COMMISSION STAFF WORKING DOCUMENT Investment projects in energy infrastructure Accompanying the document COMMUNICATION FROM THE COMMISSION TO THE EUROPEAN PARLIAMENT, THE COUNCIL, THE EUROPEAN ECONOMIC AND SOCIAL COMMITTEE AND THE COMMITTEE OF THE REGIONS Making the internal energy market work
Date: 2012-11-15
Institutions: European Commission
Subjects: biofuel, commodities market, electrical energy, energy diversification, energy supply, energy transport, extraction of oil, natural gas, oil pipeline, oil refining, renewable energy, single market, trans-European network

EUROPEAN 
COMMISSION 

Brussels, 15.11.2012  
SWD(2012) 367 

COMMISSION STAFF WORKING DOCUMENT 

Investment projects in energy infrastructure 

Accompanying the document 

COMMUNICATION FROM THE COMMISSION TO THE EUROPEAN 
PARLIAMENT, THE COUNCIL, THE EUROPEAN ECONOMIC AND SOCIAL 
COMMITTEE AND THE COMMITTEE OF THE REGIONS 

Making the internal energy market work 

{COM(2012) 663 final} 
{SWD(2012) 368 final}

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   EN 

 
 
 
 
 
  
 
TABLE OF CONTENTS 

1. 

2. 

Synopsis ....................................................................................................................... 2 

Introduction .................................................................................................................. 4 

2.1. 

Policy and legal context ............................................................................................... 4 

2.1.1.  Policy context............................................................................................................... 4 

2.1.2.  The Energy Infrastructure Package.............................................................................. 4 

2.1.3.  Legal basis.................................................................................................................... 5 

2.2. 

2.3. 

3. 

Methodology ................................................................................................................ 6 

Consultation of experts ................................................................................................ 7 

Investment projects in energy infrastructure................................................................ 7 

3.1. 

Oil infrastructure .......................................................................................................... 7 

3.1.1.  Oil refining ................................................................................................................... 8 

3.1.2.  Oil transport ............................................................................................................... 10 

3.1.3.  Oil storage .................................................................................................................. 11 

3.2. 

Gas infrastructure ....................................................................................................... 12 

3.2.1.  Gas transport .............................................................................................................. 13 

3.2.2.  LNG terminals............................................................................................................ 17 

3.2.3.  Gas storage ................................................................................................................. 18 

3.3. 

Electricity infrastructure............................................................................................. 19 

3.3.1.  Electricity generation ................................................................................................. 20 

3.3.2.  Electricity transmission.............................................................................................. 23 

3.4. 

3.5. 

4. 

5. 

6. 

Biofuels infrastructure................................................................................................ 28 

Carbon Capture and Storage infrastructure................................................................ 29 

Overcoming barriers to investment............................................................................ 30 

Conclusion.................................................................................................................. 32 

Annexes...................................................................................................................... 33 

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COMMISSION STAFF WORKING DOCUMENT 

Investment projects in energy infrastructure 

Accompanying the document 

COMMUNICATION FROM THE COMMISSION TO THE EUROPEAN PARLIAMENT, 
THE COUNCIL, THE EUROPEAN ECONOMIC AND SOCIAL COMMITTEE AND 
THE COMMITTEE OF THE REGIONS 

Making the internal energy market work 

EN 

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   EN 

 
1. 

SYNOPSIS 

This  document  reports  on  the  notifications  made  by  EU  Member  States  on  their  investment 
projects in energy infrastructure, under Council Regulation (EU, Euratom) No 617/2010 in 2011. 
It  highlights  the  importance  of  investing  in  energy  infrastructure  to  contribute  to  a  more 
integrated and efficient internal energy market in electricity and gas, and in related sectors, such 
as oil and biofuels. 

It  concludes  that,  although  investment  is  being  made  in  all  sectors,  it  is  not  reaching  the  rate 
needed  to  meet  the  policy  ambitions.  There  is  also  concern  that  the  current  economic  and 
financial situation is having a detrimental impact on energy infrastructure investment, particularly 
in  new  supply  sectors.  Investing  in  energy  infrastructure  can  help  generate  growth  and  job 
creation  in  the  EU.  This  report  therefore  confirms  the  need  for  policy  makers  to  keep  up  the 
momentum  towards  market  integration,  improve  the  economic  conditions  for  energy-sector 
investment  across  Europe  and  develop  European  instruments  to  promote  investment  in 
sustainable, secure and competitive energy. 

This document provides a sector-by-sector analysis and a good overview of the current state of 
existing and planned energy infrastructure per Member State. 

In the electricity sector, most Member States are investing in generating capacity. This is driven 
by  the  increasing  demand  for  electricity  and  the  binding  renewables  targets  in  2020.  Between 
2005  and  2010,  substantial  investment  was  made  in  renewable  energy,  leading  to  an  installed 
capacity of 288 GW in 2010 (increasing its share in gross final energy consumption from 8.6 to 
12.7 %  and  in  electricity  generation  from  14.7  to  19.6 %).  Nevertheless,  more  investment  is 
needed to achieve the national targets. The total investment of 40 GW notified by Member States 
is still far from the additional capacity needed to achieve the level of 487 GW in 2020, agreed in 
the  National  Renewable  Energy  Action  Plans.  However,  due  to  the  limitations  of  the  method 
applied (threshold for reporting of 10 MW for photovoltaic projects and 20 MW for wind parks), 
the  notifications  may  have  underestimated  investment  in  power  generation  from  renewable 
energy. 

The notifications also report major investment in the coming years in electricity generation from 
nuclear  energy  and  fossil  fuel-fired  power  stations.  Concerning  nuclear  energy,  Bulgaria,  the 
Czech  Republic,  Finland,  France,  Lithuania,  Romania,  Slovakia,  Sweden  and  the  United 
Kingdom have notified the Commission that they are planning to build new nuclear capacity or 
increase  the  capacity  of  their  existing  nuclear  power  plants.  Regarding  fossil  fuels,  Germany 
(following its decision to decommission nuclear power plants), Greece, Ireland, the Netherlands, 
Spain  and  the  United  Kingdom  are  significantly  investing  in  additional  capacity  generated  by 
conventional thermal power stations and/or cogeneration plants. 

In  addition,  most  Member  States  are  expanding  their  national  and  cross-border  electricity 
transmission  capacity.  This  is  in  line  with  the  announced  grid  reinforcements,  needed  to  cope 

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with  increasing  electricity  demand  and  supply  and  the  take-up  of  variable  generation  from 
renewables. However, the Ten-Year Network Development Plan (TYNDP) for electricity found 
that  one  in  three  planned  investments  is  experiencing  delays  in  implementation  due  to  long 
permitting processes. In addition, as the investment volumes need to increase by on average 70 % 
from  past  years,  access  to  finance  remains  a  challenge,  especially  in  the  current  economic 
situation. The main areas of investment in renewable integration have been identified in northern 
Europe  (to  integrate  wind  energy)  and  the  Iberian  Peninsula  (for  wind,  hydro  and  solar 
integration).  The  Baltic  countries  need  to  connect  better  their  energy  markets  to  other  EU 
electricity networks in order to develop regional trade (thereby implementing the Baltic Energy 
Market Interconnection Plan). In the south-east and south-central regions, investment is needed to 
cope with major energy flows in the north-south direction. 

In  the  gas  sector,  although  Member  States  have  notified  significant  investment  projects,  major 
investment  is  still  needed  to  properly  address  the  security  of  supply,  diversification  of  sources, 
low-carbon  objectives  and  completion  of  the  internal  market.  Some  Member  States  still  find 
themselves on a ‘gas island’ as a result of no or insufficient infrastructure connections with the 
rest  of  the  EU  (in  particular  the  three  Baltic  States,  Finland,  Malta  and  the  Iberian  Peninsula). 
Single-source dependency still prevails in northern and eastern Europe (with varying degrees of 
import dependency: Finland, Estonia, Latvia, Lithuania, Slovakia, Bulgaria and Romania). 

On  the  LNG  front,  several  projects  are  planned  to  help  diversify  gas  sources  and  routes  and 
therefore  improve  the  security  of  supply.  Belgium,  Italy,  Lithuania,  the  Netherlands,  Poland, 
Portugal and Spain have notified plans to build LNG terminals. Future LNG terminals are also 
planned in Cyprus, Estonia, Germany, Greece, France, Ireland, Latvia and Romania, but most of 
these  projects have not yet  received a final  investment  decision. Concerning gas storage, at the 
moment, it seems that the overall EU storage capacity is sufficient to cover seasonal demand, but 
tight supply-demand situations may appear in some regions, due to the uncertainty of future gas 
demand and of planned investment. 

In  the  oil  sector,  only  minor  oil  infrastructure  additions  are  planned.  This  is  in  line  with  the 
European oil sector analysis, since demand is projected to slowly fall over the coming decade and 
investment needs for oil infrastructure will be mainly to replace existing infrastructure. However, 
the  oil  refining  industry  needs  to  invest  in  conversion  capacity,  to  produce  more  middle 
distillates. 

In the biofuel sector, notifications show that the biofuel production capacity will be expanded in 
some  Member  States  in  the  coming  years  and  there  is  already  an  overcapacity  in  biodiesel 
production.  However,  more  investments  will  be  needed,  specifically  on  infrastructure  for 
producing  second  generation  biofuels1,  in  order  to  meet  the  projected  increase  in  demand  in 
response to EU renewables targets for 2020 and to compensate the reduction in oil demand. 

CCS  projects  are  currently  at  an  early  stage  of  development,  to  be  analysed  properly  via  the 
notifications.  Only  France  and  Hungary  reported  on  a  CO2  transport  pipeline.  This  is  likely  to 
change, though, for future notifications, as the CCS sector is developing. 

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2. 

INTRODUCTION 

2.1. 

Policy and legal context 

2.1.1.  Policy context 

Investment in energy infrastructure is crucial to secure energy supply in the European Union. It is 
a key factor to ensure the development of the internal market and to reach the 2020 energy and 
climate targets and the longer-term climate and energy objectives. 

It  has  been  estimated  that  Europe’s  energy  system  requires  investment  of  EUR  1  trillion2  by 
2020. Of this, EUR 540 billion are for power generation3 and EUR 210 billion are for electricity 
and gas networks of European importance:4  

– 

– 

About EUR 140 billion for high voltage electricity transmission systems, both onshore 
and offshore, storage, and smart grid applications at transmission and distribution level; 

About EUR 70 billion for high pressure gas transmission pipelines (coming into the EU 
and between EU Member states), storage, liquefied/compressed natural gas (LNG/CNG) 
terminals and reverse flow infrastructure; 

The volume of investment for the period 2011-2020 will need to increase by 30 % for gas and by 
around 70 % for electricity compared to current levels. 

