© 2014 Energy Technologies Institute LLP - Subject to notes on page 1
© 2014 Energy Technologies Institute LLP The information in this document is the property of Energy Technologies Institute LLP and may not be copied or communicated to a third party, or used for any purpose other than that for which it is supplied without the express written consent of Energy Technologies Institute LLP.This information is given in good faith based upon the latest information available to Energy Technologies Institute LLP, no warranty or representation is given concerning such information, which must not be taken as establishing any contractual or other commitment binding upon Energy Technologies Institute LLP or any of its subsidiary or associated companies.
Technologies and Modelling to Address The Challenges of Network Transition (REMOO 2014)Phil Proctor – Programme Manager Energy Storage and Distribution
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Energy Technologies Institute
• The Energy Technologies Institute (ETI) is a public-private partnership between global industries and UK Government
Delivering...
• Targeted development, demonstration and de-risking of new technologies for affordable and secure energy
• Shared risk
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ETI technology programme areas • Offshore Wind
• Marine
• Distributed Energy
• Buildings
• Energy Storage and Distribution
• Smart Systems and Heat
• Carbon Capture and Storage
• Transport
• Bioenergy
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Electricity:68000 km T&D
Natural Gas5300 km T&D
Heat 733km
Electricity:835,740 km T&D
Natural Gas289,000 km T&D
Heatkm
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Source: Energy Networks Association
Transmission
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Source: Energy Networks Association
Distribution
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0
50
100
150
200
250
300
0 2,000 4,000 6,000 8,000 10,000 12,000 14,000 16,000Dem
and
(GW
)
Half hours
Electricity and Heat over 1 Year
Low grade heat
© 2014 Energy Technologies Institute LLP - Subject to notes on page 1
Electricity
• Electricity networks could contribute £6-34bn to GDP by 2050 (TINA)
• Network design and operation are especially important for electricity networks, particularly:
– Designing for peak capacity– Management of peak loads
• Reinforcement, particularly of the distribution system, could become a major issue
• Investment in the networks is heavily influenced by the policy and regulatory mechanisms that exist
Electricity networks are expected to deliver a lot more of the UK’s energy in the future
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Gas
• What is the role of unconventional gas (e.g. shale gas) and what will be the effect on prices?
• Biogas and AD gas could also supplement natural gas supply – how much of a part will this play in lowering overall CO2 emissions?
• Gas with CCS could be deployed in the power and industry sectors
• How is it best to utilise the existing gas network in Great Britain, as gas usage changes?
Gas and gas networks have a continuing role to play in the delivery of energy
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Heat
• DHNs offer flexibility in future fuel supplies• The economics of possible pathways are
worth exploring• The network itself is a long term investment• ESCOs and local authorities are dominant
stakeholders• The UK Government has invested £1m for
feasibility studies for heat networks in Manchester, Newcastle, Nottingham, Leeds and Sheffield
• There are impacts on the electricity system that need to be understood
District Heat Networks (DHNs) can enable the transition to long term delivery of low carbon heat
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Hydrogen
• Hydrogen can be produced from several different sources and in several different ways
– Using renewable electricity– From fossil fuels or biomass– With and without CCS
• Transitions to the use of hydrogen in different sectors have varying levels of impact, from an infrastructure point of view
• Future transitions between its use in different sectors may prove cost effective (from an overall system perspective)
Hydrogen is amongst the most flexible and diverse of the energy vectors but uncertainty persists around both some of the technical solutions and the overall economics
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Our modelling work and insights from our programme areasare becoming increasingly important to the value the ETI delivers.
ETI system modelling is used by UK Committee on ClimateChange and DECC to support policy recommendations.
