 304,170 314,221 325,345 312,327 306,457 318,939 317,288 326,384 340,424
Still Gas 0 0 0 0 0 0 0 0 0
Motor Gas 115,283 152,436 150,042 149,569 152,191 161,963 153,388 149,832 150,903 147,165 154,585 154,987
Kerosene 0 0 0 0 0 0 0 0 0
Diesel Fuel Oil 61,348 73,184 73,306 71,698 73,149 71,257 67,810 67,442 71,897 78,289 83,134 87,960
Light Fuel Oil 0 0 0 0 0 0 5 0 14
Heavy Fuel Oil 16,561 23,120 29,784 26,618 38,127 38,118 37,043 34,965 42,096 34,735 35,998 37,638
Petroleum Coke 0 0 0 0 0 0 0 0 0
Aviation Gasoline 446 144 168 168 174 144 178 204 275 255 181 144
Aviation Turbo Fuel 30,314 61,519 49,215 56,115 50,580 53,867 53,908 54,006 53,706 56,841 52,487 59,679
Total Energy 253,592 348,256 344,180 335,857 339,777 352,149 335,327 325,146 341,472 340,107 348,150 362,101
Note: Total includes railways, airlines, marine, pipelines, road transport/urban transit and retail pump sales. Source: STC RESD
Table 29. Production (GDP) and Energy Intensity Indicators, Transportation (Million $2002)
1990 2000 2001 2002 2003 2004 2005 2006 2007 2008 2009 2010
GDP 5,141 14,855 14,835 14,789 15,284 15,864 17,340 18,784 18,829 18,415 17,959 18,473
Intensity (Energy/TJ/GDP) 49.3 23.4 23.2 22.7 22.2 22.2 19.3 17.3 18.1 18.5 19.4 19.6
Index (1990 = 1) 1.00 0.475 0.471 0.460 0.451 0.450 0.392 0.351 0.368 0.374 0.393 0.397
Source: STC CANSIM Table 379-0025 — Gross Domestic Product (GDP) at basic prices, by NAICS and province, annual (dollars)
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Table 30. Energy Use, Agriculture (TJ)
Fuel Type 1990 2000 2001 2002 2003 2004 2005 2006 2007 2008 2009 2010
Coal
Natural Gas 2,781 4,149 4,140 731 695 669 742 750 739 691 557 5,716
Gas Plant NGLs 449 190 256 162 152 149 144 142 170 190 149 152
Electricity 984 1,827 1,439 1,344 1,294 1,452 1,472 1,329 1,737 2,619 2,708 2,664
Coke
Coke Oven Gas
Petroleum Products 5,880 10,073 12,271 12,223 11,571 11,151 8,879 9,252 10,760 9,201 8,356 9,432
Still Gas
Motor Gas 2,211 2,583 3,224 4,018 4,092 4,158 3,812 3,798 3,843 3,801 3,273 3,927
Kerosene 377 196 166 154 98 41 8 11 8 4 0 4
Diesel Fuel Oil 1,791 6,320 7,308 7,185 7,066 6,833 5,021 5,377 6,833 5,370 5,048 5,442
Light Fuel Oil 1,501 920 1,498 803 314 120 39 54 70 19 35 58
Heavy Fuel Oil 55 77 68
Petroleum Coke
Aviation Gasoline
Aviation Turbo Fuel 9 7 8
Total Energy 10,093 16,238 18,106 14,461 13,713 13,421 11,238 11,472 13,410 12,701 11,770 17,964
Source: STC RESD
Table 31. Production (GDP) and Energy Intensity Indicators, Agriculture (Million $2002)
1990 2000 2001 2002 2003 2004 2005 2006 2007 2008 2009 2010
GDP 878 975 1,141 1,058 1,053 1,057 1,061 1,078 1,134 1,147 1,157 1,156
Intensity (Energy/TJ/GDP) 11.3 16.7 15.9 13.7 13.0 12.7 10.6 10.6 11.8 11.1 10.2 15.5
Index (1990 = 1) 0.760 1.119 1.067 0.919 0.875 0.853 0.712 0.715 0.795 0.744 0.684 1.044
Source: STC CANSIM Table 379-0025 — Gross Domestic Product (GDP) at basic prices, by NAICS and province, annual (dollars)
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Table 32. Energy Use, Residential (TJ)
Fuel Type 1990 2000 2001 2002 2003 2004 2005 2006 2007 2008 2009 2010
Coal 10 x 0 0 0 523 206 73 0 0 0
Natural Gas 63,285 78,579 76,085 79,284 75,220 72,591 79,057 81,620 80,176 80,534 81,022 67,221
