Energy Balances of OECD Countries 2011€¦ · Yugoslavia in the publication Energy Balances of Non-OECD Countries. Several factors explain this high consumption: e.g. an electrification

I E A S T A T I S T I C S

ENERGY BALANCESOF OECD COUNTRIES

InternationalEnergy Agency

2011E D I T I O N

ENERGY BALANCESOF OECD COUNTRIES

2011E D I T I O N

INTERNATIONAL ENERGY AGENCY

The International Energy Agency (IEA), an autonomous agency, was established in November 1974. Its primary mandate was – and is – two-fold: to promote energy security amongst its member countries through collective response to physical disruptions in oil supply, and provide authoritative

research and analysis on ways to ensure reliable, affordable and clean energy for its 28 member countries and beyond. The IEA carries out a comprehensive programme of energy co-operation among its member countries, each of which is obliged to hold oil stocks equivalent to 90 days of its net imports. The Agency’s aims include the following objectives:

n Secure member countries’ access to reliable and ample supplies of all forms of energy; in particular, through maintaining effective emergency response capabilities in case of oil supply disruptions.

n Promote sustainable energy policies that spur economic growth and environmental protection in a global context – particularly in terms of reducing greenhouse-gas emissions that contribute to climate change.

n Improve transparency of international markets through collection and analysis of energy data.

n Support global collaboration on energy technology to secure future energy supplies and mitigate their environmental impact, including through improved energy

efficiency and development and deployment of low-carbon technologies.

n Find solutions to global energy challenges through engagement and dialogue with non-member countries, industry, international

organisations and other stakeholders.IEA member countries:

Australia Austria

Belgium Canada

Czech RepublicDenmark

FinlandFrance

GermanyGreece

HungaryIreland

ItalyJapan

Korea (Republic of)LuxembourgNetherlandsNew Zealand NorwayPolandPortugalSlovak RepublicSpainSwedenSwitzerlandTurkeyUnited Kingdom

United States

The European Commission also participates in

the work of the IEA.

Please note that this publication is subject to specific restrictions that limit its use and distribution.

The terms and conditions are available online at www.iea.org/about/copyright.asp

© OECD/IEA, 2011International Energy Agency

9 rue de la Fédération 75739 Paris Cedex 15, France

www.iea.org

ENERGY BALANCES OF OECD COUNTRIES (2011 Edition) - iii


TABLE OF CONTENTS INTRODUCTION ........................................................................................................................................... v

OECD ENERGY TRENDS ................................................................................................................... vii

PART I: METHODOLOGY 1. Explanatory notes ............................................... I.3 2. Units and conversions ....................................... I.11

3. Country notes .................................................... I.15 4. Geographical coverage ...................................... I.35

PART II: STATISTICAL DATA COUNTRY-SPECIFIC NET CALORIFIC VALUES .............................................................................. II.3

ENERGY BALANCE SHEETS AND ENERGY INDICATORS OECD Total .......................................................... II.14 OECD Americas .................................................... II.18 OECD Asia Oceania ............................................. II.22 OECD Europe ....................................................... II.26 International Energy Agency ................................ II.30 Australia ................................................................ II.34 Austria ................................................................... II.38 Belgium ................................................................. II.42 Canada ................................................................... II.46 Chile ...................................................................... II.50 Czech Republic ..................................................... II.54 Denmark ................................................................ II.58 Estonia ................................................................... II.62 Finland .................................................................. II.66 France .................................................................... II.70 Germany ................................................................ II.74 Greece ................................................................... II.78 Hungary ................................................................. II.82 Iceland ................................................................... II.86 Ireland ................................................................... II.90

Israel ..................................................................... II.94 Italy ....................................................................... II.98 Japan ................................................................... II.102 Korea .................................................................. II.106 Luxembourg ....................................................... II.110 Mexico ................................................................ II.114 Netherlands ......................................................... II.118 New Zealand ....................................................... II.122 Norway ............................................................... II.126 Poland ................................................................. II.130 Portugal............................................................... II.134 Slovak Republic .................................................. II.138 Slovenia .............................................................. II.142 Spain ................................................................... II.146 Sweden ............................................................... II.150 Switzerland ......................................................... II.154 Turkey................................................................. II.158 United Kingdom ................................................. II.162 United States ....................................................... II.166

SUMMARY TABLES Production ........................................................... II.172 Net imports .......................................................... II.182 Primary energy supply ........................................ II.187 Electricity generation .......................................... II.191 Final consumption ............................................... II.198 Industry consumption .......................................... II.203 Consumption in transport .................................... II.208 Other consumption .............................................. II.211

GDP .................................................................... II.215 Population ........................................................... II.217 Energy production/TPES .................................... II.218 TPES/GDP .......................................................... II.219 TPES/population ................................................. II.221 Index of industry consumption / Industrial production ........................................... II.222

RENEWABLE ENERGY AND WASTE Contribution from renewable energies and energy from waste ................................................................... II.224-262

iv - ENERGY BALANCES OF OECD COUNTRIES (2011 Edition)


What’s New? Starting with this year’s edition, the countries Chile, Estonia, Israel and Slovenia, which joined the OECD in 2010, have been incorporated into this publication. All are included in OECD totals. The regional aggregate OECD North America has been changed to OECD Americas and now includes Chile. OECD Pacific has been changed to OECD Asia Oceania and now includes Israel. OECD Europe now includes Estonia and Slovenia starting in 1990. Prior to 1990, data for Estonia are included in Former Soviet Union and data for Slovenia in Former Yugoslavia in the publication Energy Balances of Non-OECD Countries.

The IEA is currently working with a group of 24 international organisations that collect or use energy statistics. The purpose of this group, called InterEnerStat, is to improve the quality of energy data and reduce the reporting burden by harmonising definitions for energy sources and flows. As a result of this work, the IEA will now in-clude gas works gas with coal instead of including it with natural gas.

In line with the InterEnerStat work, the IEA has also made some small changes in the terminology that do not af-fect the definitions. A few examples include:

combustible renewables and waste becomes biofuels and waste solid biomass becomes solid biofuels liquid biomass becomes liquid biofuels biogas becomes biogases

ENERGY BALANCES OF OECD COUNTRIES (2011 Edition) - v


INTRODUCTION An analysis of energy problems requires a compre-hensive presentation of basic statistics in original units such as tonnes of coal and kilowatt hours of electric-ity. This type of presentation is published in Energy Statistics of OECD Countries, the sister volume to this publication. The usefulness of such basic data can be considerably improved by expressing them in a com-mon unit suitable for uses such as estimation of total energy supply, forecasting and the study of substitu-tion and conservation. The energy balance is a presentation of the basic supply and demand data for all fuels in a manner which shows the main fuels to-gether but separately distinguished and expressed in a common energy unit. Both of these characteristics will allow the easy comparison of the contribution each fuel makes to the economy and their interrela-tionships through the conversion of one fuel into another.

Energy data on OECD countries are collected from member countries by the team in the Energy Statistics Division (ESD) of the IEA Secretariat, headed by Jean-Yves Garnier. The IEA would like to thank and acknowledge the dedication and professionalism of the statisticians working on energy data in the countries. Within the IEA, electricity, coal and renew-

able statistics are the responsibility of Robert Schnapp with the help of Yasmina Abdelilah on electricity, Tomasz Truś on coal and Wendy Chen on renewables. Oil and natural gas statistics are the responsibility of Mieke Reece with the help of Tianlai Xu on oil and Laura Thomson on natural gas. Jung-Ah Kang, Julian Smith and Ryszard Pośpiech also contributed to the processing of country statistics. Karen Tréanton, with the help of Alex Blackburn, Frederic Genest and Davide D’Ambrosio, has overall production and edi-torial responsibility. Desktop publishing was carried out by Sharon Burghgraeve.

Data from 1960 to 2009 and selected estimates for 2010 are available on CD-ROM suitable for use on IBM-compatible personal computers.

In addition, a data service is available on the internet. It includes unlimited access through an annual subscription as well as the possibility to obtain data on a pay-per-view basis. Details are available at http://www.iea.org.

Enquiries about data or methodology should be addressed to Karen Tréanton:

Telephone: (+33-1) 40-57-66-33, E-mail: [email protected].

ENERGY BALANCES OF OECD COUNTRIES (2011 Edition) - vii


OECD ENERGY TRENDS One of the highlights of the OECD situation in 2010 is the 3.3% rebound of total primary energy supply (TPES) after the dramatic 4.4% decrease in 2009. After the financial crisis and slowdown in economic activity in 2008-2009, the OECD energy supply in-creased in 2010 to 5413 Mtoe, just below 2008 levels, but well below the peak of 5553 Mtoe in 2007.