In order for the Commission to assess the development of investment in energy infrastructure in 
the  EU  and  design  a  European  infrastructure  policy,  it  is  essential  to  have  a  more  precise  and 
updated picture of existing infrastructure and investment projects in the Member States. This is 
why  Council  Regulation  (EU,  Euratom)  No  617/2010  requires  Member  States  to  notify  the 
Commission  of  their  investment  projects  in  energy  infrastructure.  The  main  objectives  of  this 
Regulation  are  to:  (i)  collect  up-to-date,  reliable  and  comparable  data  to  better  observe  energy 
infrastructure in the EU; (ii) identify potential gaps between energy demand and energy supply 
capacity  and  therefore  decide  on  the  future  priorities  to  support  investment  projects  and  (iii) 
identify investment obstacles and propose best practices to address them. 

2.1.2.  The Energy Infrastructure Package 

The  Commission’s  proposal  for  a  Regulation  on  ‘Guidelines  for  trans-European  energy 
infrastructure’5  (Energy  Infrastructure  Package)  was  adopted  on  19  October  2011.  It  identifies 

2 
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4 

http://ec.europa.eu/energy/publications/doc/2011_energy2020_en.pdf 
In the Energy Roadmap 2050 scenarios http://ec.europa.eu/energy/energy2020/roadmap/index_en.htm, total 
investment needs in power stations for the period 2011-2020 range between EUR 452 and 487 bn (at 2005 
prices). At 2011 prices, this amounts to around 540 bn € for power generation alone. 
SEC/2011/1233 final. 

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twelve priority corridors and specific areas in electricity, gas, oil and CO2 networks that need to 
be implemented by 2020 to enable the EU to achieve its energy policy objectives of completing 
the internal market, security of supply and sustainability. It also proposes measures to speed up 
implementation  of  these  projects  through  provisions  on  permit  granting,  improving  regulations 
and  financing.  The  priority  corridors  and  areas  are  broken  down  into  specific  projects,  labelled 
projects  of  common  interest,  organised  by  region  and  against  technical  criteria  reflecting  the 
policy objectives. This approach builds on the Ten-Year Network Development Plans (TYNDPs) 
developed by the European Network of Transmission System Operators for Gas and Electricity 
(ENTSO-G and ENTSO-E). In the future, the TYNDPs should be accompanied by a cost-benefit 
analysis. 

The  Impact  Assessment  showed  a  lack  of  consistent  public  data  across  the  EU  on  existing 
infrastructure  and  future  investment  needs.  Information  collected  by  ENTSO-G  and  ENTSO-E 
for  the  TYNDPs  is  in  some  cases  incomplete:  (e.g.  on  liquefied  natural  gas,  storage,  etc.).  To 
address  these  gaps,  Regulation  (EU,  Euratom)  No 617/2010  can  complement  and  provide 
consistency checks and a clearer picture on the investment situation. Furthermore, the proposed 
Regulation on Guidelines will introduce strong reporting obligations for all projects of common 
interest covering the key stages, from planning until commissioning.  

2.1.3.  Legal basis 

Council Regulation (EU, Euratom) No 617/2010 concerning the notification to the Commission 
of  investment  projects  in  energy  infrastructure  within  the  European  Union  and  repealing 
Regulation (EC) No 736/96 requires Member States to notify every two years to the Commission 
(starting in 2011) data and information on investment projects concerning the production, storage 
and  transport  of  oil,  natural  gas,  electricity  (including  electricity  from  renewable  sources), 
biofuels and the capture and storage of carbon dioxide. 

The scope of the Regulation includes planned and under-construction projects, transformation of 
existing infrastructure and decommissioning projects of a certain size, on a five-year horizon, in 
the  territory  of  Member  States,  including  interconnections  with  third  countries.  The  entities 
involved in these projects should be obliged to notify this data to the Member State in question. 

The form and technical details of the notification to the Commission of data and information on 
investment projects in energy infrastructure are set out in the Annex to Commission Regulation 
(EU,  Euratom)  No  833/2010  of  21  September  2010  implementing  Council  Regulation  (EU, 
Euratom) No 617/2010. 

To ensure that this does not give rise to a disproportionate administrative burden, Article 3.2 of 
Regulation  617/2010  allows  Member  States  to  be  exempt  from  reporting  obligations  provided 
that  equivalent  information  is  supplied  to  the  Commission.  This  should  avoid  duplicating  the 
reporting  requirements  specified  in  the  third  internal  market  package  for  electricity  and  natural 
gas. This is the case, for instance, with data already collected by ENTSO-G and ENTSO-E in the 

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framework of the TYNDP and data collected by DG Energy on projects relating to nuclear power 
stations, including decommissioning. 

This  staff  working  document  is  published  in  line  with  Article  10(1)  of  Regulation  617/2010, 
which  states  that  the  Commission  should  make  a  cross-sectoral  analysis  of  the  structural 
evolution and perspectives of the energy system of the EU, on the basis of data collected from 
Member  States  and  taking  into  account  relevant  analyses  such  as  the  multi-annual  network 
development plans for gas and for electricity. 

This  procedure  is  to  be  repeated  every  two  years.  However,  in  October  2010,  the  Parliament 
requested  the  European  Court  of  Justice  to  annul  Council  Regulation  617/2010,  contesting  the 
legal base used to adopt the Regulation (Case C-490/10). The Council had decided to use Articles 
337  TFEU  and  187  TEAEC  as  a  legal  base,  on  the  grounds  that  the  Regulation  relates  to  the 
collection of general information. Under this legal base, the Council acts by simple and qualified 
majority and the Parliament does not take part in the adoption process. The Parliament considered 
Article 194 TFEU to be the correct choice, which implies an ordinary legislative procedure. On 6 
September 2012, the Court annulled Regulation 617/2010 but maintained its effects until a new 
regulation is adopted on the new legal basis, Article 194(2) TFEU. 

2.2.  Methodology 

The Member States had to send their notifications to the Commission before 31 July 2011. By the 
time  of  publication,  all  Member  States  had  done  so.  Some  countries  did  not  notify  all  their 
investment projects, using the exemptions under Article 3(2) of Regulation 617/2010. 

For each type of infrastructure (production, storage and transport) and energy sector (oil, natural 
gas, electricity, including electricity from renewable sources, biofuels and the capture and storage 
of carbon dioxide), they had to provide data using the following classification: 

– 

– 

– 

– 

– 

Existing infrastructure (at 1/1/Y and infrastructure non-operational at >3 Y); 

Infrastructure under construction (at 31/3/Y); 

Planned infrastructure with final investment decision (FID) (at 31/3/Y); 

Additions to be commissioned (under construction + FID) (at Y+ [0-2] and at Y+ [3-5]); 

Infrastructure to be decommissioned (at Y+ [0-2] and at Y+ [3-5]). 

Y corresponds to the year 2011 in this first reporting exercise. 

This  document  refers  to  planned  additions,  which  correspond  to  the  sum  of  under  construction 
and planned projects, minus infrastructure that will be decommissioned. 

To  analyse  the  notifications  and  identify  potential  gaps  between  energy  demand  and  energy 
supply capacity, a study was commissioned from Cowi/Ecorys. The main tasks to be performed 
by  the  contractor  included  checking  the  robustness  of  the  data  received  and  the  consistency, 
completeness and reliability of data. 

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As stated in the Regulation, the Commission must preserve the confidentiality of commercially 
sensitive data or information in its possession and may publish data and information forwarded 
by  Member  States,  provided  that  it  is  published  in  an  aggregated  form  and  that  no  details 
concerning individual undertakings and installations are disclosed or can be inferred. Therefore, 
only charts and tables with aggregated data are disclosed in this document.  

2.3. 

Consultation of experts 

The  Commission  consulted  governmental  and  non-governmental  experts  in  order  to  develop  a 
common understanding on future investments in a transparent and concerted way. 

During  the  consultation  process,  the  additional  utility  of  Regulation  617/2010  was  questioned, 
given  the  other  investment  monitoring  instruments,  in  particular  the  Ten-Year  Network 
Development  Plans  for  gas  and  electricity  developed  by  ENTSO-G  and  ENTSO-E.  The 
Commission  explained  that  the  objective  of  Regulation  617/2010  was  to  take  a  cross-sectoral 
approach  at  EU  level  and  to  provide  a  shared  and  public  analysis.  The  regulation  requirements 
aim at reinforcing other policy instruments and improve the quality of data necessary for policy-
making. However, clearer indications could be given to use the TYNDP process as the sole basis 
for notifying electricity and gas transmission infrastructure projects to ensure consistent data and 
analysis and to minimise the administrative burden. The risk of duplication was a major issue of 
concern, despite the fact that Regulation 617/2010 allows Member States to be exempt from the 
reporting obligations, provided that they supply equivalent information. 

3. 

INVESTMENT PROJECTS IN ENERGY INFRASTRUCTURE 

This  section  analyses  existing  infrastructure  and  investment  projects  on  the  basis  of  the 
notifications  sent  by  the  Member  States  and  alternative  sources  of  information.  It  first  gives  a 
concise  overview  of  the  current  state  of  infrastructure  and  the  main  challenges  faced  in  each 
sector. 

3.1. 

Oil infrastructure 

In  the  oil  sector,  only  minor  additions  to  the  oil  infrastructure  are  planned,  according  to  the 
notifications sent by the Member States. While this could be considered unsurprising given that it 
is projected that the demand for oil will continue to fall in the coming decade, there is a widely 
recognised  need  for  investment  in  conversion  capacity  to  reduce  the  high  gasoline  yield  of  the 
European oil refining sector in favour of higher middle-distillate yields. 

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3.1.1.  Oil refining 

The  EU  is  the  second  largest  producer  of  oil-derived  products,  after  the  United  States.  Its 
production capacity is some 15.5 million barrels per day, or 18 % of global refining capacity.6  

EU  refining  margins  have  been  depressed  since  the  beginning  of  the  crisis,  and  EU  demand 
continues to fall. The fall in demand coupled with excess capacity are the main reasons for the 
depressed margins. 

