Energy Technologies Institute (ETI)

1. To investigate the costs that domestic electricity suppliers in Great Britain might face in 2030.
2. To make projections on the assumption that, unless formally announced, no changes are made to the electricity market arrangements in place today
3. To focus in particular on the hourly variation and seasonal shape of supplier costs

1. To investigate the costs that domestic electricity suppliers in Great Britain might face in 2030.
2. To make projections on the assumption that, unless formally announced, no changes are made to the electricity market arrangements in place today
3. To focus in particular on the hourly variation and seasonal shape of supplier costs

1. Hourly Prices: Detailed Retail Cost Stacks
2. Annual Figures ( to add ) :
   • Installed Capacity
   • Generation
   • Wholesale price and captured prices for renewable technologies
   • Imports and exports with neighbouring markets
   • Total carbon dioxide emissions

The Characterisation of Feedstocks Project was commissioned by The Energy Technologies Institute (ETI) and carried out by Forest Research, and Uniper Technologies Ltd (formerly part of E.ON).

Five crops were considered: Miscanthus, willow short-rotation-coppice (SRC), poplar SRC, poplar short-rotation-forestry (SRF), and conifer SRF.

Eight studies were carried out:
In phase 1 (fieldwork spring to autumn 2015):
1. To examine the impact of climate zone, soil type, harvesting time, and storage on Miscanthus, willow SRC, poplar SRC, poplar SRF and conifer SRF
2. To examine the variation between and within fields of Miscanthus and willow SRC
3. To examine the feedstock characteristics of willow SRC and poplar SRF leaves
4. To examine the feedstock characteristics of Miscanthus before and after pelletising
In phase 2 (fieldwork November 2015 to November 2016):
V1. To examine the impact of harvest time on Miscanthus characteristics
V2. To examine the impact of harvest time on willow characteristics
V3. To examine the impact of varieties on willow characteristics
V4. To examine the impact of storage time on Miscanthus characteristics

• Stage 1 aims to characterize market and policy frameworks, business propositions, and the integrated vehicle and energy infrastructure system and technologies best suited to enabling a cost-effective UK energy system for low-carbon vehicles, using the amalgamated analytical toolset.
• Stage 2 aims to fill knowledge gaps and validate assumptions from Stage 1 through scientifically robust research, including real world trials with privatevehicle consumers and case studies with business fleets. A mainstream consumer uptake trial will be carried out to measure attitudes to PiVs after direct experience of them, and consumer charging trials will measure mainstream consumer PiV charging behaviours and responses to managed harging options

Ecosystem Land Use Modelling and Soil Carbon Flux Trial (ELUM) was funded and commissioned by the Energy Technologies Institute (the ETI) and carried out by the Centre for Ecology and Hydrology (CEH), the University of Aberdeen, the University of Southampton, Forest Research, Aberystwyth University, the University of Edinburgh and the University of York.

The ELUM project aims were to provide greater understanding on the greenhouse gas (GHG) and soil carbon changes arising as a result of direct land-use change (dLUC) to bioenergy crops, with a primary focus on the second-generation bioenergy crops Miscanthus, short rotation coppice (SRC) willow and short rotation forestry (SRF).

Experimental fieldwork on Miscanthus, SRC Willow, and SRF, and adjacent control sites, was conducted at locations across the length and breadth of mainland UK to capture data across both temporal and spatial scales.

• ESCOs 'right-size' heating solutions then provide supply contracts with price guarantees
• HEMS enable optimised ToU tariffs and DR benefits via localstorage
• Hybrid heat pump driving arbitrage opportunities in the home

1. The pathway results (capacity, generation ,costs) for all scenarios. The pathway results are the output of the capacity optimisation model (LT: Long-Term)
2. Levelised cost of electricity and value of capacity for the Base Case (Model LT: Long-Term)
3. Detailed dispatch results for the Base Case for a spot year (2030). The dispatch results have been simulated with the full year dispatch model (ST: Short-Term)
4. Dispatch results for two spot years (2030, 2050) for the rest of the scenarios. These results were simulated with the capacity optimisation model (LT)
5. Comparisons between the Base Case and sensitivities
6. Comparisons between Base Case and other GB scenarios

The TEAB project compares the costs, efficiencies and GHG emissions of biomass supply chains with and without significant pre-processing, to assess whether and how pre-processing steps can benefit UK bioenergy supply chains.

Ten supply chains were selected for modelling and analysis in the project, two of which generate heat, and eight generating power. These are compared in groups according to their shared conversion technology, and all the chains are able to use a blend of Miscanthus and woody feedstocks (from 0-100%).

Available here are gPROMS and Excel models describing bioenergy supply chains, and project reports. Further README files in the models and reports sub-directories describe the contents further.

• Indicative fuel cell light and heavy vehicle specifications for each of the truck and bus categories currently used by the ETI
• Fuel cell system component costs by year and global production volume
• Initial production cost, TCO and CO2 savings assessment
• Equivalent data for battery electric vehicles for comparison purposes

• A detailed analysis of the potential cost components that determined the price for domestic retail electricity supply in 2030.
• Based on a number of scenarios for the capacity mix in 2030.
• The project was delivered by Baringa, the independent business and technology consultancy.

This knowledge building project sought to outline a number of price scenarios for the retail price of electricity across a number of different energy vectors in 2030. This was to help build the ETIs evidence base of the operation of future UK energy systems and markets. This was also to stimulate a discussion about the realities of 2030 electricity system operation and uncertainties about this.

This project, which was delivered by Baringa built on their existing time series of hourly supplier electricity costs for 2030. They delivered an hourly electricity price series for 2030 based on traceable assumptions for three different 2030 supply-demand scenarios.

The findings from this project helped inform two existing ETI projects. Firstly, the Consumers, Vehicles and Energy Integration project which sought to understand the required changes to market structures and energy supply systems in order to encourage wider adoption of plug-in vehicles and their integration into the energy system. It also informed the Integrated Heat project which developed a modelling tool to evaluate the opportunities and challenges for electric heating to meet future UK household requirements.

• Project to develop a technology platform to build blades in excess of 100 metres
• Use of carbon fibre in manufacture enabled longer blades with increased swept area to be built
• Manufactured through smaller component pieces rather than full-length mouldings

The ETI commissioned Isle of Wight SME Blade Dynamics to develop a technology platform to build blades in excess of 100m for use on the next generation of large offshore wind turbines with a capacity of 6MW.