Some of the reports and publications ETI dataand insights appeared within in 2013:• EEF – Tech for growth –delivering green and growthpolicies through technology• Policy Connect – Future energyseries of reports• DECC Heat Strategy• Offshore Wind IndustrialStrategy, business andgovernment action report
Strategic insights and system modelling
• Element Energy report on thecosts of CCS for BIS and DECC• CCS in the UK – Governmentresponse to the CCS costreduction task force• BIS report – Global marketopportunities and UK capabilitiesfor future smart cities• DECC renewables roadmap
© 2014 Energy Technologies Institute LLP - Subject to notes on page 1
© 2014 Energy Technologies Institute LLP - Subject to notes on page 1
© 2014 Energy Technologies Institute LLP - Subject to notes on page 1
0
100
200
300
400
500
600
20102020
20302040
2050
TWh
Electricity GenerationRenewables (inc.geothermal)
Nuclear
Hydrogen
Biomassand waste(inc. withCCS)Fossilbased withCCS
0
100
200
300
400
500
600
20102020
20302040
2050
TWh
Electricity Consumption
Other
Transportelectrification
Buildingheating andcooling
Buildinglighting andappliances
Industry
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Future energy scenarios
Electricity use to 2050 Electricity generation to 2050
Source: National Grid (2013)
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Other CO2 emissions
Power Sector
Industry SectorBuildings Sector
International A & STransport Sector
-50
0
50
100
150
200
20102020
20302040
2050
Net CO2 Emissions by Sector
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0
200
400
600
800
1000
1200
2020 2030 2040 2050
TWh
Gas ConsumptionOther
Space heatingand hot waterDomesticcookingPower
0
20
40
60
80
100
120
140
160
180
200
2020 2030 2040 2050
TWh
Hydrogen ConsumptionPower
Transport
© 2014 Energy Technologies Institute LLP - Subject to notes on page 1
0
2
4
6
8
10
12
14
16
2021 2023 2025 2027 2029 2031 2033 2035 2037 2039 2041 2043 2045 2047 2049
Cum
ulat
ive
Net
wor
kR
einf
orce
men
t Cos
t (£b
n)
Network Reinforcement Costs to Support Plug-in Vehicles
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© 2014 Energy Technologies Institute LLP - Subject to notes on page 1
Storage solutions for balancing generation and demand
0.00E+00
1.00E+02
2.00E+02
3.00E+02
4.00E+02
5.00E+02
6.00E+02
2010 (Historic) 2020 2030 2040 2050
Storage Solutions (GWh availability) Pumped Storage ofElectricity
Compressed AirStorage of Electricity
Battery Storage ofElectricity
Geological Storage ofHydrogen
Building Space HeatStorage
Building Hot WaterStorage
District Heat Storage
Geological Storage ofSeasonalH2
Distribution ScaleElectricity Storage
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A range of technology solutions
GW1
MW100
MW10
100 kW
Microsecond Second Minute Day Week Month
10 kW
kW1
Dischargeduration
Electricity-onlyapplications Thermal-onlyapplications Electricityandthermalapplications
Demand
shifting
andpeak
reduction
ArbitrageSeasonalstorage
Voltage
support
Hour
Spinningand
non-spinning
reserve
Load
following
1 MW
Waste
Variable
supply
resource
integration
Combinedheatpower
Source. IEA Technology Roadmap Energy Storage 2014
kW1 kW10 kW100 MW1 MW10 100MW GW1
Reserve & ResponseServices
Transmission & DistributionGrid Support
Bulk PowerManagement
KEYTypes of Storage
Hydrogen-related
Mechanical
Electrochemical
Electrical
ThermalHigh-Power SupercapacitorsSuper Conducting
Magnetic Energy Storage
Flywheels
Nickel Metal Hydride Battery
Nickel Cadium Battery
Lead Acid Battery
Li-ion Battery
High-EnergySupercapacitors
Advanced Lead-Acid Battery
Sodium-Sulphur Battery
Flow Batteries
Cryogenic Energy Storage
Compressed AirEnergy Storage
Hydrogen & Fuel CellsPumped HydroPower Storage
Source. Pathways for Energy Storage in the UK, Cemte for Low Carbon Futures 2012
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System Modelling Toolkit• Project to support the future design, operation and
roll-out of cost effective CCS systems in the UK
• A modelling tool-kit capable of simulating the operation of all aspects of the CCS chain
• Support initial conceptual design and eventual detailed design and operation of CCS systems
Project Partners© Image courtesy of PSE enterprises 2014
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Waste Gasification • Competition to design the most efficient,
economical and commercially viable gasification demonstrator plant
• Advanced Plasma Power, Broadcrown and Royal Dahlman selected for the competition. Each design capable of providing a step change in efficiency compared to existing gasification projects in the UK
• Each of the plant designs will need to operate at a net electrical efficiency of at least 25% at 5-20MW scale
Project Partners
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chemicals and m
aterials
Methane (bioSNG)
Mixed alcohols synthesis
Furnace/Boiler
Fuel cell
Ethanol (fermentation)
Fischer Tropsch
Engine/Turbine
direct combustion
chemical synthesis
Gasification
Methanol synthesis
Carbon monoxide
Hydrogen
Ammonia
DiMethylEther (DME)
Diesel / jet fuel
n-paraffins
Fertilisers
Acetyls
MTO / MOGDFormaldehyde
Fuels
Cleaned syngas
Heat
Power
Courtesy of NNFCC
Gasification to produce clean syngas provides flexibility; mitigating against future energy system uncertainties
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Electricity and Heat over 1 Year
0
50
100
150
200
250
300
0 2,000 4,000 6,000 8,000 10,000 12,000 14,000 16,000
Dem
and
(GW
)
Half hours
Low grade heat
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Market timing – overall UK energy system
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Market timing – Smart systems and heat
prepare
20502040203020202010
UK space heat production
oil
gas
ASHP
DHN
No targets-80% CO2
TWh
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• Software tool to design cost-effective local energy systems for the UK