The OECD in the world

In 2009, 18% of the world population lived in the OECD, while 75% of the world GDP was created in its 34 member countries.1 The TPES of the OECD in 2009 represented about 44% of global energy supply, while the total energy production of the OECD ac-counted for 31% of the global energy production.

Table 1. OECD in the world, 2009

Population (millions)

GDP* TPES (Mtoe)

Production (Mtoe)

OECD 1 225 29 633 5 238 3 807 World** 6 761 39 674 11 795 12 272 OECD share**

18% 75% 44% 31%

* (billion USD, 2000 prices and exchange rates) ** preliminary figures

In terms of TPES/population, with 4.3 toe per capita (compared to a world average of 1.7 toe per capita), the OECD is the most energy-intensive region.

1. Starting with this year’s edition, the countries Chile, Estonia, Israel and Slovenia, which joined the OECD in 2010, have been incorporated into this publication. All are included in OECD totals. The regional aggregate OECD North America has been changed to OECD Americas and now includes Chile. OECD Pacific has been changed to OECD Asia Oceania and now includes Israel. OECD Europe now includes Estonia and Slovenia starting in 1990. Prior to 1990, data for Estonia are included in Former Soviet Union and data for Slovenia in Former Yugoslavia in the publication Energy Balances of Non-OECD Countries.

Several factors explain this high consumption: e.g. an electrification rate of almost 100%, a high rate of cars per household, large industry and service sectors, high heating degree-days and a high GDP per capita.

In contrast, in terms of TPES/GDP, with 0.18 toe per thousand USD2 (compared to a world average of ap-proximately 0.30 toe per thousand USD), the OECD is the least energy-intensive region. Several factors also explain the lower consumption: high GDP compared to other regions, high efficiency in trans-formation processes (especially power plants), high efficiency in final consumption (efficient cars, insula-tion of houses) and delocalisation of high energy-consuming industries.

In 2010, the OECD produced 3 889 Mtoe of primary energy while its total primary energy supply was 5 413 Mtoe. As a consequence, 28% of the energy consumed by the OECD in 2010 (the energy depend-ency) had to be imported from non-OECD countries.

The following paragraphs highlight the main changes since 1971 as well as giving a snapshot of the situation in 2010 for supply and in 2009 for consumption.

Production

After dipping in 2009, OECD primary energy produc-tion increased by 2.2% to 3 889 Mtoe in 2010. This is the highest level of energy production since the founding of the International Energy Agency (IEA) in 1974 and represents a 65.1% increase compared to 1971 (i.e. an annual average growth of 1.3% over the 39-year period).

When analysing changes in the OECD energy situa-tion, it is interesting to break the 39-year period into

2. 2000 prices and exchange rates.

viii - ENERGY BALANCES OF OECD COUNTRIES (2011 Edition)


two parts (1971-1990 and 1990-2010), since 1990 is the reference year for the Kyoto Protocol. The in-crease in production was not uniform over the timeframe, with a much stronger growth in the first half of the period (2.0% per year) compared to the second half (0.6% per year). The comparative annual growth for each of the fuels shows similar trends, i.e. a much higher growth in the first part of the period (see Figure 1). The exceptions to this are natural gas, which experienced stronger growth in the second part of the period, and biofuels and waste, which saw simi-lar growth rates for both parts of the period.

After the first oil shock in 1973 and the establishment of the IEA, a special effort was made by most of the OECD countries to reduce their dependence on im-ported oil by various policies, including the development of alternative sources of energy, and for some of them, by exploiting their oil reserves.

Figure 1. Average annual growth rates in OECD primary energy production

Within 15 years, the launch of large nuclear pro-grammes in several countries and the exploitation of new open-sky mines in OECD Americas led to a dra-matic increase of nuclear and coal production. In 1971, nuclear represented 27 Mtoe whereas in 1990 it ac-counted for 451 Mtoe. Similarly coal went up from 814 Mtoe in 1971 to 1 073 Mtoe in 1990. These in-creases, combined with the increase in oil production (especially in the Gulf of Mexico, Norway and the United Kingdom) from 693 to 923 Mtoe, explain the relatively high growth in energy production observed in the first half of the 39-year period.

During the second half of the period (from 1990 to 2010), the situation was significantly different. Oil production in the OECD as a whole peaked in 1997, and has been decreasing steadily since then. Oil pro-duction in the United Kingdom and Norway reached maximum levels in 1999/2000 whereas Mexico oil

production peaked in 2005. On the other hand, oil production for Canada in increasing and reached its highest level in 2010. Coal production in the OECD also decreased by 6.5% during this period due to the closing of high-cost deep mines in OECD Europe and OECD Asia Oceania. On the other hand, nuclear con-tinued to rise at a steady rate, going from 451 Mtoe in 1990 to 615 Mtoe in 2006 before dropping slightly between 2007 and 2009 and increasing to 596 Mtoe in 2010. In addition, the discovery and exploitation of large natural gas fields in OECD Americas led to a major increase in natural gas production from 718 Mtoe in 1990 to 967 Mtoe in 2010.

As a consequence of the contrasting evolution of the various fuels over the period, the shares of the main fuels in total production changed significantly be-tween 1971 and 2010 (see Figure 2).

In 2010, the share of fossil fuels in total OECD pro-duction accounted for 73.7%; coal, oil and natural gas represented roughly one quarter of production each. Nuclear accounted for 15.3%, a large increase from 1.2% in 1971.

Figure 2. Fuel shares in OECD production

1971 2010

Energy from renewables and waste represented 11.0% in 2010; biofuels and waste contributed for more than one half, hydro for more than one quarter and geother-mal energy accounted for most of the rest. Biofuels and waste grew more rapidly than hydro and geothermal, with a growth of 5.2% between 2009 and 2010.

As regards the other forms of renewable energy, their production started to grow steadily in recent years, although their shares remain limited. For example, solar and wind energy have experienced high annual growth since 1990, with a growth of 15.3% alone be-tween 2009 and 2010. However, their combined production still only accounted for 0.8% of total pri-mary energy production in 2010.

-6%

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Biofuels /waste3.5% Other

0.2%

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25.8%

Oil 23.0%

Gas 24.9%

Nuclear 15.3%

Hydro 3.0%

Biofuels /waste6.4% Other

1.6%

ENERGY BALANCES OF OECD COUNTRIES (2011 Edition) - ix


Trade

Preliminary data for 2010 show that OECD net im-ports remained fairly constant in 2010 after a 9.5% decrease in 2009, the largest yearly decrease since the early 1980s, which was due to the economic crisis in 2008/2009.

In 1971, 98.3% of the 1 145 Mtoe of total net imports of energy for the OECD were related to oil; net im-ports were equivalent to nearly half of the OECD energy production. The policies taken by OECD member countries in order to reduce their dependence on imported oil had twofold consequences for the pe-riod 1971-1985: • a decrease in net imports of oil from 1 461 Mtoe in

1977 to 804 Mtoe in 1985; • a decrease in the share of oil imports in total net

imports (from 98.3% in 1971 to 88.4% in 1985).

The fall of oil prices in the mid 1980s had an impact on the historical trend of OECD energy trade. Net imports of oil in the OECD started to increase again in 1986, growing on average by 2.4% per year between 1986 and 2005. In 2005, net imports of oil peaked at 1 425 Mtoe before declining to 1 238 Mtoe in 2009. In 2010, net oil imports remained stable at 1 239 Mtoe.

On the other hand, volatility of oil prices, increasing performance of natural gas-fired power plants, fuel switching for heating purposes and a growing interest in the use of natural gas for its lower CO2 emissions led to a steady increase of net imports of natural gas. After decreasing by 3.6% in 2009, net imports of natural gas rose by 9.5% between 2009 and 2010. This reduced the share of oil in total energy imports to 74.6% in 2010.

Figure 3. Net imports of primary energy by fuel for the OECD

Total primary energy supply

After falling in 2008 and 2009, OECD’s TPES in-creased by 3.3% in 2010. In 2010, the share of fossil fuels in TPES was 81.0%, almost constant from the all-time low of 80.9% in 2009. This compares to a share of 94.4% in 1971. Despite the policies taken after the first oil supply shock to reduce the depend-ency on oil, oil remains the largest component of TPES in the OECD. However, its share has decreased from 50.6% in 1971 to 36.3% in 2010 (see Figure 4).

Figure 4. Fuel shares in TPES for the OECD*

1971 2010

* Includes electricity trade.

Although efforts have been made to reduce the use of oil in sectors where it can be substituted by other fu-els, e.g. electricity production, the growing demand in “captive” sectors such as transport explains why the share of oil remains the highest amongst all energy sources.

The share of coal and peat in total TPES was 24.3% in 1971 and decreased to 20.2% in 2010. In the last dec-ade, coal was partly replaced by natural gas, notably for electricity generation. Natural gas was the only fossil fuel with increasing shares in the last 39 years (from 19.5% in 1971 to 24.5% in 2010) and became the second fuel in the OECD starting in 1999.