New design techniques were used incorporating carbon fibre along with other composite materials.This created blades weighing up to 40% less and allowed for cost savings in the overall blade, turbine and tower structure to be made, when the system is designed as a matched unit. This helps reduce the cost of energy.

The manufacturing process sees the blades constructed through the assembly of smaller, more accurate and easily manufactured component pieces as opposed to the traditional large and expensive full-length mouldings.

In October 2015, Blade Dynamics was acquired by GE.The acquisition by one of the world largest companies and the resources and market reach they bring with them should enable the technology to progress quickly and reach a wide global market.

Press Release – dated 19 May 2011: extract

This is a six-month long £455,000 Biomass to Power with CCS project which will provide clarity on what further developments are required to better understand the biomass to power with CCS sector and what opportunities it could generate for the UK. The research will incorporate feedback from existing international demonstration projects that incorporate biomass co-firing, as well as dedicated biomass to power conversion. The project is being delivered through CMCL Innovations, in conjunction with Cambridge University, Doosan Babcock, Drax Power, EDF Energy, E4tech, Imperial Consultants, and Leeds University.

• Research project to identify how retrofitting of existing housing stock could be accelerated
• Identified a series of potential retrofit approaches to UK housing stock
• Approaches identified were tested within our Smart Systems and Heat programme

• FEED Study for a CCS plant capable of capturing up to 95% of CO2 emissions from coal fired power stations
• Project aimed at pre-combustion
• Involved CO2 removal by physical separation

We have invested 3.5m to date in a project with Costain to design a carbon capture pilot plant capable of capturing up to 95% of CO2 emissions from coal fired power stations.

The project is aimed at pre-combustion carbon capture applications, involving CO2 removal by physical separation. Costain has produced a frontend engineering design study for a demonstration unit, working with the University of Edinburgh and Imperial College, London.

The Condition Monitoring project was led by Moog Insensys and included Romax, SeeByte, the University of Strathclyde, E.ON and EDF.

It looked towards developing an intelligent integrated, predictive, condition monitoring package for wind turbines, which improved reliability and increased availability by reducing downtime by up to 20% and led to potential savings of 6,000 per turbine.

Launched in September 2009 with5.4m of ETI funding the system was tested on turbines belonging to EDF in France and E.ON in North Yorkshire. The project completed in summer 2013.

• Stage 1 aims to characterize market and policy frameworks, business propositions, and the integrated vehicle and energy infrastructure system and technologies best suited to enabling a cost-effective UK energy system for low-carbon vehicles, using the amalgamated analytical toolset.
• Stage 2 aims to fill knowledge gaps and validate assumptions from Stage 1 through scientifically robust research, including real world trials with private vehicle consumers and case studies with business fleets. A mainstream consumer uptake trial will be carried out to measure attitudes to PiVs after direct experience of them, and consumer charging trials will measure mainstream consumer PiV charging behaviours and responses to managed harging options.

• Project to examine the economical and technical feasibility of Tension Leg Platform (TLP) design
• Investigated offshore 5MW wind turbines with hybrid concrete/steel floater and concrete counter weight
• Showed that TLP based solutions could help reduce the costs of offshore wind in the UK

This project was led by Blue H Technologies. The consortium also included BAE Systems, Romax, Centre for Environment, Fisheries and Agricultural Science, EDF, PAFA Consulting Engineers and Sea & Land Power and Energy Ltd. It delivered an economic and technical feasibility study for a novel floating TLP 5MW offshore wind turbine including a hybrid concrete/steel floater and a concrete counter weight.

The project started in January 2009 with an ETI investment of £3.3m and completed in the summer of 2010. The project provided us with valuable data on TLP floating foundation design and cost. It helped shape the next stage of our Offshore Wind programme.

Our analysis also concluded that the cost of energy sites to the South West, North West and North East of the UK could provide highly competitive levelised energy costs.

• The Infrastructure Cost Calculator was developed to allow users to calculate and compare network transition costs across a number of scenarios and vectors, including electricity, gas, heat and hydrogen
• The Infrastructure Cost Calculator provides users with access to a robust, centrally stored database of infrastructure costs based on current industry data
•  Users can define and compare different scenarios to understand long term investments for a UK transition to a low carbon energy network

In order to assess the opportunities for meeting long term emissions reductions targets, it is necessary to understand the costs and performance of the energy infrastructure that will carry energy from where it is generated, to where it is consumed. Example capabilities of the Infrastructure Cost Calculator include:

• Impact Analysis: testing new innovations to understand how they impact on the cost of networks.
• Sensitivity Analysis: investigating how cost changes based on future scenarios impact upon lifetime network costs.
• Transition comparisons: investigating the difference between the costs of pathways to reach a low carbon energy network.
• Time implications: analysing the financial impacts of carrying out infrastructure changes over different time periods.

• A FEED study into the design of an offshore wind floating platform system demonstrator
• Tension Leg Platform designed in partnership with Alstom 150-6MW Haliade turbine

Floating turbine technology is of strategic importance to any future UK offshore wind strategy. 

This project drew upon earlier ETI studies. These showed that floating foundations could be very attractive, by allowing the UK to access higher wind sites that are reasonably close to shore. Our analysis suggests that floating offshore wind has the medium to long term potential to deliver attractive energy costs.

The Glosten Associates, a US-based navel architecture and marine engineering firm designed a tension leg platform (TLP) floating system demonstrator through a Front End Engineering Design (FEED) Study.

This has shown that UK offshore wind energy costs could fall to below £85MWh by the late 2020s, with further reductions possible as the technology matures. The floating platform is designed to provide high capacity factors in wind speeds exceeding 10 metres per second in water between 50 and 1200 metres deep. The TLP technology is suitable for water depths from as low as 55 metres (much lower than conventional TLP developed from oil and gas experience) up to several hundred metres. Floating foundations could enable the UK (and other countries) to develop a wider range of offshore wind sites that are relatively close enough to shore, rather than being limited to sites suitable for foundations fixed to the seabed.

