Van partiële energiesystemen naar geïntegreerde energie systemen Workshop Groningen, 13 september 2013
Acknowledgment This project is supported by the European Commission through the Seventh Framework Programme (FP7). 2 / 57
ENSEA – International North Sea cooperation on Energy System Integration Environmental Planning Netwerken ENSEA = Targets Education Interregional cooperation Research Human Capital Governance Investments
Programma 1. Introductie ENSEA Koos Lok 2. Inleiding op ENSEA-thema’s: - Offshore oil & gas infrastructure North Sea Koos Lok - Power-to-Gas Catrinus Jepma - Bio-Energy Luc Rabou Pauze 3. Uitleg break-out sessies Catrinus Jepma 4. Break-out sessies in twee groepen 5. Samenvatting en vervolgstappen Catrinus Jepma 6. Afsluiting Borrel 4 / 57
Introductie ENSEA Wat is de doelstelling van de workshop vandaag? - Formuleren wat er in Nederland, in het bijzonder Noord-Nederland, rondom de Noordzee gebeurt en staat te gebeuren. - Bespreken samenhang en inzet triple-helix. - Van partiële energiesystemen naar geïntegreerde energiesystemen. - Waar moet Nederland zich komende jaren op inzetten? Wat is een geschikte rol voor Nederland? - Discussies over concrete thema’s: Offshore infrastructurele ontwikkelingen, Power-to-Gas en Bio-Energy. 5 / 57
Introductie ENSEA Wat is het ENSEA project? - ENSEA richt zich op versterking van samenwerkingsverbanden in de triple-helix. - Samenhang creëren in netwerken, kennis en projecten op en rondom de Noordzee. - Inventariseren en identificeren van ontbrekende elementen aan bijvoorbeeld de kenniskant, samenwerking private sector en de governance structuren. 6 / 57
Introductie ENSEA Concreet, waar praten wij over: - Afspraken in de private sector. - Kennisontwikkeling systeemintegratie. - Netwerken en governance versterken (OSPAR 2018). - Afstemming E&P belangen; verlengd onderhoud pijpleidingen. - Power-to-Gas pilot op boorplatform in de Noordzee. - Business case: transport elektriciteit door pijpleidingen d.m.v. waterstof. - Offshore pilot projects; schowcase. 7 / 57
Exploring the potential for optimal (re-)use of existing Oil & Gas infrastructure in the North Sea ENSEA Regional Workshop for the Northern Netherlands, September 13 2013 Koos Lok (Energy Valley) & Janneke Pors (IMSA Amsterdam)
Contents 1. Objectives of study 2. Working hypothesis of study 3. Current and future North Sea energy developments 4. First exploration of some North Sea energy developments : a) Decommissioning, b) Underground Gas Storage, c) Carbon Capture and Storage, d) Electricity grid, e) Ecological reuse 5. Intended follow-up of study 9 / 57
1. Objectives of study Overall objective • Explorative, science-based essay for EU policy-makers and a broad group of North Sea (energy) stakeholders which aims to open a discussion on system integration of energy infrastructure in the North Sea region in general and re- use of Oil & Gas infrastructure in specific. Research objectives • Examine the role and potential of the North Sea to contribute to the transition towards a renewable energy system in North-Western Europe? • Describe the main current and future offshore energy developments in the North Sea region and their objectives and functions • Explore the potential to re-use existing oil & gas infrastructure and maximize integration with (new) (renewable) energy infrastructure systems. • Identify the main boundary conditions for feasibility of potential re-use and/or system integration options • Sketch the main pathways to stimulate and accelerate potential re-use and/or system integration options 10 / 57
2a. Working hypothesis: Drivers Growing share of Significant role for Declining O & G renewable energy gas in all energy production North Sea scenarios Intermittency issue of Decommissioning renewable energy Declining gas obligations production & CO 2 -reduction targets New energy business increasing import fossil energy developments in dependency North Sea region Diversification of gas carriers Need for new Need for optimal use business model for of existing O&G infrastructure Need for optimal use Need for flexible, Need for efficient of renewable, reliable, affordable, investments in new affordable energy low-carbon energy infrastructure Fossil energy Renewable energy North Sea infrastructure 11 / 57
3. North Sea energy developments DCM DCM UGS O&G Pipelines Piping NORTH Grid UGS SEA UGS P2G P2G CCS P2G Wind CCS CCS Wind 12 / 57