In addition, projections for future EU petroleum demand indicate that the fall will continue, with 
the exception of growth in middle distillates. Even this, however, is projected to be positive only 
for a few more years (even taking into account future demand from the shipping industry for very 
low sulphur fuel). 

The  response  of  a  number  of  EU  refining  companies  to  the  current  market  situation  and  future 
prospects has been to put refinery units up for sale or to halt operations, sometimes for indefinite 
periods  of  time.  However,  refineries  have  not  been  completely  closed,  due  to  the  large,  and 
costly, site remediation clean-up work that owners would have to face. 

Altogether,  some  eight  refineries  have  ceased  operations  since  the  beginning  of  the  crisis, 
amounting to around 6 % of total EU refining capacity. 

Capacity reductions have an impact on the security of supply because every refinery produces a 
certain amount of products that are valuable from a security of supply standpoint (such as middle 
distillates and naphtha, of which the EU is a net importer). There is also the concern that shutting 
down refining operations will lead to job losses for the employees of those refineries. 

In addition to shut-downs, some 12 % of EU capacity has changed hands since the beginning of 
the crisis. Many of the sellers have been vertically integrated oil companies, but a number of the 
buyers  have  either  little  or  no  experience  in  refining.  A  large  proportion  of  the  EU  refining 
capacity sold since the crisis has been bought by non-EU companies. 

In sharp contrast to EU demand, non-EU petroleum product demand, especially for products such 
as diesel, gasoil and naphtha, is projected to grow significantly. The expectation, therefore, is that 
global competition will rise — and, therefore, prices will rise — for supplies of these products, 
which also happen to be the petroleum products that the EU consumes more than it produces. The 
EU has been experiencing a growing trend in net imports of middle distillates and naphtha in the 
EU over the last few years. 

On the other hand, the EU produces much more gasoline than it consumes and it exports the rest. 
The US has been the main outlet for this excess gasoline over the last few years, but it is widely 
believed that it will significantly reduce its imports of gasoline in the future. Finding new outlets 
for gasoline exports is deemed a difficult challenge. 

6 

Market Observatory for Energy (2011), Europe’s energy position — Annual report 2010. 

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Going forward,  and  given the falling EU  demand,  it is very likely that the EU will increase its 
import dependence on certain products such as gasoil/diesel, unless the industry is able to invest 
in  further  conversion  capacity  to  produce  more  middle  distillates.  This  investment  is  also 
necessary to decrease the high gasoline yield of the EU refining industry, which would reduce the 
EU refining industry’s ‘export dependence’ in that fuel. 

Notifications from Member States 

Existing capacity at 1/1/2011. Investment projects at 31/3/2011. 

Source: Notifications from Member States under Council Regulation 617/2010 and Commission Regulation 833/2010. 

According to investment plans known by March 2011 notified by the Member States (see chart 
O1), oil refining capacity will decrease by 2 %. This represents an aggregate of Member States 
that  anticipated  reducing  their  refining  capacity  and  other  Member  States  that  projected 
increasing  their  refining  capacity.  Member  States  such  as  France,  Romania  and  Italy  expect  to 
reduce  their  oil  refining  capacity  (by  15 %,  12 %  and  4 %  respectively),  while  Portugal  and 
Greece anticipated investment in additional capacity (+14 % and +12 %). 

Decommissioning plans in France and Italy reflect the situation of gasoline overcapacity and low 
margins as mentioned earlier, with expectations of additional closures of refineries also likely in 
other Member States for the same reasons. The only signs of anticipated investment in conversion 
capacity  to  produce  less  gasoline  and  more  middle  distillates  were  in  the  notifications  sent  by 
Greece and Portugal. 

The  situation  of  the  EU  refining  sector  prompted  the  European  Commission  to  organise  and 
invite  stakeholders  to  a  round  table  meeting  on  refining  in  May  2012  to  discuss  the  need  for 
coordinated  action  at  EU  level  to  deal  with  the  sector’s  difficulties.  A  decision  was  taken  to 

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assess and monitor the situation of the security of supply of petroleum products and the impact of 
current and future EU legislative proposals on the competitiveness of the refining sector. 

3.1.2.  Oil transport 

Most of the crude oil imported into the EU arrives by sea. Approximately 20 % of EU oil imports 
are  transported  via  two  cross-border  pipelines:  the  Druzhba  pipeline,  connecting  Russia  with 
central  Europe;  and  the  Norpipe  pipeline,  supplying  oil  from  the  Norwegian  oil  fields  in  the 
North Sea to the United Kingdom. 

In  addition,  the  EU  has  a  wide  network  of  oil  pipelines,  transporting  crude  oil  and  refined 
products internally. Products are also transported by trucks, ships and trains. 

To increase the security of supply and reduce environmental risks, the Commission has identified 
an  oil  priority  corridor  among  the  twelve  priority  corridors  listed  in  the  draft  Regulation  on 
Guidelines  for  trans-European  energy  infrastructure’.7  The  Oil  supply  connections  in  Central 
Eastern Europe (‘OSC’) will ensure interoperability of the oil pipeline network in Central Eastern 
Europe.  The  Member  States  concerned  are  Austria,  the  Czech  Republic,  Germany,  Hungary, 
Poland and Slovakia. 

Notifications from Member States 

Existing capacity at 1/1/2011. Investment projects at 31/3/2011. Source: Notifications from Member States under Council Regulation 617/2010 
and Commission Regulation 833/2010. 

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Only  Austria,  Belgium,  Bulgaria  and  Slovakia  have  reported  investment  projects  in  crude  oil 
pipelines  for  the  years  to  come  (see  charts  O2  and  O3),  representing  an  additional  capacity  of 
42 %  in  Belgium  and  11 %  in  Slovakia  in  national  pipelines,  while  investment  projects 
represented 100 % more cross-border pipeline capacity in Austria and 11% more in Bulgaria. 

However,  it  seems  that  information  is  missing  for  some  countries,  when  comparing  with 
alternative  sources.  For  instance,  the  data  provider  IHS  also  reports  investment  in  Poland,  the 
Czech Republic and Greece. 

Existing capacity at 1/1/2011. Investment projects at 31/3/2011. 

Source: Notifications from Member States under Council Regulation 617/2010 and Commission Regulation 833/2010. 

3.1.3.  Oil storage 

Since 1968, all Member States must have crude oil and/or petroleum product stocks equivalent to 
90 days of average consumption of the main fuels. In 1974, the treaty setting up the International 
Energy Agency (IEA) established a similar rule for its Member countries, requiring them to hold 
oil and petroleum product stocks equivalent to 90 days of net imports. 

The new Oil Stocks Directive (2009/119/EC) aligns the EU obligation to that of the IEA, so for 
most  Member  States,  the  stockholding  obligation  will  be  90  days  of  net  imports.  The  new 
directive is to be transposed into national legislation by 31 December 2012. 

EN 

14 

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Notifications from Member States 

Existing capacity at 1/1/2011. Investment projects at 31/3/2011. ktoe: thousand tonnes of oil equivalent. 

Source: Notifications from Member States under Council Regulation 617/2010 and Commission Regulation 833/2010. 

Chart  O4  presents  the  notification  data  on  oil  storage  capacity.  The  data  is  the  sum  of  storage 
capacity of crude oil and petroleum products as provided by Member States. In total, oil storage 
capacity in the coming years should increase by 4 %, according to the notifications. 

Given that overall demand for oil products is falling in most Member States, no major problems 
regarding  storage  capacity  are  expected  in  the  immediate  future.  However,  as  demand  shifts, 
storage facilities need to be changed. Thus, the anticipated increases in demand for kerosene and 
transport diesel call for further investment in storage capacity for these products. 

3.2. 

Gas infrastructure 

Gas consumption in Europe has increased rapidly over the last 10 years. The share of natural gas 
in  the  European  energy  mix  rose  to  25 %  in  2010  from  20 %  in  1995.  This  trend  is  likely  to 
continue as gas will be an important source of energy in the next decade. It may be used for the 
transformation of energy systems by acting as a backup supply to balance the increasing share of 
power generation from variable renewables. 

Increasing consumption alongside decreasing domestic production have contributed to increasing 
imports of natural gas, resulting in higher import dependency. The gas import dependency of the 
EU increased from 43.5 % in 1995 to 62.4 % in 2010. In 2010, the EU imported its natural gas 
mainly from Russia (35 %), Norway (27 %) and Algeria (14 %). 

EN 

15 

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Single-source  dependency  prevails  in  northern  and  eastern  Europe,  with  varying  degrees  of 
import  dependency  (in  Member  States  such  as  Finland,  Estonia,  Latvia,  Lithuania,  Slovakia, 
Bulgaria and Romania). Certain Member States find themselves on a ‘gas island’ as they have no 
or  insufficient  infrastructure  connections  with  the  rest  of  the  EU  (in  particular  the  three  Baltic 
States and Finland, Malta and the Iberian Peninsula). 

Gas  sources  and  routes  need  to  be  diversified.  Investment  in  reverse-flow  infrastructure, 
increased  storage  capacity  and  additional  LNG  terminals  are  needed  to  address  the  security  of 
supply challenge and increase market integration and competition. 

In the impact assessment of the Communication on Energy infrastructure priorities for 2020 and 
beyond,8 the investment need for gas infrastructure in the coming decade was estimated to reach 
EUR 70 bn, including EU internal interconnectors, new import infrastructure (pipelines and LNG 
terminals)  and  storage  requirements.  In  volume,  it  is  projected  that  gas  transmission  capacity 
needs to be increased by 30 %. 

3.2.1.  Gas transport 

Around 80 %  of  imported gas flows into  Europe through pipelines while the remaining 20 % is 
transported through shipping in the form of Liquefied Natural Gas (LNG).9 

Notifications from Member States 

Existing capacity at 1/1/2011. Investment projects at 31/3/2011. 

8 
9 

SEC/2010/1395 
SWD (2012) 368 

EN 

16 

   EN 

 
 
                                                 
Sources:  Notifications  from  Member  States  under  Council  Regulation  617/2010  and  Commission  Regulation  833/2010;  ENTSO-G  ENTSO-G 
data used for AT, DE, ES, LV, NL, and UK. 

Only  minor  investments  in  national  gas  pipelines  were  reported  by  Member  States  (except  in 
Sweden and Greece, for their existing network, and in Poland). 