The findings and deliverable reports from this project have been made available to the Offshore Renewable Energy Catapult the technology innovation and research centre for offshore wind, wave and tidal energy to inform their ongoing work in the area of offshore wind.

Extract from press release – dated 27 October 2009:

An extensive study to look at increasing efficiency and cutting emissions of heavy-duty vehicles (HDV) and off-road machines has been launched today (27 October) by the Energy Technologies Institute (ETI). The ETI study will evaluate heavy-duty vehicles such as coaches, buses and mining vehicles, determine drive-cycles showing the types of UK usage patterns for each class of vehicle, identify the potential efficiency improvement technologies and evaluate the benefits case for each one. The project, which is expected to last nine months, will focus on the technologies which have the largest potential to reduce CO2 emissions.

The UK HDV fleet currently consumes more than 13.5 billion litres of liquid fuel each year and contributes 8.96% to overall UK carbon emissions. Significant CO2 reductions across the entire HDV fleet are therefore critical to achieving the overall UK target of an 80% reduction by 2050. The project, led by Ricardo and including Caterpillar and Rolls-Royce, will carry out a detailed analysis of the UK’s heavy-duty vehicle fleet and identify ways in which technological solutions can increase its efficiency and contribute to a reduction in liquid fuel consumption.

ETI Chief Executive Dr David Clarke said: “Carbon reduction from heavy-duty vehicles presents a significant challenge. Many of the current options to reduce CO2 emissions from light-duty vehicles are not feasible for heavy duty applications. Due to the high energy usage, strategies such as electrification are unlikely to be successful, so the aim is to look at ways of increasing the efficiency of use of liquid fuels.Also, the vehicle types, applications and technologies to improve efficiency are diverse so it is difficult to find a single universal technological solution. This project will allow us to identify potential technological solutions to increasing efficiency and reducing liquid fuel consumption across the heavy-duty vehicle fleet.”

Neville Jackson, Director of Advanced Technology, Ricardo said: ”Fuel efficiency has always been the key product attribute for heavy-duty vehicles. Whilst Ricardo and our project partners have made significant progress in reducing fuel consumption, opportunities still exist to identify and develop further technologies that can enable heavy duty engines to make their contribution to reductions in carbon emissions. This study will focus on technologies that deliver benefits in real world applications and that can support the UK as a leader in low carbon products.”

• Investigation into concepts and technologies required to deliver significant cost reductions
• Swept areas (blade size) needed to be larger than was usual at the time of the project
• The optimum size of turbine identified was larger than the historical state of the art design

The Helm Wind project carried out an unconstrained investigation into the concepts and technologies required to deliver significant cost of energy reductions for offshore wind. This included rotor diameter, geometry and speed, number of blades, upwind and downwind orientations, drivetrain options and support structures. Led by E.ON, the consortium also included BP, Rolls-Royce and the University of Strathclyde.

The project started in January 2009 with an ETI investment of £2.5m. The project finished in the autumn of 2010. It identified that sufficient improvements could be made through technology innovation to deliver energy costs that were comparable with 2010 onshore wind costs one of ETI objectives for the offshore wind programme.

This required innovation in rotor aerodynamics and diameter, drivetrain technologies and electrical systems. The consortium also identified that the optimum turbine size for offshore wind; was significantly larger than the historical state of the art design.

Hydrogen is likely to be an increasingly important fuel component in the future. This 3.5m project was designed to advance the safe design and operation of gas turbines, reciprocating engines and combined heat and power systems using hydrogen-based fuels. Through new modelling and large-scale experimental work the project sought to identify the bounds of safe design and operation of high efficiency combined cycle gas turbine and combined heat and power systems operating on a range of fuels with high and variable concentrations of hydrogen. The goal of the project was to increase the range of fuels that can be safely used in power and heat generating plant. The project involved the Health and Safety Laboratory, an agency of the Health and Safety Executive, in collaboration with Imperial Consultants, the consulting arm of Imperial College London

The Industrial Doctorate Centre for Offshore Renewable Energy (IDCORE) trains research engineers whose work in conjunction with sponsoring companies aims to accelerate the deployment of offshore wind, wave and tidal-current technologies. This is to help meet the UK’s ambitious renewable energy targets. Students undertake a four year full time course including time with a sponsoring company working on “real world” applications and research initiatives to obtain their doctorates.

The centre is funded by the ETI and the Engineering and Physical Sciences Research Council (EPSRC).

Academic partners / research facilities:

• University of Edinburgh
• University of Exeter
• University of Strathclyde

Programme partners:

• HR Wallingford
• The Scottish Association for Marine Science

Industrial partners / sponsoring companies:

• Cefas
• EDF Energy
• E.ON
• GE & Alstom Energy
• Narec
• FloWave
• TT Tidal Energy Ltd
• Siemens/MCT
• Lloyd’s Registrar
• TWI
• DNV GL
• Sgurr Energy
• Alba Turn

• A feasibility study on the technical and commercial viability of vertical axis turbines
• Investigated 5MW and 10MW designs based on aerogenerator rotor concepts
• The project was delivered by a consortium featuring industry and academia.

The NOVA project delivered a feasibility study which evaluated the technical and commercial viability of a 5MW and 10MW vertical axis turbine, based upon the aerogenerator rotor concept. It also evaluated specific design options for the rotor, drivetrain and foundations.

Project Managed by OTM Consulting Ltd, the consortium also included Wind Power Ltd, the Centre for Environment Fisheries and Aquaculture Science and the Universities of Cranfield, Sheffield and Strathclyde. Started in January 2009 with an ETI investment of 2.8m and completed in summer 2010 the project provided the ETI with valuable information that helped shape the next stage of our Offshore Wind programme.

The project showed that the Nova concept was commercially and technically feasible. Our further analysis suggested that horizontal access wind turbines will evolve faster than vertical access wind turbines and provide lower costs of energy in the short to medium term.

• Indoor turbine test rig based at the Offshore Renewable Energy Catapult (OREC) in Northumberland
• Designed to allow the whole offshore wind drivetrain to be tested onshore before deployment offshore

In project ETI-WIND-5 Two consortia, GE Energy Power Conversion / MTS and Horiba, were commissioned to deliver competing technical designs for an indoor test rig capable of testing a complete wind turbine drive train and nacelle.