The share of nuclear energy in OECD TPES grew from 0.8% in 1971 to 11.3% in 2001, falling slightly to 11.0% in 2010. The development of nuclear energy was particularly intense between 1971 and 1990, with an average growth of 16.0% per year. Since then, the development of nuclear energy has slowed, with a growth of 1.4% per year.

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Nuclear 11.0%

Hydro 2.1%

Other5.9%

x - ENERGY BALANCES OF OECD COUNTRIES (2011 Edition)


Figure 5. Share of fossil fuels and nuclear in OECD TPES

Although hydro energy increased from 76 Mtoe in 1971 to 115 Mtoe in 2010, the share of hydro in TPES remained constant at around 2%.

The impact of other alternative energy sources grew from 2.6% in 1971 to 5.9% in 2010. Within this cate-gory, solid biofuels (including wood, wood wastes, charcoal and other solid biofuels) was the largest con-tributor and represented 3.0% of total TPES. Geothermal energy (including both direct use and en-ergy used for electricity generation) contributed 0.6% to TPES while wind contributed 0.4%. Due to recent efforts in OECD countries to increase the amount of biofuels blended in transport fuels, biogasoline repre-sented 0.5% and biodiesels represented 0.2% of total TPES in 2010. Small amounts also came from other liquid biofuels, biogases, municipal waste, industrial waste, solar and tide/wave/ocean.

Figure 6. OECD TPES by fuel

TPES rose from 3 372 Mtoe in 1971 to 5 553 Mtoe in 2007 before falling to 5 238 Mtoe in 2009 and re-bounding to 5 413 Mtoe in 2010. With an annual average rate of growth of 1.2% per year since 1971, this growth was less than half that of the growth in GDP observed for the OECD over the same period.

As a consequence, energy intensity (TPES/GDP) fell from 0.31 toe per thousand USD in 1971 to 0.18 toe per thousand USD in 2006 and has remained constant since then.

Figure 7. TPES/GDP in the OECD

Energy dependency, defined as the fraction of TPES not supplied by OECD production, is strongly influ-enced by the evolution of OECD oil production and imports. Energy dependency of total OECD was 30.2% in 1971 and peaked in 1976 at 34.9%, when the increase in oil production in Norway and the United Kingdom had not yet started. Energy dependency de-clined sharply after 1979, when an increasingly large part of the oil imports started to be replaced by do-mestic production.

In the following years the trend of energy dependency was mainly influenced by the variations of OECD oil production (and imports), but it was smoothed by the increasing weight of other energy sources. As a result, energy dependency grew slowly between 1985 and 2007, when it was back to 1971 levels. In 2008 and 2009 lower demand in the OECD countries caused the energy dependency to fall from 30.5% to 27.3% in two years, before increasing again to 28.2% in 2010.

Figure 8. Energy dependency in the OECD

0%

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1971 1975 1980 1985 1990 1995 2000 2005 2010

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ENERGY BALANCES OF OECD COUNTRIES (2011 Edition) - xi


Electricity generation

Electricity generated in the OECD increased 3.5% in 2010, just below the all-time high of 2008. Elec-tricity generation on average increased by 2.7% per year since 1971, twice as fast as TPES but at a rate comparable to the growth in GDP. Total generation, including the part from CHP, amounted to 10 772 TWh in 2010.

The fuels used for electricity production changed sig-nificantly over time and, as for TPES, the trend in the fuel mix was affected by oil prices and the energy policies of OECD member countries.

Figure 9. GDP, TPES and electricity output in the OECD

Power generation is the sector where the efforts to reduce dependency on oil found their best ground. Oil accounted for 21.7% of the electricity production in 1971, but its share was reduced to 2.8% in 2010. Most of the decline occurred in the late 1970s and in the early 1980s.

Figure 10. Electricity generation by fuel in the OECD

On average, electricity from coal and peat increased by 2.3% per year after 1971, but its growth was weaker after 1990 (1.0% per year, on average), espe-cially because of the increasing use of natural gas in power generation. In 2010 the share of coal and peat was 34.7%, as compared to 39.4% in 1971.

Natural gas accounted for 13.0% of OECD electricity production in 1971. The share of natural gas in elec-tricity decreased until the late 1980s and reached its minimum in 1988, when natural gas-fired power plants contributed only 8.4% of the total electricity output. Technological improvements (highly efficient gas turbines and combined cycle plants), low CO2 emissions and relatively low prices reversed the trend and allowed natural gas to gain in importance during the 1990s. Outputs from natural gas-fired power plants reached 23.4% in 2010.

The share of hydro decreased dramatically from 22.9% in 1971 to 12.4% in 2010, despite an increase in abso-lute terms, since most of the possible sites for large hydro production had already been equipped by 1971.

Figure 11. Fuel shares in OECD electricity output

1971 2010

* Includes other renewables and waste

The development of nuclear energy has been extremely important in electricity generation. Nuclear power rep-resented over one-fifth of the total electricity output in 2010, while its share was less than 3% in 1971.

Other energy sources gave a limited contribution to electricity generation in 2010. Biofuels and waste rep-resented 2.3% of total output. Although wind electricity grew by 23.4% per year between 1990 and 2010, it did not exceed 2.4% of the total output gener-ated in OECD countries. However, for the first time in 2001, wind accounted for more electricity generation than geothermal.

The overall efficiency of electricity generation improved over time, but less than might have been expected given that new power stations were built. The increase

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Other*0.3%

Coal/peat

34.7%

Oil 2.8%

Gas 23.4%

Nuclear 21.2%

Hydro 12.4%

Other*5.5%

xii - ENERGY BALANCES OF OECD COUNTRIES (2011 Edition)


was due to technical improvements, especially in combined cycles. However, the primary energy from nuclear (obtained from traditional cycles with an effi-ciency close to 33%) and the weight of nuclear in total electricity production offset the gain in the overall efficiency of power plants.

The fraction of TPES consumed for electricity and heat generation increased significantly between 1971 and 2009. The reasons behind such an increase can be found in the transition of OECD economies from industry to services (which are more electricity-intensive than industry), in the growing use of elec-tric-intensive technologies and in the growing share of electricity consumption (with respect to other energies) in industry, commercial/public services and residential.

Total final consumption

OECD total final consumption (TFC) of energy ac-counted for 3 582 Mtoe in 2009, 5.8% lower than the peak in 2007. However, preliminary information show an increase of TFC in 2010 although final data are not yet available. In 2009, TFC represented more than two-thirds of TPES. On average, TFC has increased by 0.9% per year since 1971, one-third that of the GDP growth for the OECD.

Trends were not homogeneous amongst energy sources. End-use of coal tended to decrease in all sec-tors, while oil consumption was heavily affected by the high oil prices in the mid 1970s and early 1980s and declined in all non-captive sectors. Natural gas increased by 1.2% per year from 1971 to 2009 while electricity doubled its share in TFC over the same period.

Despite all the efforts made to reduce the oil depend-ency of OECD countries, transport has always been a captive sector for oil, which accounted for 94.4% of transport consumption in 2009 compared to 95.0% in 1971.

Moreover, the weight of transport in TFC increased between 1971 and 2009 due to the rising number of vehicles, the tendency to use larger engines, the high use of road transport in trading goods and the relative decrease of the use of oil in other sectors. In 2009, transport was about one-third of the total final con-sumption, while it only accounted for a quarter in 1971.

Figure 12. TFC by fuel and by sector in the OECD

Industry, residential and services also increased their consumption, but at lower rates. In addition, natural gas and electricity started to substitute consumption of oil and coal in these sectors.

The share of coal in industry dropped from 17.8% in 1971 to 8.3% in 2009; it went down from 16.9% to 2.3% in residential. The oil share in commercial/public services represented 45.9% of consumption in 1971 and fell to 14.0% in 2009. Similarly, the oil share declined from 35.3% to 13.4% in residential.

Final consumption of electricity fell by 4.1% between 2007 and 2009. This was the first time since 1982 that electricity consumption went down. Indeed on aver-age, driven by the development of electricity-intensive technologies (electronics, robotics, etc.), total final consumption of electricity grew by 2.7% a year be-tween 1971 and 2009. The greatest increases concerned commercial/public services (4.2%) and residential (3.1%). The growth of natural gas was more moderate, with an increase of 1.2% per year, and mainly concerned residential and commercial/public services, with a joint average increase of 1.9% during the 38-year period. Use of natural gas in agri-culture and road increased significantly, but both sectors started from very low bases.