Gas Plant NGLs 2,244 990 1,009 1,283 1,152 1,015 906 896 1,066 1,197 942 957
Electricity 45,280 58,328 58,226 60,042 59,164 63,115 63,413 63,783 79,834 69,706 69,308 66,835
Coke
Coke Oven Gas
Petroleum Products 10,281 5,584 5,809 1,059 951 1,238 899 898 964 920 2,076 1,380
Still Gas
Motor Gas 0 0 0 0 0 11 6 22 0
Kerosene 934 226 121 121 124 185 75 64 102 64 64 26
Diesel Fuel Oil 0 0 0 0 0 0 0 1 0
Light Fuel Oil 9,310 5,358 5,688 939 826 1,055 826 834 854 846 1,987 1,354
Heavy Fuel Oil 38
Petroleum Coke
Aviation Gasoline
Aviation Turbo Fuel
Total Energy 121,100 143,458 141,196 141,668 136,487 137,960 144,800 147,402 162,555 152,358 153,347 136,393
Source: STC RESD
Table 33. Production (GDP) and Energy Intensity Indicators, Residential (Million $2002)
1990 2000 2001 2002 2003 2004 2005 2006 2007 2008 2009 2010
GDP 7,875 12,341 12,621 13,212 13,629 14,144 14,946 15,667 16,471 17,311 18,158 18,955
Intensity (Energy/TJ/GDP) 15.4 11.6 11.2 10.7 10.0 9.8 9.7 9.4 9.9 8.8 8.4 7.2
Index (1990 = 1) 1.00 0.756 0.727 0.697 0.651 0.634 0.630 0.612 0.642 0.572 0.549 0.468
Source: STC CANSIM Table 379-0025 — Gross Domestic Product (GDP) at basic prices, by NAICS and province, annual (dollars)
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Table 34. Energy Use, Commercial and Institutional (TJ)
Fuel Type 1990 2000 2001 2002 2003 2004 2005 2006 2007 2008 2009 2010
Coal
Natural Gas 45,952 48,414 45,594 63,435 50,554 49,436 47,699 47,806 46,993 52,422 46,969 44,421
Gas Plant NGLs 1,453 2,640 2,969 3,194 2,908 2,612 1,746 1,726 2,053 2,303 1,815 1,843
Electricity 37,952 46,518 48,100 48,262 47,534 45,453 46,317 46,846 57,794 54,681 54,458 56,513
Coke
Coke Oven Gas
Petroleum Products 19,513 24,910 23,253 31,972 30,393 42,333 45,985 42,924 37,981 42,640 2,642 1,981
Still Gas
Motor Gas 5,494 6,115 4,694 4,442 5,327 5,117 5,135 4,928 5,460 5,737 1,334 1,183
Kerosene 249 328 381 430 403 426 381 249 275 185 173 162
Diesel Fuel Oil 6,726 13,340 13,512 18,311 18,897 28,376 31,931 30,345 26,412 34,355 2,275 2,689
Light Fuel Oil 3,551 2,021 1,467 5,645 5,653 5,711 5,711 5,327 4,349 1,924 326 295
Heavy Fuel Oil 697 616 956 816 659 2,571 2,550 2,397 2,962 2,516 170 0
Petroleum Coke - - - 0 0 0 0 0 0 0 0 0
Aviation Gasoline 429 392 325 349 308 342 282 188 131 94 101 60
Aviation Turbo Fuel 2,368 2,098 1,919 1,982 3,157 3,149 3,332 2,779 1,806 2,132 1,889 1,904
Total Energy 104,866 122,495 119,917 146,863 131,387 139,834 141,749 142,144 145,084 152,046 105,884 104,758
Note: This sector includes Public Administration. Source: STC RESD
Table 35. Production (GDP) and Energy Intensity Indicators, Commercial and Institutional (Million $2002)
1990 2000 2001 2002 2003 2004 2005 2006 2007 2008 2009 2010
GDP 37,713 66,756 68,635 71,351 73,648 74,183 75,217 80,418 83,842 81,409 80,759 82,168
Intensity (Energy/TJ/GDP) 2.8 1.8 1.7 2.1 1.8 1.9 1.9 1.8 1.7 1.9 1.3 1.3
Index (1990 = 1) 1.00 0.660 0.628 0.740 0.642 0.678 0.678 0.636 0.622 0.672 0.472 0.459
Note: This sector includes Public Administration. Source: STC CANSIM Table 379-0025 — Gross Domestic Product (GDP) at basic prices, by NAICS and province, annual (dollars)
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Table 36. Energy Use, Public Administration (TJ)