GE Energy Power Conversion and MTS were subsequently commissioned to design, develop and commission the test rig, which is sited at OREC in Blyth, Northumberland. We have invested over £25m (ETI-WIND-5 + ETI-WIND-6) in the concept, in partnership with Innovate UK who funded the Narec building and supportive infrastructure at Blyth. 

The test rig has been designed to allow the whole turbine nacelle to be tested, in a purpose-built, onshore test facility before being exposed to the challenging offshore conditions. This will help reduce the technical and commercial risks of mass production and deployment.

• Indoor turbine test rig based at the Offshore Renewable Energy Catapult (OREC) in Northumberland
• Designed to allow the whole offshore wind drivetrain to be tested onshore before deployment offshore

Two consortia, GE Energy Power Conversion / MTS and Horiba, were commissioned to deliver competing technical designs for an indoor test rig capable of testing a complete wind turbine drive train and nacelle.

• Examined potential impact of plug-in vehicles on the UK grid
• Assessed recharging infrastructure required to support any mass-market adoption of plug-in vehicles
• Defined a system architecture to integrate vehicles, electricity networks, charging points and payment systems

This project looked at the potential impact of electric vehicles on the UK electricity distribution grid. It also assessed the recharging infrastructure required to support mass market adoption of plug-in vehicles in the UK.

In collaboration with a number of stakeholders it defined a system architecture to integrate vehicles, electricity networks, charging points and payment systems.

This project carried out an

• Analysis of the potential size of the market for plug-in vehicles in the UK
• Analysis of the potential total level of investment needed in the UK
• Analysis of the potential total level of carbon offset in the UK

This project provided a strategic level analysis of the potential size of the market for plug-in vehicles, the total level of investment needed and the total carbon offset for the UK.

The analysis was conducted against a set of scenarios including technology breakthrough, macro-economics and government policy. It determined the viability of different pathways to a self-sustaining mass market for plug-in vehicles.

The Performance Assessment of Wave and Tidal Array Systems (PerAWaT) project, launched in October 2009 with £8m of ETI investment. The project delivered validated, commercial software tools capable of significantly reducing the levels of uncertainty associated with predicting the energy yield of major wave and tidal stream energy arrays. It also produced information that will help reduce commercial risk of future large scale wave and tidal array developments.

• Development and demonstration of a pre-saturated core fault current limiter
• Product design offers advantages of a non-superconducting pre-saturated core fault current limiter with instant response and recovery and a small footprint based on established transformer design and build process
• Commissioned into service in May 2013 at a UK Power Networks primary substation in Newhaven, where it has performed excellently.

Designed by GridON, this pre-saturated core fault current limiter uses a direct current coil to magnetically saturate the iron core, providing a very low impedance during normal operation and a high impedance in response to a network fault. It is based on combining industry standard proven transformer technology and GridON's concept of magnetic flux alteration to saturate the iron core.

The limiter is fully scalable for use at voltage levels on both distribution and transmission systems. Its design removes the need for superconducting components or associated cryogenic systems.

1. A review of latest theoretical estimates of land available for biomass production in the UK and Europe.
2. A desk study to identify additional constraint layers which could be used to refine the ETI’s own in-house land availability constraint masks. The suitability of these additional constraint layers was tested through field surveys.
3. A review of the steps and agencies involved in land use change to bioenergy crops and forestry.
4. Case studies of three farmers who have planted bioenergy crops, focusing on the financial and food production impacts of their decision.

Fault current levels are becoming a significant barrier to the installation of low-carbon and other distributed generation. Management of these fault levels is also a key enabler for the growth of smart distribution systems, offering improved operation, flexibility and efficiency. This project will develop and demonstrate a resistive superconducting fault current limiter device, which will reduce the impact of faults on electricity distribution networks, helping the cost effective growth and increased flexibility and reliability of distribution systems, with more low carbon electricity generation installed in the distribution system. It will be developed by Applied Superconductor Ltd, based in Blyth, Northumberland, in partnership with Rolls-Royce, and will be installed on the network at a Western Power Distribution substation in Loughborough, Leicestershire. E.ON will act as technical consultants.

• Phase one will focus on a gap analysis.
• Phase two will look at developing a series of improved methodologies from the gaps identified in phase one
• Phase three will demonstrate how to apply these methodologies. Finally, phase 3 will develop a “how to” guide for use by project engineers.

The 541k project retrofitted five types of domestic property.

1. A pre-1919 mid-terracehouse.
2. A pre-1919 detachedhouse.
3. A 1919-44 semi-detachedhouse.
4. A 1945-64 semi-detachedhouse
5. A post 1980 semi-detachedhouse.

This project provided insights into consumer behaviour relating to the heating decisions they make.

The project consisted of four pieces of consultancy work to provide the overall view of consumer behaviour. These pieces of workexamined:

• Consumer response and behavioursanalysis
• A literature review of personality and risky heatdecisions
• Household heating designaids
• Segmentationanalysis

• Project specified the data system functionality and proposed architecture to fulfil the information and service requirements of a smart energy system;
• Functionality addressed the question of data security.

Economics consultancy Europe Economics were appointed to develop a modelling framework to help local authorities effectively evaluate the benefits of creating more energy efficient buildings and networks. Working in collaboration with AECOM, who specialise in building data collection and management, the model will help local authorities to scope out potential future opportunities and benefits for their particular location.

This project complemented the EnergyPath Networks software modelling tool (ETI-SS1203) which was used in the planning of cost-effective local energy systems.

In conjunction with our SSH programme delivery partners, the Energy System Catapult we are working with Newcastle City Council, Bridgend County Borough Council and Greater Manchester Combined Authority to support energy infrastructure planning using the EnergyPath Networks tools.

EnergyPath is a registered trade mark of the Energy Technologies Institute LLP

The ETI commissioned the HEMS & ICT Market project to undertake an in depth study and assessment of HEMS along with what data, processes and controls andpotential additional services enabled via a linked ICT system. The project delivers key insights and findings in terms of potential future offerings and capabilities of these products along with market assessment information. The aim of the project was to characterise the existing market for HEMS and ICT systems and to quantify themarket/commercial opportunities for future HEMS and ICT propositions for both consumer and business.