Use of other energy sources (mainly biofuels) was limited to certain industrial activities (paper, pulp, wood and wood products) and to residential, although the share in transport is growing as a result of recent policies in OECD countries to increase the fraction of biogasoline and biodiesels in transport fuels. The share of biofuels and waste in total final consumption was 4.7% in 2009.

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ENERGY BALANCES OF OECD COUNTRIES (2011 Edition) - I.1


PART I

METHODOLOGY

MULTILINGUAL GLOSSARIES See multilingual glossary at the end of the publication.

Voir le glossaire en plusieurs langues à la fin du présent recueil. Deutsches GLOSSAR auf der letzten Umschlagseite. Riferirsi al glossario multilingue alla fine del libro.

巻末の日本語用語集を参照 Véase el glosario plurilingüe al final del libro.

—ÏÓÚËÚÂ ÏÌÓ„ÓˇÁ˚˜Ì˚È ÒÎÓ‚‡¸ ‚ ÍÓÌˆÂ ÍÌË„Ë.

I.2 - ENERGY BALANCES OF OECD COUNTRIES (2011 Edition)


ABBREVIATIONS

Btu: British thermal unit GWh: gigawatt hour kcal: kilocalorie kg: kilogramme kJ: kilojoule Mt: million tonnes m3: cubic metre t: metric ton = tonne = 1000 kg TJ: terajoule toe: tonne of oil equivalent = 107 kcal CHP: combined heat and power GCV: gross calorific value GDP: gross domestic product HHV: higher heating value = GCV LHV: lower heating value = NCV NCV: net calorific value PPP: purchasing power parity TPES: total primary energy supply IEA: International Energy Agency IPCC: Intergovernmental Panel on Climate Change ISIC: International Standard Industrial Classification OECD: Organisation for Economic Co-Operation and Development OLADE: Organización Latinoamericana de Energía UN: United Nations UNIPEDE: International Union of Producers and Distributors of Electrical Energy c confidential e estimated .. not available - nil x not applicable



1. EXPLANATORY NOTES

Unit

The IEA energy balance methodology is based on the calorific content of the energy commodities and a common unit of account. The unit of account adopted by the IEA is the tonne of oil equivalent (toe) which is defined as 107 kilocalories (41.868 gigajoules). This quantity of energy is, within a few per cent, equal to the net heat content of 1 tonne of crude oil. Through-out this publication 1 tonne means 1 metric ton or 1000 kg.

Conversion (from original units to toe)

The change from using the original units to tonnes of oil equivalent implies choosing coefficients of equiva-lence between different forms and sources of energy. This problem can be approached in many different ways. For example, one could adopt a single equiva-lence for each major primary energy source in all countries, e.g. 29 307 kJ/kg (7 000 kcal/kg) for hard coal, 41 868 kJ/kg (10 000 kcal/kg) for oil, etc.

The main objection to this method is that it results in distortions since there is a wide spread in calorific values between types of coal and individual coal products, and between calorific values of these fuels in different countries. The Secretariat has, therefore, adopted specific factors supplied by the national ad-ministrations for the main categories of each quality of coal and for each flow or use (i.e. production, im-ports, exports, electricity generation, coke ovens, blast furnaces and industry).

For crude oil, specific factors have been used for pro-duction, imports and exports based on consultations

with experts from the national administrations. The IEA applies regional conversion factors (in conjunc-tion with Eurostat for the European countries) for the oil products.

Gas data in Energy Statistics of OECD Countries are presented in terajoules on a gross calorific basis. Data on biofuels & waste are presented in terajoules on a net calorific basis (with the exception of liquid biofuels which are in 1000 tonnes).

The balances are expressed in terms of "net" calorific value. The difference between the "net" and the "gross" calorific value for each fuel is the latent heat of vaporisation of the water produced during combus-tion of the fuel. For coal and oil, the net calorific value is about 5% less than gross, for most forms of natural and manufactured gas the difference is 9-10%, while for electricity and heat there is no difference as the concept has no meaning in this case. The use of net calorific value is consistent with the practice of the Statistical Offices of the European Communities and the United Nations.

Electricity data are converted from original units of gigawatt hours to million tonnes of oil equivalent using the relationship: 1 terawatt hour = 0.086 Mtoe.

For more detail on converting to heat units, see Section 2, Units and conversions.

Primary energy conventions

When constructing an energy balance, it is necessary to adopt conventions for primary energy from several sources, such as nuclear, geothermal, solar, hydro, wind, etc. The two types of assumptions that have to be made are described below.



Choice of the primary energy form For each of these sources, there is a need to define the form of primary energy to be considered; for instance, in the case of hydro energy, a choice must be made between the kinetic energy of falling water and the electricity produced. For nuclear energy, the choice is between the energy content of the nuclear fuel, the heat generated in the reactors and the electricity pro-duced. For photovoltaic electricity, the choice is between the solar radiation received and the electricity produced.

The principle adopted by the IEA is that the primary energy form should be the first energy form down-stream in the production process for which multiple energy uses are practical. The application of this prin-ciple leads to the choice of the following primary energy forms:

• Heat for nuclear, geothermal and solar thermal; • Electricity for hydro, wind, tide/wave/ocean and

solar photovoltaic.

Calculation of the primary energy equivalent There are essentially two methods that can be used to calculate the primary energy equivalent of the above energy sources: the partial substitution method and the physical energy content method.

The partial substitution method: In this method, the primary energy equivalent of the above sources of electricity generation represents the amount of energy that would be necessary to generate an identical amount of electricity in conventional thermal power plants. The primary energy equivalent is calculated using an average generating efficiency of these plants. This method has several shortcomings, including the difficulty of choosing an appropriate generating effi-ciency and the fact that the partial substitution method is not relevant for countries with a high share of hydro electricity. For these reasons, the IEA, as most inter-national organisations, has now stopped using this method and adopted the physical energy content method.

The physical energy content method: This method uses the physical energy content of the primary energy source as the primary energy equivalent. As a conse-quence, there is an obvious link between the principles adopted in defining the primary energy forms of energy sources and the primary energy equivalent of these sources.

For instance, in the case of nuclear electricity produc-tion, as heat is the primary energy form selected by the IEA, the primary energy equivalent is the quantity of heat generated in the reactors. However, as the amount of heat produced is not always known, the IEA estimates the primary energy equivalent from the electricity generation by assuming an efficiency of 33%, which is the average of nuclear power plants in Europe.

In the case of hydro and solar PV, as electricity is the primary energy form selected, the primary energy equivalent is the physical energy content of the elec-tricity generated in the plant, which amounts to assuming an efficiency of 100%. A more detailed presentation of the assumptions used by the IEA in establishing its energy balances is given in Section 2.

For geothermal, if no country-specific information is reported, the primary energy equivalent is calculated as follows:

• 10% for geothermal electricity;

• 50% for geothermal heat.

Since these two types of energy balances differ sig-nificantly in the treatment of electricity from solar, hydro, wind, etc., the share of renewables in total en-ergy supply will appear to be very different depending on the method used. As a result, when looking at the percentages of various energy sources in total supply, it is important to understand the underlying conven-tions that were used to calculate the primary energy balances.

Indicators

Energy production: total primary energy production, expressed in Mtoe.

Net imports: imports minus exports for total energy, expressed in Mtoe.

Total primary energy supply: expressed in Mtoe.

Net oil imports: imports minus exports of oil, ex-pressed in Mtoe.

Oil supply: primary supply of oil, expressed in Mtoe.

Electricity consumption: domestic consumption, i.e. gross production + imports - exports - losses, expressed in TWh.



Population: the main source of these series for 1970 to 2009 is National Accounts of OECD Countries, Volume 1, 2011. Data for 1960 to 1969 have been estimated using the growth rates from the population series published in the OECD Economic Outlook No 76. For the Czech Republic, Hungary and Poland (1960 to 1969) and Mexico (1960 to 1962), the data are estimated using the growth rates from the popula-tion series from the World Bank published in the World Development Indicators CD-ROM. For the Slovak Republic, population data for 1960 to 1989 are from the Demographic Research Centre, Infostat, Slovak Republic.

Population for 2010 has been estimated using the population numbers submitted on the Questionnaire for country submissions for the SLT/CERT annual review of energy policies.

GDP: the main source of these series for 1970 to 2010 is National Accounts of OECD Countries, Volume 1, 2011. GDP data for Australia, France, Greece and Sweden for 1960 to 1969 and Denmark for 1966 to 1969 as well as for Netherlands for 1969 come directly from the most recent volume of National Accounts. GDP data for 1960 to 1969 for the other countries have been estimated using the growth rates from the series in the OECD Economic Outlook No 76 and data previously published by the OECD. Data prior to 1986 for Chile, prior to 1990 for the Czech Republic and Poland, prior to 1991 for Hungary, and prior to 1992 for the Slovak Republic are IEA Secretariat estimates based on GDP growth rates from the World Bank.