4a. Decommissioning (DCM) • Decommissioning of offshore installations in the North Sea is planned for years to come because of economic depreciation and depletion of oil & gas fields. • O&G production until ca. 2040 and possibly later as oil prices rise and combinations with CCS increase the life time and productivity of fields. • 500-600 offshore installations (60-70 fields) need to be abandoned and decommissioned over the coming 20-40 years. • OSPAR 98/3 demands full removal to shore and disassembly, unless disused O&G installations could have ‘ another legitimate purpose in the maritime area authorised or regulated by the competent authority’. • There are no international guidelines on the decommissioning of disused pipelines. The regulatory regime is currently left to individual states. 13 / 57
4a. Decommissioning: Dutch example So whether we like it or not … Source: EBN 14 / 57
4a. Decommissioning: Costs • The technical costs of removing O&G installations in the North Sea are estimated at € 53 billion in the next 30 to 40 years. • Some estimate costs at €100 billion. • Costs are largely covered by governments (50-80%) as a result of tax deduction & co- ownership. • These costs include the costs of removal of jackets and topsides, plugging of wells and cleaning of seabed. • The costs of pipeline decommissioning are not included and are currently estimated at over £2bn (only UKCS) with the assumption that trunk lines are left in place and other pipelines are trenched and buried. 15 / 57
4a. Decommissioning: Who pays the costs? Who pays for decommissioning costs? e.g. cost estimate of jacket decommissioning: £ 10 billion ������ ����� ����� ������ 16 / 57
4b. Underground Gas Storage (UGS) • The need for underground gas storage is driven by: a. need for growing flexibility caused by the intermittency of renewable energy sources. b. need for supply security in case of an outage in a major supply source (Oxford, 2013). • Additional gas storage capacity demand in northwest Europe is estimated at 13-20 billion m 3 2030, depending on gas scenario (De Joode, 2010). • If approx. half of the currently known plans is met, this would be sufficient in meeting future demand. Realisation of many UGS plans, however, is currently uncertain. • Offshore storage is mainly suitable for large-scale, seasonal storage and/or strategic storage. • Of offshore locations partly depleted gas fields are the most favourable locations, as they have proven to trap gas and provide the possibility to use O&G infrastructure and ‘native gas’ as cushion gas. 17 / 57
4b. UGS: Role and benefits Strategic storage Security of supply Flexibility of supply Seasonal storage Natural gas Cheap supply Export & trade New business model gas sector Integration of Hydrogen / Optimal use of intermittent Methane renewable energy renewable energy Role of Benefits of gas storage gas storage 18 / 57
4b. UGS: ‘Rough’ project Field characteristics • The Rough gas field in the Southern North Sea was the world's first Capacity 10% UK offshore gas storage reservoir and is operational since 1985. peak use • The storage facility is built by British Gas and currently operated by Storage 2.8 BCM capacity Centrica Storage. Delivery 1.5 BCM • Rough is the largest gas storage facility in UK able to meet 10% of the capacity UK's winter peak day demand and representing around 75% of UK’s Field depth 2743 m current storage capacity. Distance to 25 km shore • Excess summer supplies are injected into the reservoir, to be produced during the winter to meet the peak demand. Figure: Rough facility 19 / 25
4c. Carbon Capture & Storage (CCS) 20 / 25
4c. CCS: Sleipner project • The Sleipner field is the world’s first offshore CCS project. The facility is operational since 1996 and will last until the accompanying gas field is depleted • The natural gas of Statoil’s Sleipner field contains around 9% CO 2 , which is removed and then injected into a geological layer below the Sleipner platform in the central North Sea, 250 km from land. • The CO 2 is stored in a sandstone formation 1000 m below the sea floor, the Utsira formation, and will stay there for thousands of years. • One million tonnes per year is stored, roughly 3% of the Norwegian CO 2 emissions in 1990. Until now eight million tonnes of CO2 have been stored. • The CCS technology was designed to fit on an offshore platform. 21 / 57
4d. Electricity grid • ….. 22 / 57
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