ETIs research highlights that a Home Energy Management System (HEMS) should be a key component of a future smart energy system, but given the fact that most consumers do not willingly engage with their energy system any product solutions need to be consumer focused if they are to be effective. Therefore this project to design an advanced HEMS is a core component of the ETIs Smart Systems and Heat programme (now delivered by the Energy Systems Catapult) to make energy and heat consumption more consumer focused.

As part of the two year project, the system that is developed will be installed and tested in homes during the winter of 2016 and the results analysed to give an insight into consumer patterns, their electricity and gas use and the building and heating system performance. This will provide a significant dataset of consumer behaviours, energy use and building characterisation to develop further future products. Providing a secure and scalable platform will also help to integratemore appliances in the home and allow valuable services and applications to be developed, deployed andmanaged.

ETIs research highlights that a Home Energy Management System (HEMS) should be a key component of a future smart energy system, but given the fact that most consumers do not willingly engage with their energy system any product solutions need to be consumer focused if they are to be effective. Therefore this project to design an advanced HEMS is a core component of the ETIs Smart Systems and Heat programme (now delivered by the Energy Systems Catapult) to make energy and heat consumption more consumer focused.

As part of the two year project, the system that is developed will be installed and tested in homes during the winter of 2016 and the results analysed to give an insight into consumer patterns, their electricity and gas use and the building and heating system performance. This will provide a significant dataset of consumer behaviours, energy use and building characterisation to develop further future products. Providing a secure and scalable platform will also help to integrate more appliances in the home and allow valuable services and applications to be developed, deployed and managed.

The Integrated Electric Heating Project provided a modelling tool to evaluate the opportunities and challenges for electric heating to meet UK household requirements. The tool will be used to create and evaluate upgrade pathways for a small number of housing archetypes informed by detailed information gathered from dwelling participating in the recent Home Energy Management System trial.

About the project

Management consultancy Baringa Partners are delivering this new project to develop the capability to improve understanding with regards the future role of energy storage and the provision of cross-vector system flexibility within the context of the overall UK energy system.

The project is split into two stages:

The first stage will provide a modelling framework that will help us to understand the services that storage and flexibility could provide for multiple energy vectors electricity, heat, hydrogen and gas at different time and space resolutions. It will provide a detailed examination of the operation of storage within the energy system and an assessment of its near term (5-10 years) market potential.

The second stage will enable the developed modelling framework to operate in conjunction with other ETI models, such as its Energy System Modelling Environment. This will allow the ETI to undertake assessments of long term energy system scenarios to fully understand the role for storage and flexibility.

The project will also seek to identify the policy and market arrangements to determine the commercial viability of energy storage, the shape of potential future energy storage markets and the regulatory factors that would be required for such an operational market.

• Project confirms there are no major technical hurdles to storing industrial scale CO2 offshore in the UK with sites able to service mainland Europe as well as the UK
• 12 month project was carried out by Pale Blue Dot Energy, Axis Well Technology and Costain with 2.5m of funding provided by the Department of Energy and Climate Change (DECC)

Aberdeen-based consultancy Pale Blue Dot Energy supported by Axis Well Technology and Costain delivered a project which identified the next phase of sites deep under the seabed in UK waters to store CO2 emissions from coal and gas power stations and heavy industry plants.

The 12 month project was delivered by the ETI and funded with up to 2.5m from DECC. It progressed the appraisal of five selected storage sites towards readiness for Final Investment Decisions, de-risking these stores for potential future storage developers.

This project identified 20 specific CO₂storage sites (from a potential 579 sites) which together represent the tip of a very large strategic national CO₂storage resource potential,estimated to be around 78GT (78,000 million tonnes). The top 15% of this potential storage capacity would last the UK around 100 years.

Five of these sites were then selected for further detailed analysis given their potential contribution to mobilise commercial-scale carbon, capture and storage (CCS) projects for power and industrial use in the UK. Outline storage development plans and budgets were prepared for each.

Under the terms of the DECC funding package, the ETI is publishing on its website the detailed reports from the project and providing access to the sub-surface geological models.

The project has built on data from CO₂Stored - the UKs CO₂storage atlas - a database which was created from the ETIs UK Storage Appraisal Project. This is now publically available and being further developed by The Crown Estate and the British Geological Survey. Information on CO2Stored is available at www.co2stored.co.uk

• WP1: Landscape review of current developments;
• WP2: High Level Engineering Study (down-selecting from 24 to 8 Biomass to Power with CCS technologies);
• WP3: Parameterised Sub-System Models development; and
• WP4: Technology benchmarking and recommendation report. Reports generally follow this coding.

The Tidal Energy Converter (TEC) System demonstrator saw the ETI invest £3.2m in a project to take a whole system and through life analysis approach to deliver the best optimised design for a commercially viable 200MW tidal stream array.

It involved a broad range of the marine technology skill base and identified supply chain solutions applicable to generic tidal stream devices. Phase 1 of the project, launched in May 2012, was led by Atlantis Resources Corporation and project managed by Black & Veatch.

The project drew on the systems integration and technology skills of Lockheed Martin, as well as many leading technology providers in the marine industry. The results indicate that tidal energy could be comparable and cost competitive with offshore wind by 2020.

Key findings and deliverable reports from this project have been shared with the Offshore Renewable Energy Catapult the technology innovation and research centre for offshore wind, wave and tidal energy to inform their ongoing work in the area of tidal energy.

• Concentrated Solar Power (CSP) generated in the Sahara to be imported to the UK;
• Wind energy generated in the Outer Hebrides to be imported to the UK; and
• Wind energy generated in the Orkney Islands to be exported to Norway

Key findings of the study are:

• Electricity transmission represents the least cost solution if electrical energy is required at the demand site
• Chemical energy carriers do however compare favourably with electricity transmission where they can be used directly

In terms of the levelised costs per unit of energy delivered to the UK, the analysis demonstrates that electricity transmission represents the least cost solution if electrical energy is required at the demand site. This is true for all of the three generating site scenarios. For example, the cost associated with transferring electrical energy via a transmission network from the Outer Hebrides to the UK mainland is just over £70/MWh and from the Sahara £139/MWh compared to between £232/MWh and £281/MWh using chemical storage media.
The chemical energy carriers do however compare favourably with electricity transmission where they can be used directly. If energy can be supplied as a fuel rather than electricity, the case for the chemical energy storage media becomes economically viable. For example,hydrogen can be delivered to the UK from the Sahara at a cost of £124/MWh by ship or £120/MWh by pipeline, which is less than that for direct transmission (i.e. £139/MWh).