The GDP data have been compiled for individual countries at market prices in local currency and an-nual rates. These data have been scaled up/down to the price levels of 2000 and then converted to US dol-lars using the yearly average 2000 exchange rates or purchasing power parities (PPPs).

Purchasing power parities are the rates of currency conversion that equalise the purchasing power of dif-ferent currencies. A given sum of money, when converted into different currencies at the PPP rates, buys the same basket of goods and services in all countries. In other words, PPPs are the rates of cur-rency conversion which eliminate the differences in price levels between different countries. The PPPs selected to convert the GDP from national currencies to US dollars were aggregated using the Geary-Khamis (GK) method and rebased on the United States. For a

more detailed description of the methodology please see Purchasing Power Parities and Real Expenditures, GK Results, Volume II, 1990, OECD 1993.

Industrial Production Index: the main source of these series is the OECD database Main Economic Indica-tors, April 2011. Industrial production refers to the goods produced by establishments engaged in mining (including oil extraction), manufacturing, and produc-tion of electricity, gas and water. These are categories B, C, D and E of ISIC1 Rev. 4 or NACE Rev. 2 classi-fications. From 1991, the industrial production index for Germany refers to unified Germany and has been linked to the series for Western Germany. For OECD Total, data refer to all OECD countries; prior to 1995 Chile, Czech Republic, Estonia, Hungary, Iceland, Israel, Poland, Slovak Republic and Slovenia are ex-cluded. For OECD Europe, data refer to the 25 OECD countries that are located in Europe starting from 1995; prior to 1995 Czech Republic, Estonia, Hun-gary, Iceland, Poland, Slovak Republic and Slovenia are excluded.

Layout

The energy balances are presented in tabular format: columns for the various sources of energy and rows for the different origins and uses.

Columns Across the top of the table from left to right, there are eleven columns with the following headings:

Column 1: Coal and peat includes all coal, both pri-mary (including hard coal and lignite) and derived fuels (including patent fuel, coke oven coke, gas coke, BKB, gas works gas, coke oven gas, blast furnace gas and other recovered gases). Peat is also included in this category. Note: starting with the 2011 edition, gas works gas is included here with coal. In previous years, gas works gas was included with natural gas.

Column 2: Crude oil comprises crude oil, natural gas liquids, refinery feedstocks, and additives as well as other hydrocarbons (including emulsified oils, syn-thetic crude oil, mineral oils extracted from bituminous minerals such as oil shale, bituminous sand, etc., and oils from coal liquefaction).

1. International Standard Industrial Classification of All Economic Activities, Series M, No. 4 / Rev. 4, United Nations, New York, 2008.



Column 3: Oil products comprise refinery gas, eth-ane, LPG, aviation gasoline, motor gasoline, jet fuels, kerosene, gas/diesel oil, fuel oil, naphtha, white spirit, lubricants, bitumen, paraffin waxes, petroleum coke and other oil products.

Column 4: Natural gas includes natural gas (exclud-ing natural gas liquids). Note: starting with the 2011 edition, gas works gas is included with coal. In previ-ous years, gas works gas was included with natural gas.

Column 5: Nuclear shows the primary heat equivalent of the electricity produced by a nuclear power plant with an average thermal efficiency of 33%.

Column 6: Hydro shows the energy content of the electricity produced in hydro power plants. Hydro output excludes output from pumped storage plants.

Column 7: Geothermal, solar, etc. shows production of geothermal, solar, wind and tide/wave/ocean energy and the use of these energy forms for electricity and heat generation. Unless the actual efficiency of the geothermal process is known, the quantity of geo-thermal energy entering electricity generation is inferred from the electricity production at geothermal plants assuming an average thermal efficiency of 10%. For solar, wind and tide/wave/ocean energy, the quanti-ties entering electricity generation are equal to the electrical energy generated. Other uses shown in this column relate to geothermal and solar thermal heat.

Column 8: Biofuels & waste comprises solid biofuels, liquid biofuels, biogases, industrial waste and municipal waste. Biofuels are defined as any plant matter used directly as fuel or converted into fuels (e.g. charcoal) or electricity and/or heat. Included here are wood, vegetal waste (including wood waste and crops used for energy production), ethanol, animal materials/wastes and sulphite lyes (also known as "black liquor" which is an alkaline spent liquor from the digesters in the production of sulphate or soda pulp during the manufacture of paper where the energy content is derived from the lignin removed from the wood pulp and which is usually 65-70% solid in its concentrated form).

Municipal waste comprises wastes produced by resi-dential and commercial/public services that are collected by local authorities for disposal in a central location for the production of heat and/or power. Hos-pital waste is included in this category.

Note that for biofuels, only the amounts of biomass specifically used for energy purposes (a small part of

the total) are included in the energy statistics. There-fore, the non-energy use of biomass is not taken into consideration and the quantities are null by definition.

Data under this heading are often based on incomplete information. Thus the data give only a broad impres-sion of developments, and are not strictly comparable between countries. In some cases complete categories of vegetal fuel are omitted due to lack of information. Please refer to individual country data when consult-ing regional aggregates.

Column 9: Electricity shows final consumption and trade in electricity, which is accounted at the same heat value as electricity in final consumption (i.e. 1 GWh = 0.000086 Mtoe).

Column 10: Heat shows the disposition of heat pro-duced for sale. The large majority of the heat included in this column results from the combustion of fuels although some small amounts are produced from electrically powered heat pumps and boilers. Any heat extracted from ambient air by heat pumps is shown as production.

Column 11: Total equals the total of Columns 1 to 10.

Rows The categories on the left hand side of the table have the following functions:

Row 1: Production is the production of primary en-ergy, i.e. hard coal, lignite, peat, crude oil, NGL, natural gas, biofuels and waste, nuclear, hydro, geo-thermal, solar and the heat from heat pumps that is extracted from the ambient environment. Production is calculated after removal of impurities (e.g. sulphur from natural gas). Calculation of production of hy-dro, geothermal, etc. and nuclear electricity is explained in Section 2, Units and conversions.

Row 2/3: Imports and exports comprise amounts having crossed the national territorial boundaries of the country, whether or not customs clearance has taken place.

For coal: Imports and exports comprise the amount of fuels obtained from or supplied to other countries, whether or not there is an economic or customs union between the relevant countries. Coal in transit should not be included.

For oil and natural gas: Quantities of crude oil and oil products imported or exported under processing agreements (i.e. refining on account) are included. Quantities of oil in transit are excluded. Crude oil,



NGL and natural gas are reported as coming from the country of origin; refinery feedstocks and oil products are reported as coming from the country of last con-signment. Re-exports of oil imported for processing within bonded areas are shown as exports of product from the processing country to the final destination.

For electricity: Amounts are considered as imported or exported when they have crossed the national terri-torial boundaries of the country. If electricity is “wheeled” or transited through a country, the amount is shown as both an import and an export.

Row 4: International marine bunkers covers those quantities delivered to ships of all flags that are en-gaged in international navigation. The international navigation may take place at sea, on inland lakes and waterways, and in coastal waters. Consumption by ships engaged in domestic navigation is excluded. The domestic/international split is determined on the basis of port of departure and port of arrival, and not by the flag or nationality of the ship. Consumption by fishing vessels and by military forces is also excluded. See domestic navigation (Row 40), fishing (Row 46) and non-specified “other” (Row 47).

Row 5: International aviation bunkers includes deliv-eries of aviation fuels to aircraft for international aviation. Fuels used by airlines for their road vehicles are excluded. The domestic/international split should be determined on the basis of departure and landing locations and not by the nationality of the airline. For many countries this incorrectly excludes fuel used by domestically owned carriers for their international departures.

Note: In October 2008 the IEA hosted the 3rd meeting of InterEnerStat. This group is made up of 24 international organisations that collect or use energy statistics. One of the objectives of the group is to improve the quality of energy data by harmonising definitions for energy sources and flows. As a result of this meeting, the IEA decided to align its energy sta-tistics and balances with most other international organisations and to treat international aviation bunkers in the same way as international marine bunkers. Starting with the 2009 edition, international aviation bunkers is subtracted out of supply in the same way as international marine bunkers.

Row 6: Stock changes reflects the difference between opening stock levels on the first day of the year and closing levels on the last day of the year of stocks on national territory held by producers, importers, energy transformation industries and large consumers. A

stock build is shown as a negative number, and a stock draw as a positive number.

Row 7: Total primary energy supply (TPES) is made up of production (Row 1) + imports (Row 2) - exports (Row 3) - international marine bunkers (Row 4) - international aviation bunkers (Row 5) ± stock changes (Row 6).

Row 8: Transfers include interproduct transfers, prod-ucts transferred and recycled products (e.g. used lubricants which are reprocessed).