By contrast, there were reports of significant investment projects for cross-border gas pipelines in 
the vast majority of Member States, to extend the total gas network capacity by 18 %. The most 
significant  investments  in  cross-border  interconnections  are  expected  in  the  coming  years  in 
Germany, the Czech Republic, Italy, the Netherlands and Greece (see chart G2). 

Existing capacity at 1/1/2011. Investment projects at 31/3/2011. 

Sources: Notifications from Member States under Council Regulation 617/2010 and Commission Regulation 833/2010; ENTSO-G data used for 
AT, DE, ES, FR, IE, LT, LV, NL and UK. 

As  previously  mentioned,  Member  States  are  exempt  from  the  obligation  to  report  data  and 
information that are already provided by ENTSO-G in the TYNDP for gas. The exemption was 
used by ten Member States10 for some data. 

The Ten-Year Network Development Plan for gas (TYNDP) 

According  to  the  3rd  Energy  Package,  the  principle  aim  of  the  TYNDP  for  gas  is  to  provide  a 
consistent outlook for European gas infrastructure signalling potential gaps in future investment. 
It also endeavours to capture the wider gas market dynamics by looking at aspects such as supply 
potential,  market  integration,  and  security  of  supply.  The  TYNDP  for  gas  thus  provides  a 
comprehensive analysis of the gas market and identifies the range of projects in the pipeline. The 

10 

Austria,  Germany,  France,  Ireland,  Lithuania,  Latvia,  the  Netherlands,  Spain,  Sweden  and  the  United 
Kingdom. 

EN 

17 

   EN 

 
 
                                                 
process of framing the TYNDP follows the annual winter and summer outlooks and includes a 
comprehensive stakeholder consultation. 

The latest TYNDP was adopted in 2009 and covers the period 2011-2020. It includes 77 projects 
for  which  the  final  investment  decision  (FID)  has  been  taken  and  96  projects  with  the  FID 
pending.  The  projects  include  transmission  pipelines,  storage  and  LNG  projects  and  represent 
total investment of EUR 89.3 billion. 

The underlying market analysis, however, shows that from the European policy perspective, more 
investment  is  still  needed  in  addition  to  the  FID  projects  to  properly  address  the  security  of 
supply, low-carbon objectives and completion of the internal market. According to the TYNDP, 
the  European  transmission  system  offers  reasonable  flexibility,  while  storage  will  continue  to 
play a key role in meeting the increased demand for gas during the winter season and to provide 
for  more  supply  flexibility.  Regarding  market  integration,  the  TYNDP  concluded  that  all 
investment  projects  will  help  reduce  network  clustering  and  improve  integration  of  the  energy 
market. 

Country Specific Recommendations 

The  Council  recently  sent  Country  Specific  Recommendations,  as  part  of  the  ‘Europe  2020 
Strategy’,  to  the  Baltic  States,  Bulgaria,  Germany,  Hungary,  Italy,  Poland  and  Spain  regarding 
the need to increase gas interconnections.11 

Baltic  countries  need  to  connect  their  energy  markets  to  other  EU  gas  networks  in  order  to 
increase  the  security  of  supply  and  develop  regional  trade  (thereby  implementing  the  Baltic 
Energy  Market  Interconnection  Plan).  A  risk  assessment  is  underway  on  gas  interconnections 
with Estonia and Lithuania, as well as an assessment of pipeline projects (the Poland-Lithuania 
‘Baltic Connector’ gas pipeline). 

Bulgaria needs to complete its ongoing investment projects on gas interconnectors (in particular 
with  Romania,  Serbia  and  Greece)  and  make  physical  and  contractual  reverse-flow  possible  on 
the interconnector with Turkey. Bulgaria also needs to play a more proactive part in opening up 
the Southern Gas Corridor, which has the potential to diversify supply sources and routes and to 
strengthen competition. 

Germany needs to improve the north-south gas transport capacity and integrate the German gas 
market more with its neighbours in central Europe to improve the availability of gas capacity, to 
provide  a  back-up  of  renewable  energies  and  improve  the  security  of  both  gas  and  electricity 
supply.  Germany  should  enhance  the  interconnectivity  of  its  gas  infrastructure  to  neighbouring 
countries, including reverse flows, and develop new north-south and east-west transport capacity. 
Good progress is underway on reverse flows with Austria. Significant bottlenecks remain at the 
border  with  Denmark  (Ellund),  Poland  (Lasow),  in  southern  Germany  and  on  the  north-south 
route.12 

11 
12 

http://ec.europa.eu/europe2020/making-it-happen/country-specific-recommendations/index_en.htm 
SWD (2012) 368 

EN 

18 

   EN 

 
                                                 
In Central-Eastern Europe the North-South energy corridor13 has to be further developed in order 
to  create  or  further  complete  the  North-South  gas  route  that  connects  import  sources  from  the 
Baltic, Black and Adriatic Seas, to integrate the market and enhance security of supply. 

Hungary needs to increase its cross-border capacity in gas. Its current capacity is insufficient to 
ensure the integration of national markets on a regional level. 

In  Italy,  the  high  share  of  imported  gas  in  electricity  generation  means  that  it  needs  to  have  a 
secure gas supply. The country should therefore continue to actively diversify its supply sources 
and routes, including implementation of the Trans-Adriatic pipeline forming the Italian branch of 
the Southern Gas Corridor. 

In Poland, the key problem is the lack of diversification, with almost 90 % of gas imported from 
Russia.  The  recent  new  interconnections  with  the  Czech  Republic  and  Germany  are  improving 
the situation. 

The  Council  recommended  that  Spain  improve  its  gas  interconnections  with  neighbouring 
countries, France and Portugal, and to develop the Africa-Spain-France gas corridor. 

A  more  detailed  country  analysis  is  provided  in  the  Staff  Working  Document  on  European 
Energy Markets.14 

EU priorities 

The  following  priority  gas  corridors  were  identified  in  the  draft  Regulation  on  Guidelines  for 
trans-European energy infrastructure:15 

(1) 

North-South gas interconnections in western Europe (‘NSI West Gas’) 

Member  States  concerned:  Belgium,  France,  Germany,  Ireland,  Italy,  Luxembourg, 
Malta, the Netherlands, Portugal, Spain and the United Kingdom; 

(2) 

North-South  gas  interconnections  in  central-eastern  and  south-eastern  Europe  (‘NSI 
East Gas’) 

Member  States  concerned:  Austria,  Bulgaria,  Cyprus,  Czech  Republic,  Germany, 
Greece, Hungary, Italy, Poland, Romania, Slovakia and Slovenia; 

(3) 

Southern Gas Corridor (‘SGC’) 

13 

14 
15 

As  agreed  in  the  Memorandum  of  Understanding  on  North-South  Interconnections  in  Central  Eastern-
Europe  signed  on  23  November  2011  in  Brussels,  by  and  between  the  Republic  of  Austria,  Republic  of 
Bulgaria, Republic of Croatia, the Czech Republic, the Federal Republic of Germany, Republic of Hungary, 
Republic of Poland, Romania, Republic of Slovenia, Republic of Slovakia and the European Commission,  
SWD (2012) 368 
Other gas infrastructure than transmission are also included in the priority corridors: e.g. LNG/CNG storage 
and reverse flows. 

EN 

19 

   EN 

 
                                                 
Member  States  concerned:  Austria,  Bulgaria,  Czech  Republic,  Cyprus,  France, 
Germany, Hungary, Greece, Italy, Poland, Romania, Slovakia, Slovenia; 

(4) 

Baltic Energy Market Interconnection Plan in gas (‘BEMIP Gas’) 

Member  States  concerned:  Denmark,  Estonia,  Finland,  Germany,  Latvia,  Lithuania, 
Poland and Sweden. 

3.2.2.  LNG terminals 

Alongside  increasing  volumes  of  imported  gas  into  the  EU,  the  share  of  liquefied  natural  gas 
(LNG) deliveries has risen from 10 % twenty years ago to slightly under 20 % in 2011.16 

Investment  in  LNG  (liquefied  natural  gas)  will  help  diversify  energy  sources  and  increase  the 
security of supply. 

Notifications from Member States 

Existing capacity at 1/1/2011. Investment projects at 31/3/2011. Type of infrastructure: maximum regasification capacity. 

Sources:  Notifications  from  Member  States  under  Council  Regulation  617/2010  and  Commission  Regulation  833/2010;  ENTSO-G  for  LNG 
terminals in EL, ES and PT. 

Belgium, Italy, Lithuania, the Netherlands, Poland, Portugal and Spain have all notified plans for 
LNG regasification terminals (see chart G3). 

16 

SWD (2012) 368 

EN 

20 

   EN 

 
 
                                                 
According to Gas Infrastructure Europe (GIE), future LNG terminals are also planned in Cyprus, 
Estonia, Germany, Greece, France, Ireland, Latvia and Romania. 

The LNG terminal in the east Baltic region would cater for the needs of the three Baltic States 
and Finland, with the ideal location generally considered being near the Gulf of Finland.17 

3.2.3.  Gas storage 

The supply flow of  natural  gas  is  relatively stable but demand varies, mainly between seasons. 
Underground gas storage is an effective tool to respond to these demand variations. 

For  instance,  massive  withdrawals  from  gas  storage  helped  to  meet  high  increases  in  demand 
during  the  fourth  quarter  of  2010,  limiting  the  need  for  imports.  It  also  played  a  key  role  in 
meeting the peak demand in Europe during the cold spell in February 2012. 

Gas storage is considered a secure and economically viable way to ensure the supply of natural 
gas  and  deal  with  potential  gas  supply  shortages.  Natural  gas  undertakings  keep  gas  stocks  in 
commercial  storage  to  guarantee  delivery  to  their  consumers  at  times  of  changing  supply  and 
demand  conditions.  Some  Member  States  have  developed  strategic  storage  sites  where  gas  is 
reserved  exclusively  for  emergency  situations.  There  is  no  mandatory  EU  requirement  for  gas 
storage  (unlike  for  oil  storage).  EU  Regulation  994/2010  concerning  measures  to  safeguard  the 
security of gas supply only includes a ‘supply standard’, which requires natural gas undertakings 
to  be  able  to  deliver  gas  to  protected  consumers  under  predefined  conditions.18  Using 
underground  gas  storage  is  one  way,  but  not  the  only  way  to  fulfil  this  obligation.  Natural  gas 
undertakings  may  conclude  special  standby  contracts  for  pipeline  or  LNG  deliveries  to  comply 
with this provision. 

Natural  gas  can  be  stored  for  an  indefinite  period  of  time  in  natural  gas  storage  facilities  and 
withdrawn as and when needed. 