The results also indicate that using electro-chemical energy storage media (i.e. a Zinc-Air Battery ship concept) is unlikely to represent an economically viable concept. The overall costs are dominated by the cost of the batteries themselves. Even assuming an extremely ambitious cost target for a transportable battery the levelised cost per unit of electricity delivered is over six times that of the baseline transmission option.

This £4m project was delivered by a consortium of project partners from across academia and industry - LR Senergy Limited, BGS, the Scottish Centre for Carbon Storage (University of Edinburgh, Heriot-Watt University), Durham University, GeoPressure Technology Ltd, Geospatial Research Ltd, Imperial College London, RPS Energy and Element Energy Ltd.

We have agreed a licence with The Crown Estate and the BGS to host and further develop an online database of mapped UK offshore carbon dioxide storage capacity produced by UKSAP.

This is now publically available under the name of CO2 Stored. It can be accessed via http://www.co2stored.co.uk.

The web-enabled database - the first of its type anywhere in the world - contains geological data, storage estimates, risk assessments and economics of nearly 600 potential CO2 storage units of depleted oil and gas reservoirs, and saline aquifers around the UK. It enables interested stakeholders to access information about the storage resource and to make more informed decisions related to the roll out of CCS in the UK.

MacArtney has developed an entirely new type of medium voltage wet mate connector designed especially for the offshore renewable energy market. The new 11 kV wet mate connector makes interconnection and connecting dynamic cables from offshore renewable energy converters to export cables faster and easier. Up to now, disconnecting or connecting cable terminations offshore has been a time-consuming and consequently expensive business and required bringing cables up on deck. Funded by ETI, MacArtney has developed, produced and tested the new 11 kV connector solution.

MacArtneys wet mate connector eliminates the need to bring the cable to the surface for mating and de-mating, shortens the time needed for connection and makes it possible to operate in waters with limited time windows. This is particularly important for renewable energy devices where changing tides or wave action are often a critical factor in marine renewable deployments.

Faster and easier terminations : Cables ends are terminated to an 11 kV connector pair before deployment and mechanically connected offshore. The mechanical connection of the two halves takes less than an hour a significant improvement on the time it normally takes to cut and splice cables offshore. This mechanical connection also makes it possible to connect and disconnect cables time and time again. The 11 kV termination can also be pre mounted onto cable ends for installation in two stages. Half of the system can be installed on the sea floor with a pressure cap mounted to the connector and the second half of the cable mated at a later stage. "We know what challenges renewable energy converters face Being involved with many large marine renewable energy projects over recent years has given MacArtney a deep understanding of the challenges and issues faced when connecting moving, dynamic devices to stationary export cables that transfer captured energy to the onshore grid."

Grid compliant - The MacArtney 11 kV wet mate connector system is a fully tested and EN/CEI/IEC 60502-4 compliant connector solution specifically designed to meet the needs of the marine renewables industry and requirements from grid owners and utilities. Tests were witnessed by DnV (Det Norske Veritas) and real-sea tests performed off Falmouth, UK, in October 2011.

• To investigate the costs that domestic electricity suppliers in Great Britain might face in 2030.
• To make projections on the assumption that, unless formally announced, no changes are made to the electricity market arrangements in place today
• To focus in particular on the hourly variation and seasonal shape of supplier costs

• To investigate the costs that domestic electricity suppliers in Great Britain might face in 2030.
• To make projections on the assumption that, unless formally announced, no changes are made to the electricity market arrangements in place today
• To focus in particular on the hourly variation and seasonal shape of supplier costs

• This study investigates the costs that domestic electricity suppliers in Great Britain might face in 2030
• Projections are made based on the assumption that, unless formally announced, no changes are made to today’s electricity market arrangements
• Particular focus is given to the hourly variation and seasonal shape of costs faced by suppliers
• Hourly retail cost stacks in 2030 are modelled for the average domestic electricity consumer in the East Midlands

1. National Grid Two Degrees (NG 2 Degrees): A relatively high demand scenario, with relatively high renewables, nuclear and imports, but reduced levels of CCGT
2. ETI Long-Term Role of Gas (ETI LT ROG): The highest-demand scenario modelled, with high levels of renewables, CCGT and storage, but reduced nuclear capacity
3. ETI Consumers, Vehicles and Energy Integration (ETI EVEI): With demand the lowest of the three, this scenario has the highest levels of nuclear, but the lowest levels of renewables and storage

1. Trends in supplier costs that might occur between 2017 and 2030 if market arrangements remain unchanged
2. Differences between scenarios that can be seen, reflecting different technology and market assumptions
3. Issues that could result if arrangements remain unchanged over horizon to 2030

• A word document providing interpretation of the findings in this slide deck
• A high level viewpoint for senior stakeholders summarising the work, results and insights
• An Excel workbook containing the key inputs and a
  full set of hourly outputs by scenario

• To investigate the costs that domestic electricity suppliers in Great Britain might face in 2030.
• To make projections on the assumption that, unless formally announced, no changes are made to the electricity market arrangements in place today
• To focus in particular on the hourly variation and seasonal shape of supplier costs

• High Electricity: a world in which electricity becomes the dominant energy vector requiring upgrading of related electricity infrastructure. This test case assumes a predominantly centralised approach to generation and transmission.
• High Heat: a world in which there is considerable progress in rolling out heat networks in urban centres, with the mix of energy vectors otherwise being similar to today. The test case suggests a more decentralised infrastructure with more localised forms of generation.
• High Hydrogen: a world in which a transmission and distribution network for hydrogen is developed.