Row 9: Statistical differences includes the sum of the unexplained statistical differences for individual fu-els, as they appear in the basic energy statistics. It also includes the statistical differences that arise because of the variety of conversion factors in the coal and oil columns. See introduction to Energy Statistics of OECD Countries for further details.

Row 10: Electricity plants refers to plants which are designed to produce electricity only. If one or more units of the plant is a CHP unit (and the inputs and outputs can not be distinguished on a unit basis) then the whole plant is designated as a CHP plant. Both main activity producer2 and autoproducer3 plants are included here. Columns 1 through 8 show the use of primary and secondary fuels for the production of electricity as negative entries. Heat from chemical processes used for electricity generation will appear in Column 10. Gross electricity produced (including power stations' own consumption) appears as a posi-tive quantity in the electricity column. Transformation losses appear in the total column as a negative number.

Row 11: Combined heat and power plants (CHP), refers to plants which are designed to produce both heat and electricity, sometimes referred as co-generation power stations. If possible, fuel inputs and electricity/heat outputs are on a unit basis rather than on a plant basis. However, if data are not available on a unit basis, the convention for defining a CHP plant noted above is adopted. Both main activity producer and autoproducer plants are included here. Note that for autoproducer CHP plants, all fuel inputs to elec-tricity production are taken into account, while only

2. Main activity producers generate electricity and/or heat for sale to third parties, as their primary activity. They may be privately or pub-licly owned. Note that the sale need not take place through the public grid. 3. Autoproducer undertakings generate electricity and/or heat, wholly or partly for their own use as an activity which supports their primary activity. They may be privately or publicly owned.



the part of fuel inputs to heat sold is shown. Fuel in-puts for the production of heat consumed within the autoproducer's establishment are not included here but are included with figures for the final consump-tion of fuels in the appropriate consuming sector.

Columns 1 through 8 show the use of primary and secondary fuels for the production of electricity and heat as negative entries. Total gross electricity pro-duced appears as a positive quantity in the electricity column and heat produced appears as a positive num-ber in the heat column. Transformation losses appear in the total column as a negative number.

Row 12: Heat plants refers to plants (including heat pumps and electric boilers) designed to produce heat only, which is sold to a third party under the provi-sions of a contract. Both main activity producer and autoproducer plants are included here. Heat pumps that are operated within the residential sector where the heat is not sold are not considered a transforma-tion process and are not included here – the electricity consumption appears as residential use.

Columns 1 through 8 show the use of primary and secondary fuels in a heating system that transmits and distributes heat from one or more energy sources to, among others, residential, industrial, and commercial consumers, for space heating, cooking, hot water and industrial processes.

Row 13: Blast furnaces contains inputs to and outputs of fuels from blast furnaces. It is often difficult to cor-rectly account for all inputs and outputs in energy transformation industries, and to separate energy that is transformed from energy that is combusted. As a result, in certain cases the data in the total column are positive numbers, indicating a problem in the underly-ing energy data.

Row 14: Gas works contains the inputs to and outputs from plants manufacturing gases for distribution to the public, either directly or after blending with natural gas. The coal column will contain the output of gas works gas minus any inputs of coal and coal products into the gas works. Inputs of oil products or natural gas into the gas works will figure as negative numbers with conversion losses appearing in the total column.

Row 15: Coke/patent fuel/BKB plants contains losses in transformation of coal from primary to secondary fuels and from secondary to tertiary fuels (hard coal to coke and patent fuel, lignite to BKB, etc.).

Row 16: Oil refineries shows the use of primary en-ergy for the manufacture of finished oil products and

the corresponding output. Thus, the total reflects transformation losses. In certain cases the data in the total column are positive numbers. This can be due either to problems in the primary refinery balance, or to the fact that the IEA uses regional net calorific values for oil products.

Row 17: Petrochemical plants covers backflows re-turned from the petrochemical industry. Note that backflows from oil products that are used for non-energy purposes (i.e. white spirit and lubricants) are not included here, but in non-energy use.

Row 18: Liquefaction plants includes diverse lique-faction processes, such as coal liquefaction plants and gas-to-liquid plants.

Row 19: Other transformation covers non-specified transformation not shown elsewhere, such as the transformation of primary solid biofuels into charcoal.

Row 20: Energy industry own use contains the primary and secondary energy consumed by transformation industries for heating, pumping, traction and lighting purposes [ISIC4 05, 06, 19 and 35, Group 091 and Classes 0892 and 0721]. These quantities are shown as negative figures. Included here are, for example, own use of energy in coal mines, own consumption in power plants (which includes net electricity consumed for pumped storage) and energy used for oil and gas extraction.

Row 21: Losses includes losses in energy distribution, transmission and transport.

Row 22: Total final consumption (TFC) is the sum of consumption by the different end-use sectors. Back-flows from the petrochemical industry are not included in final consumption (see Row 17, petro-chemical plants and Row 52, of which petrochemical feedstocks).

Rows 23-36: Industry consumption is specified in the following sub-sectors (energy used for transport by industry is not included here but is reported under transport):

Iron and steel industry [ISIC Group 241 and Class 2431]; Chemical and petrochemical industry [ISIC Divi-sions 20 and 21] excluding petrochemical feedstocks; Non-ferrous metals basic industries [ISIC Group 242 and Class 2432];

4. International Standard Industrial Classification of All Economic Activities, Series M, No. 4 / Rev. 4, United Nations, New York, 2008.



Non-metallic minerals such as glass, ceramic, cement, etc. [ISIC Division 23]; Transport equipment [ISIC Divisions 29 and 30]; Machinery comprises fabricated metal products, ma-chinery and equipment other than transport equipment [ISIC Divisions 25 to 28]; Mining (excluding fuels) and quarrying [ISIC Divi-sions 07 and 08 and Group 099]; Food and tobacco [ISIC Divisions 10 to 12]; Paper, pulp and printing [ISIC Divisions 17 and 18]; Wood and wood products (other than pulp and paper) [ISIC Division 16]; Construction [ISIC Divisions 41 to 43]; Textile and leather [ISIC Divisions 13 to 15]; Non-specified (any manufacturing industry not in-cluded above) [ISIC Divisions 22, 31 and 32].

Note: Most countries have difficulties supplying an industrial breakdown for all fuels. In these cases, the non-specified industry row has been used. Regional aggregates of industrial consumption should therefore be used with caution.

Rows 37-43: Transport includes all fuels used for transport [ISIC Divisions 49 to 51] except interna-tional marine bunkers and international aviation bunkers. It includes transport in industry and covers domestic aviation, road, rail, pipeline transport, do-mestic navigation and non-specified transport. Domestic aviation includes deliveries of aviation fuels to aircraft for domestic aviation – commercial, pri-vate, agriculture, etc. It includes use for purposes other than flying, e.g. bench testing of engines, but not airline use of fuel for road transport. The domestic/international split should be determined on the basis of departure and landing locations and not by the na-tionality of the airline. Note that this may include journeys of considerable length between two airports in a country (e.g. San Francisco to Honolulu). For many countries, the split between international avia-tion and domestic aviation incorrectly allocates fuel use for both domestic and international departures of domestically owned carriers to domestic air. Fuel used for ocean, coastal and inland fishing (included under fishing) and military consumption (included in other non-specified) are excluded from transport.

Rows 44-49: Other covers residential [ISIC Divi-sions 97 and 98, although this is only a small part of residential], commercial and public services [ISIC

Divisions 33, 36-39, 45-47, 52, 53, 55, 56, 58-66, 68-75, 77-82, 84 (excluding Class 8422), 85-88, 90-96 and 99], agriculture/forestry [ISIC Divisions 01 and 02], fishing [ISIC Division 03] and non-specified con-sumption. Non-specified includes military fuel use for all mobile and stationary consumption (e.g. ships, aircraft, road and energy used in living quarters) re-gardless of whether the fuel delivered is for the military of that country or for the military of another country. In many cases administrations find it impos-sible to distinguish energy consumption in commercial and public services from residential con-sumption. Some cannot distinguish consumption in agriculture from that in residential. In these cases, residential will also include consumption in agricul-ture and/or commercial/public services. The other total is, therefore, more accurate than its components.

Rows 50-54: Non-energy use covers those fuels that are used as raw materials in the different sectors and are not consumed as a fuel or transformed into another fuel. Non-energy use is shown separately in final con-sumption under the heading non-energy use.

Note that for biofuels, only the amounts of biomass specifically used for energy purposes (a small part of the total) are included in the energy statistics. There-fore, the non-energy use of biomass is not taken into consideration and the quantities are null by definition.

of which: petrochemical feedstocks. The petrochemical industry includes cracking and reforming processes for the purpose of producing ethylene, propylene, bu-tylene, synthesis gas, aromatics, butadene and other hydrocarbon-based raw materials in processes such as steam cracking, aromatics plants and steam reforming [part of ISIC Group 201].