Around 69 % of gas storage is in depleted fields, 19 % in aquifers, 10 % in salt cavities, and 2 % in 
above-ground storage (LNG peak shaving facilities).19  

Notifications from Member States 

The  EU’s  current  storage  capacity  amounts  to  96  bcm,  in  terms  or  working  gas  capacity, 
according  to  notifications.  Twelve  Member  States  expect  investment  in  gas  storage  capacity  in 
the  coming  years:  Austria,  Belgium  Germany,  Denmark,  Spain,  France,  Italy,  the  Netherlands, 

17 
18 
(a) 
(b) 

(c) 

19 

Pending on a decision to be taken by the BEMIP high-level group.  
The following cases are defined in Regulation 994/2010: 
extreme temperatures during a 7-day peak period occurring with a statistical probability of once in 20 years; 
any period of at least 30 days of exceptionally high gas demand, occurring with a statistical probability of 
once in 20 years; and 
for  a  period  of  at  least  30  days,  in  case  of  the  disruption  of  the  single  largest  gas  infrastructure  under 
average winter conditions. 
Study on natural gas storage in the EU: _http://ec.europa.eu/energy/gas_electricity/studies/gas_en.htm. 

EN 

21 

   EN 

 
                                                 
Poland, Romania, Slovakia and the United Kingdom. The most significant investments, both in 
absolute and relative terms, are expected in Poland and in the Netherlands. 

Existing capacity at 1/1/2011. Investment projects at 31/3/2011. 

Sources: Notifications from Member States under Council Regulation 617/2010 and Commission Regulation 833/2010.. 

Notifications were completed by IHS/GIE data for existing capacities in DE, ES, LV, UK and for investments projects in DE and UK. 

Poland has an ambitious programme of investment in gas storage, partly supported by European 
funds.  In  the  Netherlands,  several  storage  sites  (salt  caverns)  have  been  built  on  the  German 
border  and  will  be  operational  by  the  end  of  2012.  In  addition,  seasonal  storage  is  being 
developed by Taqa (an energy company) and is expected to become operational in 2013.20 

While  current  EU  storage  capacity  seems  sufficient  to  cover  seasonal  demand,  tight  supply 
demand situations may appear in some regions due to the uncertainty of future gas demand and 
the uncertainty of planned investment. 

3.3. 

Electricity infrastructure 

The main challenges for electricity infrastructure are: (i) the growing demand for electricity over 
the  coming  decades,  as  expected  under  all  scenarios  of  the  Energy  Roadmap  2050;21  (ii) 
overcoming  bottlenecks  to  complete  the  internal  market  (iii)  an  increasing  share  of  generation 

20 
21 

SWD (2012) 368 
http://ec.europa.eu/energy/energy2020/roadmap/index_en.htm.  Although  the  total  energy  demand  fell  by 
3.6 %  between  2005  and  2010,  electricity  demand  rose  by  2.4 %  over  the  same  time.  Energy  projections 
concur that electricity demand is set to increase. This is expected to materialise both under the business-as-
usual scenario and in the event of strong decarbonisation of the economy. Transport electrification would 
increase this electricity demand substantially. . 

EN 

22 

   EN 

 
 
                                                 
from renewable sources and integration of variable generated electricity; and (iv) decentralising 
electricity  demand  and  supply.  The  geographical  distance  between  some  of  the  new  forms  of 
electricity  generation  such  as  offshore  wind  and  consumption  will  require  substantial  network 
investment. However, other forms of renewable generation, such as distributed generation close 
to consumption, can reduce the need for grid reinforcement and thereby contain extra costs. 

In  any  case,  investing  in  electricity  generation  capacity  and  electricity  networks  is  necessary, 
along  with  rapid  development  of  interconnections,  to  deal  with  the  different  characteristics 
between conventional power plants and some renewable energy plants. 

3.3.1.  Electricity generation 

The total electricity generation capacity for the EU-27 (at 1 January 2011) amounted to 839 GW 
according  to  notifications22  compared  to  904  GW  in  2010  according  to  Eurostat.  This  gap  is 
probably  explicable  by  the  thresholds  set  in  Regulation  617/2010  (reporting  threshold  set  at  10 
MW for photovoltaic projects and 20 MW for wind parks). This resulted in an underestimation of 
current capacity and future investment in electricity generation from renewables, as this type of 
investment  is  usually  small-scale  (the  electricity  generation  capacity  from  renewables  was  288 
GW in 2010 according to Eurostat, while notifications amounted to 221 GW). 

The  following  chart  compares  notifications  with  Eurostat  data  on  installed  electricity  capacity 
from renewables. 

Source: Eurostat (2010 data) and notifications from Member States under Council Regulation 617/2010 and Commission Regulation 833/2010. 
Missing notifications were replaced by data from Platts for BG, EL, ES, and IE. 

Notifications on investment projects 

22 

Missing or incomplete notifications were replaced by data from Platts for BG, EL, ES, IE, and LT. 

EN 

23 

   EN 

 
 
                                                 
According  to  notifications,  most  Member  States  are  investing  in  their  electricity  generating 
capacity (total investments amount to 125 GW). These investments are driven by the increasing 
demand for electricity and the binding renewables targets in 2020. 

Existing capacity at 1/1/2011. Investment projects at 31/3/2011. 

Source: Notifications from Member States under Council Regulation 617/2010 and Commission Regulation 833/2010. 

Missing or incomplete notifications from EL, ES, IE, and LT were replaced by data from Platts. 

The  following  charts  provide  details  on  the  energy  source  used  for  electricity  generation.  As 
shown in chart E1-1, Germany, Greece, Ireland, the Netherlands, Spain and the United Kingdom 
are significantly investing in additional electricity generation capacity from fossil fuels. Germany 
is  investing  in  new  fossil  fuel-fired  power  stations,  including  cogeneration  plants,  following  its 
decision  to  decommission  nuclear  power  plants.  The  United  Kingdom  is  opting  for  additional 
electricity  generation  capacity  from  gas  power  plants.  In  total,  the  additional  capacity  in 
electricity generation from fossil fuels notified by Member States amounts to 50 GW.  

EN 

24 

   EN 

 
 
Existing capacity at 1/1/2011. Investment projects at 31/3/2011. 

Source: Notifications from Member States under Council Regulation 617/2010 and Commission Regulation 833/2010. 

Missing notifications were replaced by data from Platts for BG, ES, IE and LT. 

Concerning nuclear energy, Bulgaria, the Czech Republic, Finland, France, Lithuania, Romania, 
Slovakia, Sweden and the United Kingdom have notified the Commission that they are planning 
to build new nuclear capacity or increase the capacity of their existing nuclear power plants.23 In 
particular,  Romania  will  double  its  existing  capacity,  Finland  will  increase  it  by  59 %  and 
Slovakia  by  45 %.24  At  the  beginning  of  2011,  Germany  had  started  to  phase  out  its  nuclear 
plants,  reducing  capacity  by  almost  10  GW.  By  2022,  Germany  plans  to  phase  out  all  nuclear 
plants. 

Regarding renewables, planned investment amounts to 40 GW and should increase the generation 
capacity from this source by 18 %, according to notifications. Most Member States are investing 
in renewables (see chart E1-2), but massive investments are being made by the United Kingdom 
(10.2 GW), Austria (4.6 GW), Italy (4.2 GW)  and France (4.1 GW). The United Kingdom, the 
Netherlands,  Lithuania  Estonia  and  Cyprus  will  more  than  double  their  existing  capacity  for 
electricity generation from renewables. 

As already mentioned, due to the limitations of the method applied (the reporting threshold set at 
10 MW for PV projects and 20 MW for wind parks) no firm conclusions can be drawn from the 
notifications  as  to  whether  the  current  level  of  investment  is  sufficient  to  achieve  the  target  of 

23 
24 

Notifications from Member States under Council Regulation 617/2010 and Article 41 of Euratom Treaty. 
Notifications from Member States under Council Regulation 617/2010. 

EN 

25 

   EN 

 
 
                                                 
20 % renewable energy in gross final energy consumption, which translates into a share of 34 % 
electricity from renewable sources. 

Looking at the overall development of the sector, between 2005 and 2010 significant investments 
in  renewable  energy  were  made,  which  led  to  an  increase  in  its  share  in  gross  final  energy 
consumption  from  8.6 %  to  12.7 %  and  in  electricity  generation  from  14.7 %  to  19.6 %. 
Nevertheless, significant additional investment remains necessary to achieve the national targets 
set  in  Directive  2009/28/EC,  subsequently  broken  down  in  the  National  Renewable  Energy 
Action Plans.25 According to these action plans, Member States need to increase the total level of 
installed capacity for electricity generation from renewable sources from about 174 GW in 2005 
to about 487 GW in 2020 and according to Eurostat the installed capacity was 288 GW in 2010. 
The difference between the 2010 and 2020 figures remains far higher than the 40 GW reported in 
the context of this exercise, which underlines the need to continue to ensure a positive investment 
climate in renewable energy if the targets are to be achieved. 

Existing capacity at 1/1/2011. Investment projects at 31/3/2011. 

Source: Notifications from Member States under Council Regulation 617/2010 and Commission Regulation 833/2010. 

Missing notifications were replaced by data from Platts for EL, ES, and IE. 

25 

The  NREAPs  provide  a  breakdown  of  national  targets  by  technology  and  a  growth  path  until  2020,  see 
http://www.ecn.nl/units/ps/themes/renewable-energy/projects/nreap/reports  for  a  summary  of  technology 
results. 

EN 

26 

   EN 

 
 
                                                 
3.3.2.  Electricity transmission 

To  complete  the  internal  energy  market  and  reach  the  Europe  2020 targets,  energy  needs  to  be 
able  to  flow  to  where  it  is  needed,  without  physical  barriers  at  national  borders.  To  remove 
physical  bottlenecks  in  grids,  significant  investments  are  needed  in  energy  infrastructure  in  the 
coming  years.  Better  connected  markets  and  an  end  to  the  isolation  of  ‘energy  islands’  are 
prerequisites  in  order  to  connect  Europe  with  new  sources  of  energy  and  prepare  for  the  low 
carbon  economy.  With  sufficient  interconnection  and  a  smarter  grid,  greater  absorption  of 
renewable electricity is possible. 