1. A summary of economic modelling findings
2. Identification of key technical, commercial and regulatory barriers across Case Studies
3. Classification of the barriers identified, based on:
   • Impact – the scale of potential system benefit of multi vector operation
   • Risk – the extent to which these barriers are surmountable
4. Discusses the innovations that might mitigate these barriers, comprising the necessary technical capabilities, and the required regulatory and commercial frameworks.
5. Assesses the additional work for multi vector operation to achieve commercialisation at scale, comprising:
   • Investment
   • Timescales and necessary uptake rates
   • Skills gaps, required operational transformation and strategic considerations

• Case 1: Retention of the gas network to meet peak heating loads in a future where heat decarbonisation is achieved by high electrification
• Case 2: Gas-fired Combined Heat and Power (CHP) and electric heat pumps supplying heat networks
• Case 3: Plug-in hybrid electric vehicles switching between electric and liquid fuel running modes at times of tight electricity supply margins
• Case 4: Renewable Energy Sources (RES) electricity generation to gas (hydrogen or methane) for injection into the gas system
• Case 5: Grid electrolysis to produce hydrogen for a hydrogen distribution system
• Case 6: Renewable Electricity Connection Constraint Mitigated by Domestic Thermal Demand
• Case 7: EfW Flexing Between Producing Electricity and Gas for Grid Injection

• For each case, agree the system configurations of multi-vector (MV) and single-vector (SV) instances
• Discuss the degrees of freedom available in each case that can be used to optimise the MV and SV configurations
• Agree the expected outputs from the modelling that will be used to calculate the multi-vector case benefit
• Discuss the inputs required for each case and for the “global scenarios” and the data sources tobe used
• Agree the exogenous parameters of interest for each MV solution model

1. Domestic scale heat pumps and peak gas boilers.
2. Gas CHP and Heat Pumps supplying district heating and individual building heating loads.
3. PHEV switching fuel demand from electricity to petrol or diesel.
4. RES to H₂/RES to CH₄
5. RES to DH and Distributed Smart Heating (“virtual” DH networks)
6. Anaerobic Digestion/Gasification to CHP or grid injection

• Description of the methodology used to map and classify multi-vector interactions
• An initial assessment of each case, describing the system, the issues addressed, the current situation and the likely ‘materiality’ for the UK energy system
• The process used to filter and prioritise the cases, and the agreed shortlist
• A recap of the subsequent work to be undertaken in Work Packages 2 and 3

• electricity,
• gas,
• hydrogen,
• district heating,
• liquid fuels

• peak avoidance,
• flexibility using multiple vectorsto supply the same load,
• overcoming a generation capacity constraint,
• avoiding curtailment of a generation asset, and
• backing up an energy source

1. Domestic scale heat pumps and peak gas boilers.
2. Gas CHP and Heat Pumps to supply district heating and individual building heating loads
   1. CHP and heat pumps operating to supply heat to district heating
   2. CHP supplying district heating, with co-generated electricity used to power individual dwelling heat pumps
3. PHEV switching fuel demand from electricity to petrol or diesel.
4. RES to H₂/RES to CH₄
5. RES to DH and “virtual” DH networks
6. Anaerobic Digestion/Gasification to CHP or grid injection

• A model to map Levelised Cost Of Energy (LCOE) for wave energy is presented.
• Spatial methodology allows identification of device specific LCOE “hotspots”.
• Dijkstra&rquo;s algorithm is used for spatial cost estimation.
• Installation weather windows are estimated using the NMI statistical method.
• LCOE sensitivity to cut-in and cut-out sea state and installation season presented.

• What we do
• The areas we work in
• The outcomes
• Commercially available products
• Who we have worked with

• Energy System Analysis –the importance of CCS
• UK Power System –the value of CCS
• CCS in the UK –some recent history and development of the ETI’s current programme
• Addressing the credibility of the cost base: the ETI’s Thermal Power with CCS - Generic Business Case Project
• Conclusions and next steps

• The UK needs innovation to meet its carbon targets and for this process to beeffective and rapid – with several critical components:market confidence, finance,public policy and thecapability to innovate
• Collaboration and shared understanding is required – involving interactions across science, business and government to facilitate knowledge transfer and learning – it is easier to achieve a transition with a shared understanding of the drivers of new low carbon energy technologies
• The slower the pace of energy innovation, the less time the UK will have to transition to a low carbon economy and the more expensive it will be to do so
• Successful innovation systems often involve open and iterative processes, which are complex. They depend on multiple interactions between different actors
• Policy interventions are required to drive innovation in energy and low carbon – business needs certainty so policy stability matters
• Industry and government should work together to set strategic priorities – low carbon markets are almost entirely driven by public policy but delivered by private sector firms
• Successful innovation in low carbon energy requires new technology capabilities, new markets, new business models together with appropriate changes to the regulatory framework

• Market, policy and regulatory frameworks
• Business models and customer offerings
• Integrated vehicle and infrastructure systems and technologies using electricity, liquid fuel and hydrogen
• Consumer and fleet attitudes to adoption and usage behaviours

• NET Power technology has the potential to be a gamechanger.
• Modelling analysis confirms that NET Power’s supercritical CO₂ power cycle has the potential to deliver carbon capture at efficiencies higher than conventional amine solutions.
• Some unpublished innovations which NET Power are protecting as trade secrets are needed to make the technology as cost efficient as an unabated CCGT, which is still improving rapidly.
• The technology is immature and has multiple development hurdles to overcome and therefore it is likely to take several years before it is commercially available at scale. It is therefore likely to be best suited for deployment once other elements of CCS have been de-risked (i.e. transport and storage) rather than in a First of a Kind full scale development.

• UK-grown biomass can deliver genuine, system-level, greenhouse gas savings.
• Planting around 1.4 Mha of second generation (non-food) bioenergy crops, such as Miscanthus, Short Rotation Coppice (SRC) willow and Short Rotation Forestry (SRF), by the 2050s would make a signifi cant contribution to delivering a cost-effective, low carbon energy system. This is equivalent to ~7.5% of the total agricultural area of the UK.
• Steadily increasing the area of bioenergy crops in the UK (averaging around 30-35 kha/yr of new planting out to the 2050s) would allow the sector to ‘learn by doing’ and develop best practices, as well as monitor and manage impacts on other markets and the wider environment.
• Delivering a substantial energy crops sector whilst balancing the demand for land from other sectors will require an increase in land productivity and a reduction in food waste throughout the supply chain.
• The market for second generation energy crops is nascent.
• As the UK prepares to leave the European Union, there is an opportunity to restructure farming support in a way which provides long-term clarity and support to farmers and encourages the sustainable growth of the UK biomass sector