Rows 55-57: Electricity generated shows the total number of TWh generated by thermal power plants separated into electricity plants and CHP plants, as well as production by nuclear and hydro (excluding pumped storage production), geothermal, etc. (see, however, the notes on Rows 10 and 11). Electricity produced by heat from chemical processes is shown in the heat column.

Rows 58-60: Heat generated shows the total number of PJ generated by power plants separated into CHP plants and heat plants. Heat produced by electric boil-ers is shown in the electricity column. Heat produced by heat pumps, heat from chemical processes and heat from non-specified combustible fuels is shown in the heat column.



2. UNITS AND CONVERSIONS General conversion factors for energy

To: TJ Gcal Mtoe MBtu GWh

From: multiply by:

terajoule (TJ) 1 238.8 2.388 x 10-5 947.8 0.2778

gigacalorie (Gcal) 4.1868 x 10-3 1 10-7 3.968 1.163 x 10-3 million tonne of oil equivalent (Mtoe) 4.1868 x 10

4 107 1 3.968 x 107 11630

million British thermal unit (MBtu) 1.0551 x 10

-3 0.252 2.52 x 10-8 1 2.931 x 10-4

gigawatt hour (GWh) 3.6 860 8.6 x 10-5 3412 1

Conversion factors for mass

To: kg T lt st lb

From: multiply by:

kilogramme (kg) 1 0.001 9.84 x 10-4 1.102 x 10-3 2.2046

tonne (t) 1000 1 0.984 1.1023 2204.6 long ton (lt) 1016 1.016 1 1.120 2240.0 short ton (st) 907.2 0.9072 0.893 1 2000.0

pound (lb) 0.454 4.54 x 10-4 4.46 x 10-4 5.0 x 10-4 1

Conversion factors for volume

To: gal U.S. gal U.K. bbl ft3 l m3

From: multiply by:

U.S. gallon (gal) 1 0.8327 0.02381 0.1337 3.785 0.0038 U.K. gallon (gal) 1.201 1 0.02859 0.1605 4.546 0.0045 barrel (bbl) 42.0 34.97 1 5.615 159.0 0.159 cubic foot (ft3) 7.48 6.229 0.1781 1 28.3 0.0283 litre (l) 0.2642 0.220 0.0063 0.0353 1 0.001 cubic metre (m3) 264.2 220.0 6.289 35.3147 1000.0 1



Decimal prefixes

101 deca (da) 10-1 deci (d)

102 hecto (h) 10-2 centi (c)

103 kilo (k) 10-3 milli (m)

106 mega (M) 10-6 micro (µ)

109 giga (G) 10-9 nano (n)

1012 tera (T) 10-12 pico (p)

1015 peta (P) 10-15 femto (f)

1018 exa (E) 10-18 atto (a)

Coal

Coal has separate net calorific values for production, imports, exports, inputs to electricity/heat generation and coal used in coke ovens, blast furnaces and indus-try. For electricity/heat generation, coal inputs to each type of plant (i.e. main activity electricity plant, auto-producer electricity plant, main activity CHP plant, autoproducer CHP plant, main activity heat plant, autoproducer heat plant) are converted to energy units using average factors calculated from the Annual Electricity Questionnaire. All other flows are con-verted using an average net calorific value. Country-specific net calorific values for 2009 are given in Part II.

Crude oil

Country-specific net calorific values (NCV) for pro-duction, imports and exports by country are used to calculate the balances. The average value is used to convert all the other flows to heat values. Country-specific net calorific values for 2009 are given in Part II.

Gases

Energy Statistics of OECD Countries expresses the following gases in terajoules, using their gross calo-rific value. 1 terajoule = 0.00002388 Mtoe.

To calculate the net heat content of a gas from its gross heat content, multiply the gross heat content by the appropriate following factor.

Gas Gross to net ratio Natural gas 0.9 Gas works gas 0.9 Coke oven gas 0.9 Blast furnace gas 1.0 Other recovered gases 1.0

Biofuels and waste

The heat content of primary solid biofuels, biogases, municipal waste and industrial waste, expressed in terajoules on a net calorific value basis, is presented in Energy Statistics of OECD Countries. The Secretariat does not receive information on volumes and other characteristics of these fuels.

1 terajoule = 0.00002388 Mtoe.

Data for charcoal are converted from tonnes using the average net calorific values given in Part II.

Unless country-specific information has been pro-vided, data for biogasoline are converted from tonnes using 26 800 kJ/kg. Biodiesels and other liquid biofu-els are assumed to have a net calorific value of 36 800 kJ/kg unless otherwise specified.

Oil products

The IEA applies regional conversion factors (in con-junction with Eurostat for the European countries) for the oil products.



Regional net calorific values for oil products

Oil products Europe Americas Asia Oceania

kJ/kg kJ/kg kJ/kg

Refinery gas 49 500 48 100 48 100 Ethane 49 500 49 400 49 400 Liquefied petroleum gases 46 000 47 300 47 700 Motor gasoline 44 000 44 800 44 600 Aviation gasoline 44 000 44 800 44 600 Gasoline type jet fuel 43 000 44 800 44 600 Kerosene type jet fuel 43 000 44 600 44 500 Kerosene 43 000 43 800 42 900 Gas/diesel oil 42 600 42 600 42 600 Fuel oil 40 000 40 200 42 600 Naphtha 44 000 45 000 43 200 White spirit 43 600 43 000 43 000 Lubricants 42 000 42 000 42 900 Bitumen 39 000 40 000 38 800 Paraffin Waxes 40 000 Petroleum Coke 32 000 32 000 33 800 Non-specified oil products 40 000

Electricity

Figures for electricity production, trade, and final con-sumption are calculated using the energy content of the electricity (i.e. at a rate of 1 TWh = 0.086 Mtoe).

Hydro-electricity production (excluding pumped stor-age) and electricity produced by other non-thermal means (wind, tide/wave/ocean, photovoltaic, etc.) are accounted for similarly using 1 TWh = 0.086 Mtoe.

The primary energy equivalent of nuclear electricity is calculated from the gross generation by assuming a 33% conversion efficiency, i.e. 1 TWh = (0.086 ÷ 0.33) Mtoe.

In the case of electricity produced from geothermal heat, if the actual geothermal efficiency is not known, then the primary equivalent is calculated assuming an effi-ciency of 10%, so 1 TWh = (0.086 ÷ 0.1) Mtoe.

Heat

Information on heat is supplied in terajoules and 1 terajoule = 0.00002388 Mtoe.

In the case of heat produced in a geothermal plant, if the actual geothermal efficiency is not known, then the

primary equivalent is calculated assuming an effi-ciency of 50%, so 1 TWh = (0.086 ÷ 0.5) Mtoe.

For direct use of geothermal and solar thermal heat, all the heat consumed is accounted for in production and consumption.

Examples

The following examples indicate how to calculate the net calorific content (in Mtoe) of the quantities ex-pressed in original units in Energy Statistics of OECD Countries.

From Original Units To Mtoe (on a NCV basis)

Coking coal production (Poland) for 2009 in thousand tonnes

divide by 41 868 and then multiply by 29.600

Natural gas in terajoules (gross)

multiply by 0.00002388 and then multiply by 0.9

Motor gasoline (Poland) in thousand tonnes

divide by 41 868 and then multiply by 44.000

Heat in terajoules (net) multiply by 0.00002388



3. COUNTRY NOTES

General notes

The notes given below refer to data for the years 1960 to 2009 and cover the summary tables at the back of the book, as well as the information on CD-ROM and the on-line data service. In general, more detailed notes are available for data starting in 1990.

Prior to 1974, most fuel inputs and electricity and heat outputs for autoproducers are included in main activ-ity producers. The figures for the quantities of fuels used for the generation of electricity and heat and the corresponding outputs in CHP and heat plants should be used with caution. Despite estimates introduced by the Secretariat, inputs and outputs are not always con-sistent. Please refer to notes below under Electricity and Heat.

In 1996, the IEA Secretariat extensively revised data on coal and coke use in blast furnaces, and in the iron and steel industry (for those countries with blast fur-naces), based on data provided to the OECD Steel Committee and other sources. The quantities of fuels transformed into blast furnace gas have been esti-mated by the IEA Secretariat based on its blast furnace model.

Moreover, in 1996 and 1997, the IEA Secretariat extensively revised data on biofuels and waste (i.e. solid biofuels, biogases, liquid biofuels, industrial waste and municipal waste) based on data from Euro-stat (for the EU-15 Member countries) and on other national sources for other OECD Member countries. As consumption data for biofuels and waste from Eurostat are generally available from 1989, there may be breaks in series between 1988 and 1989 for some EU Member countries.