Fuel Type 1990 2000 2001 2002 2003 2004 2005 2006 2007 2008 2009 2010
Coal 734 278
Natural Gas 990 6,401 6,704 5,333 5,027 4,879 5,414 5,467 5,370 5,301 4,804 2,639
Gas Plant NGLs 38 246 149 0 0 0 0 0 0 0 0 0
Electricity 3,313 3,940 3,664 3,447 3,191 3,075 3,068 2,962 3,582 3,708 3,952 3,896
Coke
Coke Oven Gas
Petroleum Products 6,746 3,393 3,082 3,124 4,017 3,371 3,338 3,288 3,414 4,302 3,633 4,311
Still Gas
Motor Gas 648 714 763 770 809 816 819 798 802 791 949 984
Kerosene 19 11 8 0 4 8 0 0 0 0 0 0
Diesel Fuel Oil 3,984 1,877 1,490 1,524 2,264 1,858 1,888 1,850 1,835 2,677 1,892 2,474
Light Fuel Oil 429 97 93 54 50 47 39 39 31 27 27 19
Heavy Fuel Oil 21 9
Petroleum Coke
Aviation Gasoline 208 10 10 10 23 13 7 7 7 10 17 0
Aviation Turbo Fuel 1,437 684 718 759 868 628 583 595 741 797 741 834
Total Energy 11,067 14,715 13,879 11,905 12,235 11,324 11,820 11,717 12,395 13,311 12,389 10,846
Source: STC RESD
Table 37. Production (GDP) and Energy Intensity Indicators, Public Administration (Million $2002)
1990 2000 2001 2002 2003 2004 2005 2006 2007 2008 2009 2010
GDP 5,074 5,774 6,277 6,339 6,588 6,790 6,919 7,128 7,188 7,202 7,268 7,506
Intensity (Energy/TJ/GDP) 2.2 3.2 2.8 2.6 2.1 2.2 2.0 1.7 1.7 1.6 1.6 1.6
Index (1990 = 1) 1.00 1.471 1.279 1.190 0.982 0.993 0.920 0.766 0.780 0.721 0.746 0.716
Source: STC CANSIM Table 379-0025 — Gross Domestic Product (GDP) at basic prices, by NAICS and province, annual (dollars)
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Table 38. Electricity Generation, Net Supply and Producer Consumption of British Columbia (GWh)
Fuel Type 1990 2000 2001 2002 2003 2004 2005 2006 2007 2008 2009 2010
Total Electricity Prod. 61,014 68,685 58,764 65,335 63,383 61,979 67,774 61,598 71,830 66,072 65,057 63,637
Primary Electricity 57,308 60,208 49,163 58,878 56,929 54,652 60,327 54,247 64,287 58,699 56,462 53,678
Secondary Electricity 3,706 8,476 9,601 6,457 6,454 7,327 7,447 7,350 7,543 7,373 8,594 9,959
Total Net Supply 57,514 64,054 61,542 62,895 60,837 63,450 65,732 68,151 69,022 68,546 68,827 66,838
Primary Electricity 53,809 55,577 51,941 56,438 54,383 56,123 58,285 60,801 61,479 61,173 60,233 56,879
Secondary Electricity 3,706 8,476 9,601 6,457 6,454 7,327 7,447 7,350 7,543 7,373 8,594 9,959
Producer Consumption (Primary)
5,205 3,112 2,778 3,742 1,216 1,756 2,934 12,376 12,378 10,356 10,984 10,130
Source: STC CANSIM Table 128-0003 — Supply and demand of primary and secondary energy in natural units, computed annual total (megawatt hour)
Table 39. Electricity Power Statistics, British Columbia (GWh)
Fuel Type 1990 2000 2001 2002 2003 2004 2005 2006 2007 2008 2009 2010
Overall Total Gen. 60,662 68,241 57,332 64,945 63,051 60,496 67,774 61,598 71,830 66,072 65,057 63,637
Total Utility Gen 47,742 54,368 45,630 51,630 49,243 46,647 54,129 48,080 58,603 52,795 51,852 51,208
Total Industrial Gen 12,921 13,873 11,702 13,315 13,808 13,849 13,645 13,517 13,227 13,277 13,205 12,429
Total Hydro Gen 57,245 59,754 48,338 58,627 56,689 53,281 60,327 54,247 64,287 58,699 56,462 53,555
By Utility 46,387 50,346 40,679 49,396 46,797 43,653 50,305 44,464 54,706 48,634 46,263 44,395
By Industry 10,858 9,409 7,659 9,231 9,892 9,629 10,022 9,783 9,581 10,065 10,199 9,160