Notifications from Member States 

According  to  notifications,  several  Member  States  will  expand  their  national  transmission 
network (see chart E2), which is in line with the announced grid reinforcements needed to cope 
with increasing demand and supply, the take-up of renewables and variable generation. National 
transmission capacity  will  be  increased by 11 % with a total of around 28 000 km of additional 
lines.26 The most significant investment in absolute terms is being made in Spain (with 8 000 km 
of addition lines, i.e. a 23 % addition to its existing network), the United Kingdom and Italy. 

Existing capacity at 1/1/2011. Investment projects at 31/3/2011. 

Source: Notifications from Member States under Council Regulation 617/2010 and Commission Regulation 833/2010. 

Missing notifications were replaced by ENTSO-E data for IE. 

26 

Missing notifications were replaced by ENTSO-E data for BG and IE. 

EN 

27 

   EN 

 
 
                                                 
The  vast  majority  of  Member  States  are  also  investing  in  cross-border  transmission  capacity, 
which  is  expected  to  increase  by  33 %  in  the  coming  years  (see  chart  E3).  In  addition  to  the 
notifications  sent  by  the  Member  States,  it  is  useful  to  refer  to  the  findings  of  the  Ten-Year 
Network Development Plan (TYNDP) for Electricity. 

Existing capacity at 1/1/2011. Investment projects at 31/3/2011. 

Source: Notifications from Member States under Council Regulation 617/2010 and Commission Regulation 833/2010. 

Notifications were completed by ENTSO-E data for DK, IE, IT, PL, PT and SI. 

The Ten-Year Network Development Plan for electricity (TYNDP) 

The  TYNDP  2012  for  electricity  provides  a  comprehensive  analysis  of  the  electricity  market, 
bottlenecks and investment needs and identifies the range of planned projects in the next five and 
ten years. Total investment needs amount to EUR 104 billion, of which EUR 23 billion is for sub-
sea cables. The figures are in line with the EUR 100 billion envisaged by the Commission in the 
impact assessment accompanying the Energy Infrastructure Package.27  

ENTSO-E identified the following main areas of investments: 

– 

– 

Renewable integration (mainly wind) in the northern part of Europe; 

Renewable  integration  (mainly  wind,  hydro  and  solar)  in  the  southern  part  of  Europe 
(Iberian Peninsula); 

27 

SEC/2011/1233 final. 

EN 

28 

   EN 

 
 
                                                 
– 

– 

Baltic  States  integration,  with  in  particular  the  Baltic  Energy  Market  Interconnection 
Plan  (BEMIP)  launched  by  the  Commission  in  2008  aiming  at  full  integration  of  the 
three Baltic States into the European energy market by improving interconnections with 
neighbouring countries; 

Major  flows  in  the  south-east  and  south-central  regions,  also  including  ‘loop  flows’  in 
the north-south direction. 

The  TYNDP  finds  that  one  in  three  planned  investments  are  experiencing  delays  in 
implementation due to long permitting processes. In addition, as the investment volumes need to 
increase by on average 70 % from 2011 to 2020, access to finance remains a challenge, especially 
in  the  current  economic  situation.  The  impact  assessment  of  the  Commission’s  proposal  on 
Energy  Infrastructure  package  provides  a  thorough  analysis  of  the  multiple  factors  that  risk 
delaying the necessary investments.28  

Country Specific Recommendations 

Council  specific  recommendations  in  the  context of  the  Europe  2020  Strategy  were  sent  to  the 
Baltic States, Bulgaria, France, Germany, Hungary, Italy, Malta, Poland and Spain regarding the 
need to increase electricity interconnections.29 

Concerning  the  Baltic  States,  Estonia  needs  to  continue  developing  electricity  cross-border 
connections with Finland to end its relative market isolation. As regards electricity networks in 
Latvia, for historical reasons, the system is interconnected with the networks of Belarus, Russia, 
Estonia and Lithuania (BRELL Ring agreement). Latvia needs therefore to strengthen its national 
electricity grid to transport energy from Finland, Sweden or Poland and to continue cooperation 
with  the  Commission  in  negotiations  with  Russia  and  Belarus  on  operating  the  electricity 
network.  In  Lithuania,  the  planned  interconnections  in  the  electricity  sector  with  Sweden  (by 
2015)  and  Poland  (by  2016)  will  allow  the  country  to  connect  to  the  European  grid  and  boost 
competition in the electricity market. 

Bulgaria  and  Hungary  should  increase  their  cross-border  network  capacity  in  order  to  facilitate 
trade with neighbouring countries and integrate renewable energy sources. 

The  Council  recommended  France  to  develop  its  energy  interconnection  capacity,  given  its 
limited  interconnection  capacity  with  neighbouring  countries,  particularly  with  Spain,  which 
curbs the development of competition on the domestic electricity market. 

In Germany, expanding the north-south axis and the cross-border interconnections is considered 
necessary, in particular given the reduced back-up capacity in the south of Germany due to the 
shutdown  of  nuclear  power  plants,  and  the  increase  in  renewable  capacities  in  the  North  and 
Baltic Seas. 

28 
29 

See also section 4 of this document. 
http://ec.europa.eu/europe2020/making-it-happen/country-specific-recommendations/index_en.htm. 

EN 

29 

   EN 

 
                                                 
The  Council  recommended  Italy  to  take  further  measures  to  improve  its  infrastructure  capacity 
and  interconnections.  The  electricity  transmission  network  still  suffers  from  congestion.  The 
south  is  poorly  interconnected  to  the  central-northern  part  of  the  country.  Developing  the 
electricity network is expected not only to reduce congestion on the domestic grid, but enhance 
Italy's interconnection capacity with neighbouring markets. 

Malta needs to complete the EEPR electricity interconnection with Sicily, as this will enable it to 
develop renewable energy and reduce oil consumption. 

The  Council  recommended  Poland  to  speed  up  development  of  the  electricity  grid,  including 
cross-border  interconnections,  and  to  eliminate  obstacles  in  electricity  cross-border  exchange. 
Congestion on the Polish domestic electricity grid could be reduced by increasing its capacity to 
interconnect to neighbouring markets. 

Spain needs to increase its electricity network’s capacity for cross-border exchange, notably with 
France,  which  would  allow  it  to  trade  more  with  neighbouring  countries  and  facilitate  further 
integration of renewable electricity from multiple sources, such as wind power. 

A  more  detailed  country  analysis  in  provided  in  the  Staff  Working  Document  on  European 
Energy Markets.30  

EU priorities 

The  following  priority  electricity  corridors  and  areas  were  identified  in  the  draft  Regulation  on 
Guidelines for trans-European energy infrastructure: 

(1) 

Northern Seas offshore grid (‘NSOG’) 

Member  States  concerned:  Belgium,  Denmark,  France,  Germany,  Ireland,  Luxemburg, 
the Netherlands, Sweden, the United Kingdom; 

(2) 

North-South electricity interconnections in western Europe (‘NSI West Electricity’) 

Member  States  concerned:  Belgium,  France,  Germany,  Ireland,  Italy,  Luxembourg, 
Netherlands, Malta, Portugal, Spain, the United Kingdom; 

(3) 

North-South  electricity  interconnections  in  central-eastern  and  south-eastern  Europe 
(‘NSI East Electricity’) 

Member  States  concerned:  Austria,  Bulgaria,  Czech  Republic,  Cyprus,  Germany, 
Greece, Hungary, Italy, Poland, Romania, Slovakia, Slovenia; 

(4) 

Baltic Energy Market Interconnection Plan in electricity (‘BEMIP Electricity’) 

30 

SWD (2012) 368 

EN 

30 

   EN 

 
                                                 
Member  States  concerned:  Denmark,  Estonia,  Finland,  Germany,  Latvia,  Lithuania, 
Poland, Sweden; 

(5) 

Smart grids deployment 

Member States concerned: all; 

(6) 

Electricity highways 

Member States concerned: all. 

3.4. 

Biofuels infrastructure 

In 2009, the EU set a new, mandatory target for the share of renewable energy in the transport 
sector to reach at least 10 % in all Member States by 2020.31 In order to reach this target, a sound 
European biofuel infrastructure is of pivotal importance. 

Biofuels  produced  in  a  sustainable  way  are  an  alternative  energy  resource  that  can  substitute 
fossil fuels in the transport sector.32 The target does not specifically state the use of biofuels but, 
at  least  until  other  renewable  energy  sources  are  sufficiently  available  in  the  transport  sector, 
biofuels  will  make  a  decisive  contribution  to  achieve  this  target.  Therefore,  a  sound  European 
biofuel infrastructure is crucial. 

The figures below (chart B1) show current biofuel production capacity per Member State, and the 
planned additions. Production capacity is set to be significantly expanded in some Member States 
over the coming years.  

31 
32 

Directive 2009/28/EC of 23 April 2009 on the promotion of the use of energy from renewable sources. 
COM(2012) 271 final. Communication on Renewable Energy adopted on 6 June 2012. 

EN 

31 

   EN 

 
                                                 
Existing capacity at 1/1/2011. Investment projects at 31/3/2011. 

Source: Notifications from Member States under Council Regulation 617/2010 and Commission Regulation 833/2010. 

Biodiesel and bioethanol together represent more than 98 % of the biofuels consumed in the EU 
in 2010. 79 % of total biodiesel consumed in 2010 (or 9.6 mega tonnes) was produced in Europe. 
All Member States produced biodiesel in that year, except for Luxembourg. The main biodiesel 
producers were in Germany, Spain, France, Italy and the Netherlands. 

However,  there  is  major  overcapacity  of  biodiesel  production:  of  the  20  mega  tonnes  per  year 
production  capacity,  57 %  was  not  used  in  2010.  There  is  also  overcapacity  in  bioethanol 
production: in 2010, almost 24 % of production capacity was not used. Despite this overcapacity, 
an additional capacity of 4 mega tonnes is planned, according to notifications. 

These are all mostly based in the production of biofuels from food crops. However, as the market 
for biofuels has expanded it has become clear that not all biofuels are the same, in terms of their 
greenhouse  gas  impacts  from  global  land  use.  Recent  scientific  studies  have  shown  that  when 
taking into account indirect land use change, for example when biofuel production causes food or 
feed  production  to  be  displaced  to  non-agricultural  land  such  as  forests,  some  biofuels  may 
actually be adding as much to greenhouse gas emissions as the fossil fuels they replace.  

