- •Foreword
- •Table of contents
- •1. Executive summary
- •Overview
- •Energy sector transformation
- •Taxation
- •Energy market reform
- •Energy security and regional integration
- •Key recommendations
- •2. General energy policy
- •Country overview
- •Energy supply and demand
- •Energy production and self-sufficiency
- •Energy consumption
- •Key institutions
- •Policy and targets
- •Energy sector transformation and independence
- •Taxation
- •Assessment
- •Recommendations
- •3. Oil shale
- •Overview
- •Supply and demand
- •Policy and regulatory framework
- •Industry structure
- •Environmental impact from oil shale production and use
- •Future of oil shale
- •Assessment
- •Recommendations
- •Overview
- •Supply and demand
- •Oil production
- •Trade: Imports and exports
- •Shale oil
- •Oil products
- •Oil demand
- •Market structure
- •Prices and taxes
- •Upstream – Oil shale liquefaction
- •Infrastructure
- •Refining
- •Ports and road network
- •Storage
- •Emergency response policy
- •Oil emergency reserves
- •Assessment
- •Oil markets
- •Oil security
- •Recommendations
- •5. Electricity
- •Overview
- •Supply and demand
- •Electricity generation
- •Imports and exports
- •Electricity consumption
- •Electricity prices and taxes
- •Market structure
- •Wholesale and distribution market
- •Interconnections
- •Synchronisation with continental Europe
- •Network balancing
- •Electricity security
- •Generation adequacy
- •Reliability of electricity supplies
- •Assessment
- •Security of supply
- •Recommendations
- •6. Natural gas
- •Overview
- •Supply and demand
- •Consumption of natural gas
- •Trade
- •Production of biomethane
- •Market structure
- •Unbundling of the gas network
- •Wholesale
- •Retail
- •Price and tariffs
- •Financial support for biomethane
- •Infrastructure
- •Gas network
- •Recent changes in network
- •LNG terminal
- •Storage
- •Infrastructure developments
- •Biomethane infrastructure
- •Regional network interconnections
- •Gas emergency response
- •Gas emergency policy and organisation
- •Network resilience
- •Emergency response measures
- •Assessment
- •Recommendations
- •7. Energy, environment and climate change
- •Overview
- •Energy-related CO2 emissions and carbon intensity
- •Climate policy framework
- •The EU climate framework
- •Domestic climate policies
- •Policies to reduce emissions from the electricity sector
- •Policies to reduce emissions from the transport sector
- •Improving the energy efficiency of the vehicle fleet
- •Alternative fuels and technologies
- •Public transport and mode shifting
- •Taxation
- •Assessment
- •Recommendations
- •8. Renewable energy
- •Overview
- •Renewable energy supply and consumption
- •Renewable energy in total primary energy supply
- •Renewable electricity generation
- •Renewables in heat production
- •Renewables in transport
- •Targets, policy and regulation
- •Measures supporting renewable electricity
- •Wind
- •Solar
- •Hydropower
- •System integration of renewables
- •Bioenergy
- •Measures supporting renewable heat
- •Measures supporting renewables in transport
- •Assessment
- •Recommendations
- •9. Energy efficiency
- •Overview
- •Energy consumption by sector
- •Residential sector
- •Industry and commercial sectors
- •Transport
- •Energy efficiency policy framework and targets
- •Targets for 2020 and 2030
- •Energy efficiency in buildings
- •Residential building sector
- •Public sector buildings
- •Support measures
- •District heating
- •District heating market and regulation
- •District heating energy efficiency potential and barriers
- •Industry
- •Transport
- •Assessment
- •Buildings and demand for heating and cooling
- •District heating
- •Industry
- •Challenges
- •Recommendations
- •10. Energy technology research, development and demonstration
- •Overview
- •Public spending on energy RD&D
- •General RD&D strategy and organisational structure
- •Energy RD&D priorities, funding and implementation
- •Industry collaboration
- •International collaboration
- •IEA technology collaboration programmes
- •Other engagements
- •Horizon 2020
- •Baltic collaboration
- •Nordic-Baltic Memorandum of Understanding (MOU) on Energy Research Programme
- •Monitoring and evaluation
- •Assessment
- •Recommendations
- •ANNEX A: Institutions and organisations with energy sector responsibilities
- •ANNEX B: Organisations visited
- •Review criteria
- •Review team
- •IEA member countries
- •International Energy Agency
- •Organisations visited
- •ANNEX C: Energy balances and key statistical data
- •ANNEX D: International Energy Agency “Shared Goals”
- •ANNEX E: List of abbreviations
- •Acronyms and abbreviations
- •Units of measure
6. NATURAL GAS
gas supply and the low-carbon energy transition. The Estonian government recognises that biomethane has substantial energy potential in Estonia, particularly in the transport sector, and estimates that there is a total production potential of up to 370 mcm a year (mcm/y). Estonia has a set a goal to reach 15 mcm/y of biomethane production by 2020, and further increase the production level to 40 mcm/y by 2030 (MEAC, 2018a).
To meet these targets, Estonia has been promoting domestic biomethane production, mainly through measures such as subsidies (see section below on prices and tariffs). In 2018, two biomethane production units were established in Estonia, with a total capacity of around 62.5 gigawatt hours per year (6.5 mcm/y) (see section below on infrastructure). The total output of domestic biomethane production was around 4.5 mcm in 2018, only a fraction of the total gas consumption level and less than one-third of the goal set for biomethane production in 2020.
Market structure
Unbundling of the gas network
Estonia underpins liquidity and competition of the domestic gas market as the primary measure to sustain security of gas supply. The Competition Authority oversees the market, including transmission and distribution regulations and pricing. The Estonian gas market has been fully liberalised since 2007 and Estonia made amendments to the Natural Gas Act in June 2012, which underpinned the unbundling of the transmission system from the producer and/or seller via complete ownership unbundling, to comply with the EU’s third energy package of 2009.
The Estonian gas market used to be dominated by a single vertically integrated company, Eesti Gaas, whose biggest shareholder was Gazprom.2 At the time of the last IDR in 2013, Eesti Gaas was still the only gas importer and trader in the country, although legislation had encouraged open competition. The 2012 amendment to the Natural Gas Act obliged AS Eesti Gaas to separate its gas distribution utility by January 2013 and divest its ownership of transmission services by 2015. The ownership unbundling was finalised in March 2016 and the current Estonian TSO is publicly owned via Elering (formerly EG Võrguteenus AS before 20153).
Wholesale
Eesti Gaas AS was the only wholesaler on the Estonian gas market until 2015, when other companies began to compete on the wholesale market. The availability of competitive gas supply from the Lithuanian GET Baltic exchange, which added the possibility of virtual gas trading in Estonia in 2017, has facilitated the emergence of new gas suppliers.
In 2017, three companies imported gas into the Estonian market: Eesti Gaas AS (still the dominant importer, representing 88% of total 2017 imports), Elektrum Eesti OÜ (8% of imports) and Eesti Energia AS (4%). Following the expiration of its long-term contract
2Others included Germany’s E.ON, Finnish utility firm Fortum and Latvia’s Itera.
3Before 2015, EG Vorguteenus AS was an independent system operator (both transmission and distribution) that leased Eesti Gaas’ assets for providing transmission services.
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ENERGY SECURITY