Total Convent. Steam 3,197 7,138 7,615 4,319 4,230 4,908 4,997 5,370 5,007 4,774 4,280 4,565
By Utility 1,224 3,547 4,380 1,106 1,144 1,555 1,414 1,674 1,385 1,592 1,295 1,313
By Industry 2.0 3,591 3,235 3,213 3,086 3,353 3,583 3,696 3,622 3,182 2,985 3,252
Total Internal Combust 220 69 69 74 73 80 102 48 83 90 126 131
By Utility 130 50 49 61 54 59 62 11 58 60 105 114
By Industry 89.9 19 20 13 19 21 39 37 24 31 21 17
Total Combust. Turbine 0.4 1,280 1,310 1,925 2,059 2,226 2,348 1,932 2,454 2,509 2,270 2,287
By Utility 0.4 426 522 1,067 1,248 1,381 2,348 1,932 2,454 2,509 2,270 2,287
By Industry 0 854 788 858 812 845 0 0 0 0 0 0
Source: STC CANSIM Table 127-0001 — Electric power statistics, computed annual total (megawatt hour)
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Appendix B: Cogeneration Data Tables, 2010
NOTE: Data updating and review are not complete; data reflect previous assessments and do not reflect current systems.
Table 1. Cogeneration for British Columbia
NAICS Start Year
Operator Type of Business Primary Thermal Host Electrical
Capacity (kW) Thermal
Capacity (kW) Cogen Type Fuel
2211 1999 Calpine Island Cogeneration Independent Power Producer Norske Skogindustrier, Elk Falls 290,000 78,051 GT NG
2211 1993 Atco Power Electric Utility Duke Energy 118,000 GT NG
2213 1998 Greater Vancouver Regional Dist. Water Treatment Plant Iona Island WWT Plant 4,050 3,963 SI Digester
2213 Annacis Island Water Treatment Plant 3,400
2213 Vancouver Landfill Landfill 9,000
3113 1973 Rogers Sugar Food Manufacturer Rogers Sugar 3,000 3,778 BPST NG
3211 1985 Riverside Forest Products Wood Products Riverside Forest Products 12,000 55,560 CST Hog
3211 1999 Tolko Industries Ltd. Wood Products 22,000 33,000 BPEST
3212 1936 Louisianna Pacific Wood Products Louisiana Pacific 7,500 18,750 ECST Hog
3221 1949 Western Pulp Ltd. Pulp and Paper Port Alice Operations 15,000 97,500 BPST, ECST SPL
3221 1963 Pope and Talbot Inc. Pulp and Paper Pope and Talbot Harmac Pulp 30,000 373,603 BPST SPL
3221 1964 Norske Canada Pulp and Paper Port Alberni Pulp and Paper Div. 18,000 137,400 BPEST Hog
3221 1968 Tembec Industries Inc. Pulp Mill Tembec Industries Inc. 58,500 276,625 BPEST SPL
3221 1968 Catalyst Paper Pulp and Paper 36,000 254,468 BPEST
3221 1972 Cariboo Pulp and Paper Pulp and Paper Cariboo Pulp and Paper 32,000 387,890 BPEST SPL
3221 1972 Domtar Pulp Pulp Mill 76,500 BPST, CST
3221 1973 Canadian Forest Products Pulp and Paper CANFOR – Northwood 55,400 BPEST SPL
3221 1979 Pope and Talbot Ltd. Pulp and Paper Mackenzie Pulp Operation 20,000 54,650 BPEST SPL
3221 1980 Norske Skogindustrier Pulp and Paper Crofton Pulp & Paper 38,700 45,267 BPST
3221 1989 Howe Sound Pulp and Paper Pulp and Paper Howe Sound Pulp and Paper 112,500 414,600 BPEST, ECST SPL
3221 1993 Celgar Pulp Co. Pulp and Paper Celgar Pulp Co. 52,000 342,807 BPEST SPL
Total 1,018,050 4,840,000
Note: Summary for Province = BC (21 detail records). Thermal capacity estimated, not all recipients responded Source: Canadian Cogeneration Database, CIEEDAC
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Appendix C: Renewable Energy Data, 2009
NOTE: Data updating and review are not complete; data reflect previous assessments and do not reflect current systems.