Because  of  these  concerns,  the  Commission  published  a  proposal  on  17  October  201233  to 
strongly  encourage  the  production  of  second  generation  biofuels  with  lower  indirect  land  use 
change  risks  in  favour  of  those  produced  from  food  and  feed  crops.  It  does  this  through  a 
combination of measures including limiting the contribution of first generation biofuels towards 
the  10%  renewable  energy  transport  target,  and  increasing  current  incentives  schemes  to 

33 

COM(2012) 595 final 

EN 

32 

   EN 

 
 
                                                 
quadruple counting for those types of biofuels that are more expensive to produce and have no 
indirect land use change impacts because they do not require land for their production (i.e. waste 
and  residues  such  as  straw).  As  such,  the  development  of  infrastructure  for  producing  second 
generation biofuels needs to be accelerated.  

3.5. 

Carbon Capture and Storage infrastructure 

Carbon Capture and Storage (CCS) is a relatively new field in energy infrastructure. Many CCS 
projects  are  being  prepared,  often  with  European  support  for  research  and/or  demonstration.  A 
number of capture projects of a size of around 20-30 MW and some storage research projects are 
currently  operational  in  Europe.  The  next  step  is  to  demonstrate  the  technology  at  integrated 
projects at a scale of at least 250 MW in order to reduce the costs so that the technology can be 
commercially  deployed  after  2020.  However,  the  number  of  actual  demonstration  projects 
currently going forward is low and many are significantly delayed. Therefore, the quality and the 
quantity of the data available in the notifications are limited, which means that interpretations and 
conclusions based on these data are relatively weak. 

Only  France  and  Hungary  reported  that  they  have  existing  CO2  transport  pipelines  and  the 
Netherlands is running investment projects in this field. None of the Member States have reported 
CO2  storage  in  their  notifications,  except  Romania  and  the  Netherlands,  where  storage 
installations are planned. 

The countries that are running active CCS demonstration projects (but without a final investment 
decision) are the Netherlands, Spain, Italy, France, Romania, Poland and the United Kingdom. 

4. 

OVERCOMING BARRIERS TO INVESTMENT 

As provided for in Regulation 617/2010, this analysis also aims to identify investment obstacles 
and promoting best practices to address them. 

Problems related to permit-granting  procedures, public opposition, financing and the  regulatory 
framework  have  been  identified  as  the  main  barriers  to  investment  in  the  impact  assessment34 
accompanying the Regulation on ‘Guidelines for trans-European energy infrastructure’.35 

Infrastructure  projects  are  primarily  financed  by  the  private  sector.  The  financial  crisis  has 
affected  the  lending  markets  and  investors  and  financial  institutions  have  become  more  risk 
averse.  The  current  credit  crunch  could  thus  be  seen  as  an  obstacle  to  investment  in  energy 
infrastructure.  In  addition,  public  budget  constraints  make  it  difficult  to  secure  financing  for 
energy infrastructure, especially for cross-border projects. 

To  boost  investment,  the  Commission  proposed  in  the  ‘Guidelines  for  trans-European  energy 
infrastructure’ streamlining  permit-granting  procedures  and  financing  support.  Each  Member 
State will designate one authority responsible for completing the entire permit-granting process. 

34 

35 

SEC/2011/1233 final. 
COM/2011/0658 final. 

EN 

33 

   EN 

 
                                                 
Projects of common interest contributing to the achievement of the 12 priority corridors identified 
by the Commission36 will be aided by these permit-granting procedures, regulatory measures and, 
under certain conditions, will be eligible for EU funding.  

At present, the Structural and Cohesion Funds can be used to support the development of energy 
infrastructure. Under the 2007-2013 budget, EUR 0.7 billion was allocated in the Member States 
for  projects  classified  as  TEN-E.  However,  the  Member  States  have  been  slow  to  use  the 
available  funds  so  far.  Since  the  decentralised  management  of  Structural  and  Cohesion  Funds, 
Member States have had difficulties in coordinating across and between countries to ensure that 
the regional network benefits from investment. 

Under  the  multi-annual  financial  framework  for  the  period  2014-2020,  the  Connecting  Europe 
Facility37  will  provide  EU  financial  aid  to  complete  priority  energy,  transport  and  digital 
infrastructure with a single fund of EUR 50 billion, out of which EUR 9.1 bn is earmarked for 
energy  infrastructure.  The  funds  from  Connecting  Europe  should  leverage  more  funding  from 
other private and public investors. A pilot phase of project bonds has been planned for 2012-2013 
with a budget of EUR 230 million. 

Regarding the policy and regulatory framework, predictability and stability are needed to create a 
favourable  environment  for  investing  in  energy  infrastructure.  The  regulatory  framework  up  to 
2020 is mainly set, so discussions of policies for the period 2020-2030 in line with the Energy 
Roadmap  2050  should  now  start  leading  to  firm  decisions  that  provide  certainty  for  long-term 
low-carbon investment.38 

The Communication on the Internal energy market39 highlights that energy markets are generally 
perceived  not  to  be  transparent  or  sufficiently  open  for  newcomers.  Economically  rational  and 
energy-efficient  investments  are  not  sufficiently  made.  Market-based  arrangements  that 
encourage  flexibility  through  effective  price  signals  must  be  introduced.  For  instance,  properly 
functioning wholesale markets, which reflect the economic value of power at each point in time 
in each area, can steer investment to where it is most efficient. State support, if needed, should be 
well-designed, targeted at identified market failures and objectives and limited in time, in order to 
minimise competition distortions in the internal market. Inappropriate public intervention must be 
avoided as it can discourage private investment and undermine the internal market. 

5. 

CONCLUSION 

The  Member  States  are  investing  in  energy  infrastructure.  They  are  increasing  their  electricity 
generation  capacity,  notably  from  renewable  energy  sources,  and  are  investing  in  biofuel 
infrastructure,  contributing  to  a  low-carbon  energy  system.  Cross-border  gas  and  electricity 
networks  are  expanding,  which  improves  integration  and  competition  in  the  internal  market. 

36 

37 
38 
39 

COM/2011/0658 final. 
COM(2011) 665. 
SEC(2011) 1565/2. 
COM (2012) 662 final. 

EN 

34 

   EN 

 
                                                 
Projects in LNG and gas storage facilities are being carried out, which increases the security of 
energy supply in the EU. 

The overall picture shows that the European policy drive, boosted by internal market objectives, 
is having a direct and positive impact on energy investment. However, with short timescales to 
integrate the whole European energy network by 2015, and to deliver the 2020 targets, the current 
rate  of  investment  is  unlikely  to  be  sufficient  to  achieve  the  results  expected.  While  there  are 
many  other  factors  at  play  (e.g.  evolution  of  demand,  production,  imports,  progress  in  energy 
efficiency, current state of infrastructure and replacement needs, utilisation rates, storage needs, 
energy costs and subsidies), a number of warning signs are emerging. 

In the electricity sector, significant additional investment is needed to achieve the national targets 
in  generation  from  renewables  and  to  adapt  transmission  networks  to  more  volatile  flows  and 
geographical  distances  between  production  and  consumption.  Investment  in  the  grid  is  also 
necessary  to  avoid  the  current  congestion  problems  worsening  (e.g.  in  Germany  and 
neighbouring  countries)  and  new  congestion  problems  appearing.  Regarding  gas  infrastructure, 
investment in cross-border pipelines, reverse-flow infrastructure, storage capacity and additional 
LNG terminals must continue to increase security of supply, in particular in the Baltic States and 
in Eastern  Europe,  where single-source dependency still prevails. In the oil sector, the industry 
should invest in further conversion capacity to adapt to market developments. Also in biofuels, 
more  investments  will  be  needed  in  infrastructure  for  the  production  of  second  generation 
biofuels in order to reach the 2020 targets and compensate the reduction in oil demand. 

This report should fuel further debate with other EU institutions, Member States and stakeholders 
with  a  view  to  identifying  potential  risks  of  under-investment  in  the  EU  and  assessing  how  to 
increase momentum and develop ways to stimulate the markets, find new sources of investment 
and plug gaps. 

*** 

EN 

35 

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6. 

ANNEXES 

Table 1: Existing capacity in energy infrastructure at 1/1/2011 

Existing capacity

unit
Austria
Belgium
Bulgaria
Cyprus
Czech Rep.
Germany
Denmark
Estonia
Spain
Finland
France
Greece
Hungary
Ireland
Italy
Lithuania
Luxembourg
Latvia
Malta
Netherlands
Poland
Portugal
Romania
Sweden
Slovenia
Slovakia
UK
Total

Oil refining
 Thousand 
tonnes /year 
24.5
224.0
23.0

22.8
279.2
22.5

41.0
188.0
56.6
24.2
17.9
230.8

156.7

37.1
24.4
54.9

16.1
247.5
1,691.3

Cross-border 
oil pipelines 
(TO)

Cross-border 
oil pipelines 
(FROM)

Oil pipelines

Oil storage

Gas pipelines

Cross-border 
gas pipelines 
(TO)

Cross-border 
gas pipelines 
(FROM)

LNG terminals Gas storage

Elec 
generation 

Elec 
transmission

Cross-border 
elec transm. 