• Designed in partnership with local authorities
• Demonstrating the capability to create future-proof and economic local heating solutions for the UK
Project Partners
EnergyPath
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Various challenges resulting in market inertia
• Incumbent gas system offers many advantages
• Consumers generally not engaged in energy systems and few driven by climate change
• Several new and largely unfamiliar heat solutions – dominant design not driven by cost
• Investment in local area energy assets will be significant but uncertain market demand and policy direction
• Local area planners lack design tools and capability to explore options and impact Elements for successful market growth
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© 2014 Energy Technologies Institute LLP - Subject to notes on page 1
Energy Infrastructure Calculator• Provides capability to understand the costs
of new, repurposed and abandoned electricity, gas, heat or hydrogen networks up to 2050
• The potential for new technologies to reduce network costs can be evaluated
£0
£1,000,000,000
£2,000,000,000
£3,000,000,000
£4,000,000,000
£5,000,000,000
£6,000,000,000
£7,000,000,000
2015 2020 2025 2030 2035 2040 2045 2050 2055 2060 2065 2070
Cum
ulat
ive
Cost
Year
Cumulative cashflow
Elect Capex Gas Capex H2 Capex Heat Capex Capex Add-Ons
Elect Opex Gas Opex H2 Opex Heat Opex
25%
61%
14%Labour
Material
Plant
38.79%61.21%
0.00% 0.00%New Build
Refurbishment
Repurposing
Abandonment
Project Partners
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Impact AnalysisDevelop Example Networks Evaluate new technologies and network solutions e.g.
HVDC
Source: Siemens.com
FCLS
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Source: Grubb M (2004), Technology Innovation andClimate Change Policy: an overview of issues and options.
Government
Business and finance community
Policy and programme interventions
Investments
Basic R&D
Idea
Applied R&D Demonstration
Consumers
Technology ‘valley of death’
Product/technology push
Market engagementprogrammes
Strategic deploymentpolicies
Barrierremoval
Market pull
Costperunit
Marketexpansion
Pre-commercial Fully-commercial
Niche marketand supported
commercial
Deployment
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The Fault Level Challenge
• As more renewable energy sources are connected to the UK distribution system (Distributed Generation), fault current levels increase
– CHP systems typically have fault contribution of 5-8 x rating– PV typically 1-1.2 x rating– Wind depends on system design
• Networks are reaching fault current rating limits– e.g. 20% of UKPN’s London network has high fault levels (>95% of rating)
UK energy policy
More generation
sources being
connected in distribution networks
Increased fault levels
Existing equipment
ratings becoming exceeded
Substantial infrastructure
investment
Major operational restrictions
Inability to connect new generation
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Slovenia Household Energy Consumption by fuel type (2009)Source: Slovenian Environment Agency
Slovenia Household Energy Consumption
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Consequences• Conventional (passive) techniques to
manage these fault currents introduce additional cost and negative impact on operational complexity, power quality, power system stability, reliability and security of supply
• A significant number of new DG projects do not proceed as a consequence, and fault current levels are becoming a major barrier to the widespread deployment of low-carbon distributed generation
• Also a major barrier to smart distribution networks with increasedoperational efficiency, flexibility, reliability and resilience
• Active Fault Current Limiters (FCLs) will provide a credible, commercially acceptable means of overcoming these barriers
Conventional (Passive) Fault Current Management Techniques
Switchgear reinforcement
Standard approach requiring high investment in most cases; also assumes switchgear exists at required ratings
Network splitting & reconfigurationLow cost but leads to operational restrictions, and often lower power quality
Passive current limiting reactors & high impedance transformers
Comparatively low cost but introduces voltage drops and much increased steady-state losses
Sequential switching Higher operational complexity, not fail-safe so a higher risk solution
Connecting DG at higher voltages Increased connection infrastructure investment
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Newhaven Town Substation (at outset)
• Newhaven Town Substation (33/11kV Primary substation), East Sussex, UK
• Plan for site works to include new flood defences (under a parallel UKPN project) as well as plinth for FCL and complete new switchroom building for future site flexibility
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Site Electrical Schematic
T210MVA
T110MVA
T310MVA
G1G2
GT160MVA
GT260MVA
12 11
6106 05
07
Newhaven Grid 33kV
Peacehaven 33kV / Newhaven ERF
Seaford
0910
13515260 Newhaven
Town 11kV
FCL
LEGEND132kV
33kV
11kV
61
14
15
53
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FCL Shipment from Australia to UK
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FCL Installed
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Test Results (extract) • Site worst case prospective fault level (4.36kA single phase fault)
• 30% initial peak limitation as required
• 55% steady state RMS limitation
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Energy Storage (Isentropic)
Project Partners
Pumped Heat Electricity Storage
• Distribution Scale• Electrical energy to heat and cold in reversible
process• Inert gas system – no chemical handling• System range 700kW – 6MW• Multiple storage services capability• £400/kW, £45/kWh