Table 1. Biogas — Landfill Gas Facilities
Name Company Location Type of Business
Electrical Capacity (kW)
Purchase Electricity from Grid?
Sell Electricity to Grid?
Thermal Capacity (kW)
Start Year Eco-certification
Hartland Landfill Maxim Power Corp. Victoria 1,600 2004
Jackman Landfill ToGro Greenhouses Ltd. Langley Agriculture 1995
Port Mann Landfill Georgia Pacific Surrey Wallboard Manufacturer
Yes No 1993
Vancouver Landfill Maxim Power Corp. Delta 5,550 99,540 2003
Total 7,150 110,040
Table 2. Biogas — Sewage Facilities
Name Company Location Type of Business Electrical Capacity (kW)
Purchase Electricity from Grid?
Sell Electricity to Grid?
Thermal Capacity (kW)
Start Year Eco-certification
Annacis Island Greater Vancouver Regional District
Richmond Regional Wastewater Treatment Facility
4,400 Yes Yes 3,300 1975
Iona Islands Greater Vancouver Regional District
Richmond Regional Wastewater Treatment Facility
3,750 Yes No 1,500 1995
Total 8,150 4,800
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Table 3. Solar Photovoltaic Installations
Name Company Location Type of Business Electrical Capacity (kW)
Purchase Electricity from Grid?
Sell Electricity to Grid?
Thermal Capacity (kW)
Start Year
Eco-certification
BCIT Solar Installation Burnaby College 4 No No 2000
CMHC Home Solar Installation
BCIT Technology Center
Burnaby Academic Research and Development
2 No No 2000
Operations Centre City of White Rock
White Rock 2003
Prince George Solar Installation
Private home Prince George Residences 1 No No 1996
Solar Plus Solar Plus Mill Bay Renewable Electricity Generator
1 Yes 1987
TELUS Solar Installation
TELUS Inc. Vancouver Telecommunications 3 No No 2000
Victoria Solar House SPS Energy Victoria Diversified Electricity Generator
1 No No 2001
Victoria Solar House 2 Victoria 2 2004
Williams Farrel Building
Vancouver 2000
Total 14
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Table 4. Hydroelectricity – Storage Facilities
Name Company Location Type of Business Electrical Capacity (kW)
Purchase Electricity from Grid?
Sell Electricity to Grid?
Thermal Capacity (kW)
Start Year
Eco-certification
Alouette BC Hydro Alouette Lake Crown Corporation 9,000 No Yes 1928
Arrow Lakes Generating Station
Columbia Power Corporation
Columbia River 185,000 No 2002
Ash River BC Hydro Ash River Crown Corporation 27,000 No Yes 1959
Bridge River #1 BC Hydro Bridge River Crown Corporation 191,000 No Yes 1948
Bridge River #2 BC Hydro Bridge River Crown Corporation 275,000 No Yes 1959
Cheakamus BC Hydro Cheakamus River Crown Corporation 157,000 No Yes 1957
Clowhom BC Hydro Clowhom River Crown Corporation 33,000 No Yes 1957
Comox Dam BC Hydro Puntledge River Crown Corporation 1953
Corra Linn FortisBC Kootenay River Utility 45,000 No No 1932
Falls River BC Hydro Falls River Crown Corporation 7,000 No Yes 1930
Gordon M. Shrum BC Hydro Peace River 2,730,000 No Yes 1968
John Hart BC Hydro Campbell River Crown Corporation 126,000 No Yes 1947
Jordan River BC Hydro Jordan River Crown Corporation 170,000 No Yes 1971
Kemano Generating Station
Alcan Primary Metal, BC
Kemano Aluminum Smelter 960,000 No Yes 1954
Kootenay Channel BC Hydro Kootenay River Crown Corporation 572,000 No Yes 1975
La Joie BC Hydro Dounton Lake Crown Corporation 25,000 No Yes 1957
Ladore Falls BC Hydro Campbell River Crown Corporation 47,000 No Yes 1956
Lake Buntzen #1 BC Hydro Lake Buntzen Crown Corporation 55,000 1951
Lake Buntzen #2 BC Hydro Lake Buntzen Crown Corporation 1914
Lois Brookfield Power Operations: BC
Lois Lake Renewable Electricity Generators
34,660 No Yes 1930
Mica BC Hydro Columbia River Crown Corporation 1,805,000 No Yes 1976
Moresby Lake Northern Utilities Inc. and Queen Charlotte Power Corp.