Biofuel 
production

Kms

Thousand metric tonnes /day

Ktoe

Kms

Mcm/day

Mcm/day

Bcm/year

Bcm

MW

Kms

MVA+MW

Kton

42.0

1376.9

208.0

213.7

64.6

4.0

595.5
771.0
680.0

1,774.3
4,871.5
517.0

9,211.0
103.0
1,270.0

2,618.0

147.4
873.0

6.5
28.5

1,032.0
6,709.0
31,172.7

54.8

1,964.0

35.3

70.3

3,088.2
4,227.8
247.5
585.1
1,999.3
56,357.6
239.4
-
-
5,447.1
31,155.0
6,062.5
5,677.8
392.6
19,542.6

-
-
-
-

19,000.3
10,022.5
4,269.2
1,048.6
6,816.7
627.1
770.6
12,545.0
190,122.4

1,600.0
4,010.0
2,645.0
-
3,640.0
31,515.0
832.0
-
9,984.0
1,154.0
937.0
1,232.0
5,783.0
1,873.0
8,894.0
1,868.0
411.0
1,281.0
-

11,500.0
10,409.0
1,299.0
13,642.0
620.0
1,018.0
500.6
8,380.0
125,027.6

170.2
337.9
71.5

223.5
231.2

18.5

29.0

83.0
8.2
293.1
15.1

9.0

317.9
201.2
13.2
39.4

172.2
216.2
51.2

192.5
495.4
16.9

67.4
22.5
183.3
20.6
35.3
27.7
14.3
27.1
6.3
19.8

128.0
17.0
7.4

9.2
313.9
82.7
2,467.8

8.7
4.8
340.3
240.4
2,315.2

9.0

60.3

23.8
4.5

11.0

5.3

56.0
169.8

4.4
0.7
0.6

2.9
19.6
1.0

3.7

12.7

6.1

14.8

2.3

5.3
9.9
0.2
2.8

2.9
5.8
95.6

18,644.6
15,517.6
10,454.5
520.0
17,426.0
183,553.0
3,502.0
1,694.0
87,922.2
14,129.0
112,290.5
15,990.0
17,243.9
7,329.3
116,120.0
2,354.0
1,446.0
2,377.0
460.0
27,669.0
31,376.6
15,753.0
13,995.9
29,853.0
2,924.0
7,193.1
81,725.1
839,463.3

2,850.6
1,705.0
5,166.0
-
5,388.0
35,445.0
2,380.0
1,724.0
35,850.0
7,136.0
14,254.0
2,894.3
4,511.5
2,279.0
64,347.0

-
286.4
5,332.0
-
3,520.0
13,458.2
5,481.0
8,888.0
15,699.6
389.0
2,737.9
19,374.7
261,097.2

20,700.0
11,521.0
13,758.7

-

17,324.0

-
7,555.0
4,546.0
12,775.0
8,230.0
27,999.0
7,820.0
18,646.2
1,591.0
-
-
4,825.0
4,133.0
-

10,570.0
11,128.5
7,929.0
12,193.0
15,019.0
8,900.0
9,473.0
1,200.0
237,836.4

1,040.0
1,110.0
196.0

944.0
1,950.9

410.0
5,964.0
800.0
343.0
35.0
1,876.0
274.6

1,508.8
706.4
1,437.0
415.0
450.0

195.2
825.0
20,480.8

Sources: Notifications from Member States under Council Regulation 617/2010 and Commission Regulation 833/2010. 

Notifications on gas pipelines were completed by ENTSO-G data for AT, DE, ES, FR, LV, and NL and on LNG terminals for EL, ES and PT. 

EN 

36 

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Notifications on electricity generation were completed by Platts data for BG, EL, ES, IE, and LT. 

Notifications on electricity transmission and cross-border networks were completed by ENTSO-E data for BG, DK, IE, IT, PL, PT and SI. 

EN 

37 

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Table 2: Planned additions in energy infrastructure at 31/3/2011 

Oil refining
 Thousand 
tonnes /year 

nd

-                   

28.4
6.6

-                     

8.7

-                     

5.2
2.9

Planned additions

unit
Austria
Belgium
Bulgaria
Cyprus
Czech Rep.
Germany
Denmark
Estonia
Spain
Finland
France
Greece
Hungary
Ireland
Italy
Lithuania
Luxembourg
Latvia
Malta
Netherlands
Poland
Portugal
Romania
Sweden
Slovenia
Slovakia
UK
total

Cross-border 
oil pipelines 
(TO)

Cross-border 
oil pipelines 
(FROM)

Oil pipelines

Oil storage

Gas pipelines

Cross-border 
gas pipelines 
(TO)

Cross-border 
gas pipelines 
(FROM)

LNG terminals Gas storage

Elec 
generation 

Elec 
transmission

Cross-border 
elec transm. 

Biofuel 
production

Kms

Thousand metric tonnes /day

Ktoe

Kms

Mcm/day

Mcm/day

Bcm/year

Bcm

MW

Kms

MVA+MW

Kton

320.0

42.0

153.0

-
1,633.5
243.7
184.5
-
2,570.0
239.4

-                

858.1

185.0
143.0
70.0
170.7

94.0

627.0
89.0
208.0
577.0

46.5
773.0
151.5
21.8

-                

343.2
829.6
195.4
7.3
600.7
200.0
343.2
136.6
7,515.7

1,188.0
205.0
377.3
650.0
186.0
18.8
46.9
5,734.7

-                   

20.2
18.0

71.5
106.5
16.8

16.3

10.7
35.6
13.7

60.5
6.0

3.7

38.6
4.7

8.2

26.9
16.8

13.5
172.7
33.8

17.8

16.3
-
-

46.4
6.0

0.6

31.3
-

8.2

1.4
41.5

-                   

390.9

-                   

2.3
41.5
5.6
356.7

nd

10.5

28.0
nd

28.0
5.0
nd

78.5

2.8
nd

nd
nd

2.7

0.4

3.4

nd
9.0

nd

0.3
2.3
25.5

6,851.0
2,088.0
1,533.0
336.5
1,840.0
772.0
430.0
373.0
6,153.0
1,822.0
7,199.0
6,637.0
635.7
3,280.0
7,241.0
1,828.1
200.0
28.0
86.0
11,406.0
3,008.5
2,908.0
5,164.7
1,666.0
1,553.0
868.0
18,782.4
87,229.5

-                

-                   

-             

422.0
268.7
256.0

265.3
2,090.0
399.0
302.0
8,087.0
208.0
592.0
973.6
273.0
247.0
2,762.0
142.0
73.5
354.0
-
953.0
1,353.7
1,794.0
210.3
1,984.6
71.0
130.1
3,902.0
28,113.9

3,000.0
1,800.0

9,144.0
1,400.0
650.0
5,570.0
1,450.0
2,300.0

2,771.2
2,568.5
7,200.0
1,752.0
500.0
1,212.0
200.0
3,500.0
6,544.0
4,786.0
4,140.0
3,800.0
3,000.0
4,158.0
1,500.0
72,945.7

749.8

nd
180.0

nd
240.0
175.0

1,110.0
24.0

nd
420.0

800.0
3,928.8

nd
27.5

-                   

116.5

436.5

195.0

10.0

10.0

Planned additions correspond to the sum of under construction and planned projects, minus infrastructure that will be decommissioned. 

nd: non disclosed. Only aggregated data are disclosed, in conformity with Article 6.3 and Recital 14 of Council Regulation 617/2010. 

Sources: Notifications from Member States under Council Regulation 617/2010 and Commission Regulation 833/2010. 

EN 

38 

EN 

 
  
                   
                     
                   
                   
                     
             
                
             
                
             
                
                   
                   
             
                
             
                
                
                
             
                
                
                   
                
                     
                
                   
                   
             
                
             
                
                
                
             
             
                
                   
                   
                   
                
                
             
                
                
                
                
                   
                   
                   
                     
             
             
             
                   
             
                
             
                
                
                   
                   
                     
             
                
             
                     
                
                   
                     
             
                
                
                   
                     
                
             
                   
             
                
             
                
                   
                   
                   
                     
             
             
             
                
                
                     
                     
             
                
             
                
                   
                
                   
                
                     
                     
                   
                
             
                     
                
                
                   
                   
                   
          
                
             
             
                
             
                     
                     
                     
                     
             
             
                   
                     
                
             
             
             
                     
                
                     
                     
             
                
             
                
                
             
             
             
                
                
                
                     
                     
             
                   
             
                
                   
                
                   
                     
                
                
             
                
                     
                     
          
             
             
                
                
                
                   
             
             
                
                
                   
                   
          
          
          
             
 
Notifications on gas pipelines were completed by ENTSO-G data for AT, DE, ES, FR, LV, and NL and on LNG terminals for EL, ES and PT. 

Notifications on electricity generation were completed by Platts data for BG, EL, ES, IE, and LT. 

Notifications on electricity transmission and cross-border networks were completed by ENTSO-E data for BG, DK, IE, IT, PL, PT and SI. 

EN 

39 

EN 

 
  
Table 3: Planned additions in energy infrastructure at 31/3/2011 (in % of existing capacity) 

Planned additions
unit
Austria
Belgium
Bulgaria
Cyprus
Czech Rep.
Germany
Denmark
Estonia
Spain
Finland
France
Greece
Hungary
Ireland
Italy
Lithuania
Luxembourg
Latvia
Malta
Netherlands
Poland
Portugal
Romania
Sweden
Slovenia
Slovakia
UK
total

Oil refining
%

Oil pipelines
%

Cross-border 
oil pipelines 
(TO)
%

Cross-border 
oil pipelines 
(FROM)
%

Oil storage
%

Gas pipelines
%

Cross-border 
gas pipelines 
(TO)
%

Cross-border 
gas pipelines 
(FROM)
%

LNG terminals Gas storage
%

%

Elec 
generation 
%

Elec 
transmission
%

Cross-border 
elec transm. 
%

Biofuel 
production
%

42%

100%

11%

11%

1%

28%

14%

10%

39%
98%
32%

-100%

3%

2%
8%
-5%
1%
9%
32%
45%
1%
4%

5%
5%

5%

11%

6%
8%
22%
47%

2%
9%
8%
5%

11%
16%
3%
105%
18%
4%
-1%
5%

12%
5%

32%

88%

37%

16%
0%
21%
40%

41%

12%
2%
0%
21%

15%
-13%
0%
16%

16%
8%

7%

200%

26%

9%

325%
22%

3%

24%

48%
-12%
2%
15%

nd

17%

255%
nd

nd

46%

63%
nd

nd
nd

71%

3%

23%

nd
91%

nd

9%
40%
27%

37%
13%
15%
65%
11%

12%
22%
7%
13%
6%
42%
-4%
45%
6%
78%
14%
1%
-19%
41%
-10%
18%
37%
6%
53%
12%
23%
10%

15%
16%
5%

5%

17%
18%
23%
3%
4%
34%
6%
11%
4%

26%
7%

27%
10%
33%
2%
13%
18%
5%
20%
11%

14%
16%

19%
14%
44%
18%
8%
0%
15%
161%

10%
29%

33%
59%
60%
34%
25%
34%
44%
125%
31%

nd
23%

nd
13%
64%

74%
3%

nd
93%

97%
19%  

nd

-15%
12%

-4%

14%
-12%

nd

-2%

Planned additions correspond to the sum of under construction and planned projects, minus infrastructure that will be decommissioned. 

Source: Notifications from Member States under Council Regulation 617/2010 and Commission Regulation 833/2010. 

Units 

Ktoe 

Thousand tonnes of oil equivalent 

EN 

40 

EN 

 
  
 
Bcm 

Billion cubic meters 

Mcm 

Million cubic meters 

Kton 

Thousand tonnes 

MW 

Mega watts 

MVA 

Megavolt-ampere 

EN 

41 

EN