Australia

All data refer to the fiscal year (e.g. July 2008 to June 2009 for 2009). For the 2002 data, the Australian Administration started to use a new survey methodol-ogy which caused shifts in the structure of industry consumption. The Australian Administration is plan-ning to revise the historical series.

Coal: Data on blast furnace gas for electricity produc-tion by autoproducers begins in 1986. Consumption in wood and wood products is included in paper, pulp and print from 2001 onwards. The drop in BKB pro-duction in 2004 was due to a fire in the main production plant.

Biofuels and Waste: For biofuels and waste, a differ-ent industry consumption breakdown is available from 1996 and leads to breaks in series. Biogas production at sewage treatment works is unavailable.

Oil: Negative refinery losses are caused by differ-ences in treatment of transfers between refineries. Imports of fuel oil have been estimated by the Austra-lian Administration. The drop in the production of crude oil in 1999 is due to a gas explosion at the Longford plant.

Natural Gas: Prior to 1991, natural gas data include ethane. Data for 1999 and 2000 are estimated by the Australian Administration.

Electricity and Heat: Inputs and outputs from auto-producer CHP plants are not available prior to 1986. The production of electricity from wind is available from 1994. Electricity production from solar PV starts in 1992 and from solar thermal in 2003. Efficiencies used to calculate the solar thermal inputs to transfor-mation were chosen by the Australian Administration to be consistent with their national statistics. Prior to 1995, electricity production from biogases is included



in natural gas. Heat data are not available from 1992 onwards. In 2002, the Australian Administration started to use a new survey methodology and reclassified the types of plants between main activity producers and autoproducers.

Prior to 2007, electricity consumption in mining and quarrying includes consumption in liquefaction/regasification plants. From 1990 to 2007, electricity consumption in wood and wood products is included together with paper, pulp and printing.

Austria

Historical revisions by the Austrian Administration have resulted in some breaks in series between 1989 and 1990.

Coal: In the 2011 edition, the Austrian Administration has revised the consumption data for coke oven coke from 1999 and lignite from 2001. Since 1996, gas works gas is reported with natural gas because it is distributed in the same network. The amount of gas works gas is negligible and it is mostly consumed by households. The last lignite mine closed in the second quarter of 2004 and lignite use for power generation ceased in 2006.

Biofuels and Waste: Data for 1986 to 1989 for solid biofuels, industrial waste, biogases and liquid biofuels are IEA Secretariat estimates based on information published by OSTAT in Energieversongung Österreichs Endgültige Energiebilanz. Due to a change in the survey methodology, the heat produced in small plants (capacity inferior to 1 MW) is not re-ported starting in 2002. Prior to 2002, data for biogases only include plants of 1 MW or larger.

Natural Gas: The break in the time series for auto-producer electricity and CHP plants between 1995 and 1996 is due to the availability of more detailed data from 1996 onwards. Differences due to measurement are included with losses prior to 2000. There are in-consistencies in the time series for commercial/public services as this sub-sector is the residual of the con-sumption data. In the 2011 edition, many consumption sub-sectors have been revised back to 1999 as a result of a new methodology.

Electricity and Heat: Starting in 1990, small amounts of electricity used in heat pumps have been included in residential. There are breaks in series between 1995 and 1996 and between 1998 and 1999 due to new methods of survey. Heat from chemical processes

used for electricity production is available from 2004. Electricity plants data may include some CHP plants operating in electricity only mode.

Inputs of other oil products to autoproducer CHP plants were reclassified as refinery gas and natural gas in 2009. Revisions to the historical time series are planned by the Austrian Administration. Electricity consumption in oil refineries includes consumption in gas works prior to 1991. Also prior to 1991, electricity consumption in the iron and steel industry includes consumption in coke ovens and blast furnaces. Con-sumption in commercial/public services includes electricity used in the field of electricity supply, dis-trict heating and water supply prior to 1990. Electricity consumption in non-specified transport represents tramways, electric buses, ski lifts and cable cars. For heat, own use is included in losses.

Belgium

Coal: Production of other bituminous coal ceased on 31 August 1992. Production includes the recuperation of coal from coal dumps. The use of coke oven gas in chemical and petrochemical ceased in 1996. The de-crease of bituminous coal and coke oven coke in the iron and steel industry in 2002 is due to the closure of several plants.

Biofuels and Waste: In 2003, combustion of munici-pal waste for electricity and heat generation purposes increased significantly. However, because a large por-tion of the heat produced is not used (sold), plant efficiencies dropped significantly between 2002 and 2003. Data for biodiesels are available starting in 2007. Data for biogasoline are available starting in 2008.

Oil: The decrease of fuel oil in industry consumption since 1993 is due to the introduction of an excise tax as well as increased use of natural gas. In 2002, patent fuel plants used fuel oil to increase the calorific value of patent fuel.

Natural Gas: The large decrease in non-specified in-dustry in 2003 is due to improvements in data collection. New legislation for data collection has led to breaks in series for industry and energy industry own use between 2004 and 2005, and between 2007 and 2008. In the 2011 edition, gas trade in Belgium includes imported LNG which is regasified and sub-sequently exported to other countries.

Electricity and Heat: For 1998 and 1999, electricity production at CHP plants with annual heat output be-low 0.5 TJ is reported with electricity only plants. In



2000, most autoproducer electricity plants using com-bustible fuels were reclassified as autoproducer CHP plants; the heat production from these plants was used for internal industrial processes and not sold to third parties until 2005. Heat from chemical processes used for electricity production is available from 2005.

Breaks in series exist between 1991 and 1992 for heat consumption in chemical and non-specified industry. Breaks in series may exist between 2007 and 2008 due to revisions of NACE classifications. There is no heat consumption starting in 2007 in the iron and steel industry because the installation concerned became an autoproducer in July 2006 and the heat is no longer sold.

Canada

Revisions received by the Canadian Administration and incorporated into the 2002 edition have resulted in breaks in series between 1989 and 1990.

Coal: Due to a Canadian confidentiality law, it is not possible for the Canadian Administration to submit disaggregated series for all of the coal types. Between 2002 and 2006, the IEA Secretariat has estimated some of the missing series. The data for 2007 onwards are given directly as reported. The Canadian Admini-stration is planning to further refine its reporting.

Biofuels and Waste: The IEA Secretariat has esti-mated the data for industrial waste from 1990 to 2007, biogasoline (ethanol) from 1998 to 2004, municipal waste from 1990 to 2004, and landfill gas from 1997 to 2006 based on information supplied by Natural Resources Canada. The IEA Secretariat estimated landfill gas production and consumption for 2007 from information supplied by Environment Canada, Waste Management. Trade of solid biofuels may be included in production or consumption. The Canadian Administration is working on separating out the data and reporting the trade explicitly. For the 2011 edi-tion, the Canadian Administration revised solid biofuels from 1990, amongst others to include wood pellets.

Oil: From 1988 onwards, data for several industrial sub-sectors are no longer available. Transfers for naphtha and other oil products include purchases of feedstock and other additives from non-reporting companies. Ethane is mainly used as a petrochemical feedstock. Prior to 1990, hydrogen used for the upgrad-ing of synthetic crude oil production was included in natural gas supply; from 1990, a different methodology

was adopted by the Canadian Administration and these amounts are now shown in other hydrocarbons (part of crude oil). Canada imported orimulsion from Venezuela from 1994 to 2000.

Natural Gas: Starting in 1992, consumption of natural gas in main activity producer CHP plants includes use in three new facilities in the province of Ontario. The data reported in non-specified transformation repre-sent quantities of natural gas used for the upgrading of refined oil products. In 2000, the increase in main activity producer electricity data is due to new genera-tion plants in Alberta and Ontario, while the increase in autoproducer electricity is due to the addition of independent power production.

Electricity and Heat: Heat production includes heat produced by nuclear power stations for distribution to other consumers. The breakdown of electricity and heat generation between natural gas and oil products in main activity producer CHP plants has been esti-mated by the Canadian Administration starting in 1990. This may cause breaks in the time series be-tween 1989 and 1990. In the 2010 edition, the Canadian Administration revised the heat consump-tion data, causing statistical differences; revisions to production are pending.

Chile

Data are available starting in 1971.

From 1990, consumption in paper and pulp includes forestry and consumption in agriculture is included in non-specified industry. In general, a new methodol-ogy has been applied for data since 1990, leading to other breaks in series between 1989 and 1990.

Biofuels and Waste: Production of landfill gas ceased in 2001 as landfill sites stopped producing adequate gas to continue collection.

Oil: There are breaks in series between 2008 and 2009 due to a change in methodology by the Chilean Administration.

Natural Gas: Inputs of natural gas to autoproducer CHP plants in 2009 are estimated by the Chilean Ad-ministration based on electricity generation. In previous ye

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