Moresby Lake Renewable Electricity Generator
5,700 1990
Powell River Brookfield Power Operations: BC Operations
Powell Lake Renewable Electricity Generators
47,250 No No 1911
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Name Company Location Type of Business Electrical Capacity (kW)
Purchase Electricity from Grid?
Sell Electricity to Grid?
Thermal Capacity (kW)
Start Year
Eco-certification
Revelstoke BC Hydro Columbia River Crown Corporation 1,980,000 No Yes 1984
Ruskin BC Hydro Hayward Lake Crown Corporation 10,500 No Yes 1930
Seton BC Hydro Seton Creek Crown Corporation 48,000 No Yes 1956
Seven Mile BC Hydro Pend D’Oreille River
Crown Corporation 804,000 No Yes 1979
Shuswap Falls BC Hydro Shuswap River Crown Corporation 6,000 No Yes 1929
Stave Falls BC Hydro Stave Lake Crown Corporation 90,000 No Yes 1912
Strathcona BC Hydro Campbell River Crown Corporation 64,000 No Yes 1958
Wahleach BC Hydro Wahleach Lake Crown Corporation 63,000 No Yes 1952
Whatshan BC Hydro Wahleach Lake Crown Corporation 54,000 No Yes 1972
Total 10,720,610
Table 5. Earth Energy Installations
Name Company Location Type of Business Electrical Capacity (kW)
Purchase Electricity from Grid?
Sell Electricity to Grid?
Thermal Capacity (kW)
Start Year Eco-certification
100 Mile House Recreation Centre
Canlan Ice Sports Corporation
100 Mile House
Recreational Facility
773.784 2002
Airport Hangar Campbell River
Campbell River
70.344 2004
APEG Building Association of Professional Engineers
Burnaby Office Building 246
Art Holdings Area Icekube Systems Chase Recreational Facility
562.752 1999
Beaver Flats Whistler 2002
Blue River Resort Mike Wiegele Helicopter Skiing
Blue River Hotel
Bob McMath Secondary School
Bob McMath Secondary School
Richmond School 1997
Bow Mel Chrysler Duncan 87.93 2004
Brentwood College Mill Bay College 246.204 2002
Burnaby Mountain Secondary
Burnaby School
Caper’s Building Kalico Developments Ltd. & Salt Lick Projects Ltd.
Vancouver Real Estate Developer
Yes 739 1993
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Name Company Location Type of Business Electrical Capacity (kW)
Purchase Electricity from Grid?
Sell Electricity to Grid?
Thermal Capacity (kW)
Start Year Eco-certification
Ciele Condominum Vancouver
City of Vancouver Works Building
Vancouver 175.86 2004
Copcan Contracting Nanaimo 123.102 2002
Cornerstone Building Burnaby 120 2004
Discovery Bay Resort Kelowna 2321.352 2002
First Lutheran Church Kelowna 211.032 2002
Gleneagles Community Centre
District of West Vancouver Vancouver Community Centre 2003
Gulf Islands Secondary School
Gulf Islands Secondary School
Salt Spring Island
School 1993
Heritage Woods Secondary School
Port Moody
School 298.962 2004
Ice Box Arena Icekube Systems Kamloops Recreational Facility
562.752 1999
Ice Box Arena Icekube Systems Kamloops Recreational Facility
281.376 2000
Kitsilano Condo Development
Kitsilano 527.58 1993
Landmark Technology Centre
Stober Construction Kelowna Office Complex
Living Waters Church Fort Langley
70.344 2002
Mission Centre Office Icekube Systems Kelowna Recreational Facility
506.4768 2003
Nature Centre Masset 17.586 2002
Nestor School Coquitlam School 140.688 2000
Nicola Valley Arena Icekube Systems Merritt Recreational Facility
562.752 2001
Ocean Farms Duncan 70.344
Oliver Curling Club Oliver Curling Club Oliver Recreational Facility
1994
Pacific Agrifood Research Centre
Agriculture and Agri-Foods Canada
Agassiz Research Institution
Pacific Gardens Nanaimo
Pacific Sands Beach Tofino 316.548 2004
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Name Company Location Type of Business Electrical Capacity (kW)
Purchase Electricity from Grid?
Sell Electricity to Grid?
Thermal Capacity (kW)
Start Year Eco-certification
Resort
Peace Arch Visitors Centre
Surrey
Poet’s Cove South Pender Island
2003
Quarry Stone Lakeside Villas
Mara 119.5848 2003
Rockridge Canyon Youth Camp
Princeton 140.688 2004
Rutland Elementary School
Rutland Elementary School Kelowna School
S.F.Home Kalico Developments Ltd. & Salt Lick Projects Ltd.
Real Estate Developers
Salt Spring Elementary School
Salt Spring Island
School 105.516 2001
Saturna Island Community Centre
Saturna Island
Community Centre 105.516 2004
Seaview School Coquitlam 105.516 2000
Serene Lea Farms Mara 140.688 2003
Shoal Point, Fisherman’s Wharf
Victoria 2003
Sk’Elp School of Excellence
Kamloops Indian Band Kamloops 2002
Spruce Grove Field House
Resort Municipality of Whistler
Whistler Government 2000
Sto-Lo Nation Medical Building
Chilliwack 105.516 2004
Sun Rivers Golf Resort Sun Rivers Golf Resort Kamloops 2004
Sundance Lodge Resort Kelowna 703.44 2004
Tekmar Control Systems Ltd.
Tekmar Control Systems Ltd.
Vernon Factory
Telkwa Faith Reformed Church
Telkwa Church 211.032 2003
Total 10,770.27
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Table 6. Low Impact Hydro Facilities
Name Company Location Type of Business Electrical Capacity (kW)
Purchase Electricity from Grid?
Sell Electricity to Grid?
Thermal Capacity (kW)
Start Year
Eco-certification
Aberfeldie BC Hydro Bull River Crown Corporation 5,000 No Yes 1922
Akolkolex Canadian Hydro Developers Inc.
Revelstoke Diversified Electricity Generator
10,000 No Yes 1995 ECP Eco-Logo
Bonnington Falls Generating Station
Nelson, Corp of the City of
Kootenay River Integrated Electric Utility 15,350 Yes No 1905 Environmental Choice Program, Eco-Logo, 1999
Boston Bar Generating Station
Algonquin Power Income Fund
Scuzzy Creek Hydro Site Managers 7,200 Yes Yes 1995
Brilliant Columbia Power Corp.
Kootenay River Renewable Electricity Generator
149,000 No No 1943
Brown Lake EPCOR Generation Inc.
Prince Rupert Electricity Generation 7,000 1996
Clayton Falls BC Hydro Clayton Falls Crown Corporation 2,000 No Yes 1961
Eagle Lake Micro Hydro at C2 Reservoir
Pacific Cascade Hydro Inc. & District of West Vancouver
West Vancouver Municipality 200 Yes Yes 2003 BC Hydro Green Certified, 2003
Elko Plant BC Hydro Elk River Crown Corporation 12,000 No Yes 1924
Hluey Lake Hydro Project
Regional Power Dease Lake Renewable Electricity Generator
200 Yes Yes 2003 Environmental Choice Certified
Hystad and East Twin Creek
East Twin Creek Hydro Ltd.
Valemount Renewable Electricity Generator
6,000 Yes Yes 1989 B.C. Hydro Green Certified, 2002
Lower Bonnington FortisBC Kootenay River Utility 49,500 No No 1925
Mamquam TransCanada Energy
Mamquam River Renewable Electricity Generator
50,000 1996
Miller Creek EPCOR Generation Inc.
Pemberton Electricity Generation 29,500 2003
Peace Canyon BC Hydro Peace River Crown Corporation 694,000 No Yes 1980
Pingston Creek Canadian Hydro Developers Inc.
Revelstoke Renewable Electricity Generator
45,000 No Yes 2003 BC Hydro Green Certified
Puntledge BC Hydro Puntledge River Crown Corporation 24,000 No Yes 1955
Purcell Mountain Lodge Purcell Mountain Lodge
Purcell Mountain Lodge
Lodge 15 1992
Raging River Raging River Power Port Alice Mining and Energy Company 1,750 Yes Yes 2002 BC Hydro Green
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Name Company Location Type of Business Electrical Capacity (kW)
Purchase Electricity from Grid?
Sell Electricity to Grid?
Thermal Capacity (kW)
Start Year
Eco-certification
and Mining Inc IPP, 2003
Rutherford Creek Innergex Inc. Pemberton
Sechelt Clean Power Income Fund
Sechelt Creek Renewable Electricity Generator
16,000 Yes Yes 1997 Environmental Choice Certified
South Slocan FortisBC Kootenay River Utility 53,100 No No 1928
Spillimacheen BC Hydro Spillimacheen River
Crown Corporation 4,000 No Yes 1955
Upper Bonnington FortisBC Kootenay River Utility 61,630 No No 1907
Upper Mamquam Canadian Hydro Developers Inc.
Squamish 2005
Walden Hydro Plant BC Hydro Lillooet Crown Corporation 16,000 No No 1974
Walter Hardman BC Hydro Cranberry Creek Crown Corporation 8,000 No Yes 1960
Waneta Generating Station
Columbia Power Corporation
Pend d'Oreille River
1952
Wilsey dam BC Hydro Shuswap River Crown Corporation 1929
TOTAL 1,269,245
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Table 7. Biomass — Wood Residue Facilities
Name Company Location Type of Business Electrical Capacity (kW)
Purchase Electricity from Grid?
Sell Electricity to Grid?
Thermal Capacity (kW)
Start Year
Eco-certification
Armstrong Tolko BC Armstrong Pulp and Paper Company 20,000 Yes Yes 2000
Campbell River Norske Canada Campbell River Pulp and Paper Company 25,000 Yes No
Celgar Celgar Pulp Co. Castlegar Pulp and Paper Company 49,400 Yes Yes 325,667 1960
Chetwynd Tembec Inc. Chetwynd Pulp and Paper Company 1980
Crofton Norske Canada Crofton Pulp and Paper Company 38,000 Yes No 1981
Fraser Flats Canadian Forest Products
Prince George Pulp and Paper Company 45,428 Yes No 1973
Golden EWP Division Louisiana-Pacific Engineered Wood
Golden Pulp and Paper Company 7,000 Yes Yes 18,375 1936
Harmac Pope and Talbot Inc.
Nanaimo Pulp and Paper Company 27,300 283,414 1963
Kelowna Tolko BC Kelowna Pulp and Paper Company 12,000 Yes 32,250 1948
Mackenzie Abitibi Consolidated Inc.
Mackenzie Pulp and Paper Company 11,120 No No 224,800 1997
Port Alberni Norske Canada Port Alberni Pulp and Paper Company 17,680 Yes No 93,432 1963
Port Alice Western Pulp Ltd. Port Alice Pulp and Paper Company 19,200 Yes 170,400 1949
Powell River Norske Canada Powell River Pulp and Paper Company 25,000 Yes Yes 1910
Pulp Mill Norske Skog Canada Ltd.
Quesnel Plywood Quesnel Plywood Quesnel Forestry 29,024 Yes 20,517 1972
Western Manufacturing Division
Scott Paper Ltd. (Kruger)
New Westminster
Pulp and Paper Company 14,000 Yes No 11,389 1950
Western Pulp Ltd. Western Pulp Ltd. Woodfibre 7,000 1947
Williams Lake TransCanada Power LP
Williams Lake Diversified Electricity Generator
72,000 Yes Yes 1993
Total 419,152 1,181,743.9
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Table 8. Biomass — Other Facilities
Name Company Location Type of Business Electrical Capacity (kW)
Purchase Electricity from Grid?
Sell Electricity to Grid?
Thermal Capacity (kW)
Start Year
Eco-certification
EYA-UBC Biodiesel Project
Environmental Youth Alliance / UBC
Vancouver Non-Profit / Academic 11,120 2002
Neoteric Biofuels Inc. Westbank
Total
Table 9. Standard Hydro Facilites
Name Company Location Type of Business Electrical Capacity (kW)
Purchase Electricity from Grid?
Sell Electricity to Grid?
Thermal Capacity (kW)
Start Year
Eco-certification
Klemtu Hydro project Kitasoo First Nation Klemtu First Nation Government 620 1981
Mears Creek Synex Energy Resources Ltd.
Gold River Diversified Electricity Generator
3,800 BC Hydro Green IPP
Ocean Falls Central Coast Power Corp.
Link Lake Renewable Electricity Generator
12,200 1917
Port Alice Western Pulp Ltd. Victoria Lake Pulp and Paper Company 2,000 1953
Tennant Lake NVI Mining Ltd. Tennant Lake Mining Company 3,060 1966
Thelwood Hydro NVI Mining Ltd Thelwood Lake Mining Company 8,200 1985
Waneta Teck-Cominco Metals
Pend D'Oreille River
Mining Company 337,700 Yes 1954
Woodfibre Western Pulp Ltd. Henrietta Lake Pulp and Paper Company 2,587 1947
Total 370,167
University of VictoriaPO Box 1700 STN CSCVictoria, BC V8W 2Y2
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