• Offshore Wind
  • Is a proven technology that is being deployed commercially with a credible path to becoming competitive with the lowest cost low carbon technologies
  • The focus for technology development is now on – improving yields, reducing capital & operational costs and achieving wider deployment
  • A stable policy and funding environment into the medium term would accelerate the achievement of energy cost competitiveness
• Tidal Stream Energy
  • Is at a much earlier stage in the innovation chain
  • Its innovation needs are known and the challenge is one of how to put the component parts together in deployable systems rather than having to reinvent the technology
  • MeyGen’s Inner Sound project, the world’s first tidal stream array is pivotal to advancing the technology and developing supply chain capability

• Liquefied Natural Gas (LNG) and Compressed Natural Gas (CNG) have the potential to reduce Greenhouse Gas (GHG) emissions over the well-to-motion pathway by 13% (LNG) - 20%(CNG) for dedicated engines and 16% (LNG) - 24%(CNG) for High Pressure Direct Injection engines per vehicle in the 2035 timeframe in comparison to the reference baselinediesel pathway.
• Cycle specific powertrain technology selection and pathway optimisation are key to providing GHG emission benefits over given usage cycles, with High Pressure Direct Injection and Dedicated gas engines providing the highest benefit.
• Retrofit dual fuel engines have been shown to have high methane emissions, often being worse than baseline diesel powertrains on a GHG emission basis. Effective testing procedures and legislative certainty are required to ensure emissions conformity and facilitate market development
• Providing methane catalysis at real world operating temperatures, i.e. below 350°C, is essential to prevent uncombusted methane making its way out of the tailpipe in powertrains that cannot control methane slip and is a key technology that enables a pathway benefit.
• Employing ‘best practices’ at LNG, CNG and L-CNG stations is a key driver to providing pathway benefits. Vapour recovery systems should be implemented at all LNG stations and the economic proposition and expected utilisation should be aligned. CNG stations should be connected to the highest pressure tier of the grid where possible or employed in combination with a L-CNG station as an easy step to reduce emissions associated with compression, at least until the carbon intensity of the grid is significantly lower than today.
• The economic proposition for natural gas in the HGV fleet hinges upon the fuel duty differential and currently only the long haul segment is economic in the near term. Fuel duty tax stability is key to enable market confi dence to invest in natural gas vehicles and the necessary supporting infrastructure.

• Planting 30 - 35 kha/yr of second generation crops (Miscanthus, Short Rotation Coppice (SRC) willow and Short  Rotation Forestry (SRF)) would keep the UK on the trajectory to deliver a bioenergy sector of the scale needed to help cost-effectively decarbonise the UK energy system.
• Due to the seasonal nature of bioenergy crop planting, management and harvesting, the majority of job opportunities will be part-time, but are complimentary to the seasonal demands of other roles in the agricultural and forestry sectors, particularly arable farming.By 2032, a 30 kha/yr planting rate could create around 8,100 job opportunities in the busiest months (or 4,300 Full Time Equivalent (FTE) jobs when averaged across the year). By the 2050s, around 16,700 opportunities could be created during peak periods (9,100 FTE jobs across the year).
• The UK is not currently in a position to deliver a planting rate of 30 kha/yr – the total planted area of Miscanthus and SRC willow has remained at around 10 kha in recent years with a limited number of players in the market. Investment is needed in the production of plant breeding materials, including research into new establishment techniques to reduce costs. Investment is also needed in training and specialised equipment for planting and harvesting.
• As the UK prepares to leave the European Union, there is an opportunity to restructure farming support in a way which encourages the sustainable growth of the UK biomass sector. This could place a value on the wider environmental benefits growing second generation energy crops can make to the farming landscape.

• Respondents have consistently supported government-led action to tackle greenhouse gas emissions. In 2017, over half of respondents (58%) thought that the government should do more to reduce emissions, with only 6% believing that the government should reduce efforts to lower emissions.
• Support for producing bioenergy from both biomass and waste has been consistently strong across all three surveys with the highest levels of support recorded in the most recent survey. Across the three surveys between 72% and 77% of respondents supported the use of biomass, and 81-84% supported the use of waste for bioenergy production.
• Bioenergy is associated with several positive features. The ability to generate energy from waste has consistently been the positive feature most selected by respondents. The ETI’s broader analysis highlights the importance of using waste feedstocks effectively to deliver emissions savings. In order to help achieve this, the ETI is investing in a 1.5 MWe waste gasifi cation demonstration plant with syngas clean-up.
• In all three surveys, competition for land and having to import biomass because not enough is produced in the UK have been perceived by respondents as the main negative features of bioenergy. Our 2016 report explored these views in more detail and concluded that using a mix of imported and domestic feedstocks could be publically acceptable, such that the UK is not overly reliant on imports and can maintain at least current levels of food self-sufficiency
• The government has consistently been the most popular choice to lead the development of the bioenergy sector, but a greater number of respondents trust scientists/academics or experts in the field, independent consumer or industry watchdogs, and environmental interest groups to provide reliable information on the sector. This suggests it will be crucial for different groups to work together to increase awareness and understanding of bioenergy while developing the sector in the UK.

• The UK can implement an affordable (approximately 1% of GDP) 35-year transition to a low carbon energy system by developing, commercialising and integrating known – but currently underdeveloped solutions
• There is enormous potential and value in CCS and bioenergy in delivering alow carbon future
• The ability (or failure) to deploy these two technologies will have a huge impact on the cost of achieving the UK climate change targets and the national architecture of low carbon systems and future infrastructure requirements
• To avoidwasting investment, crucial decisions must be made about the design of the future UK energy system, driven by choices on infrastructure
• The next decade is critical in preparing for transition
• Preparation will require major investments in developing and proving key technology options by the mid 2020s
• Preparation creates options, demonstrates leadershipand provides scope for economic advantage in a global market place
• Planned UK spend is probably sufficient, if it is targeted to develop genuine deployment readiness of the most strategically valuable options on the pathway to 2050
• Significant policy intervention will be required to support key technologies with characteristics that make a pure market approach difficult (e.g. CCS, bioenergy, nuclear, offshore wind, heat networks

• Low cost sensors that enable many things to be measured – for example all the information that cars now have available.
• Communications infrastructure that enables data to be transported almost anywhere on the planet.
• Relatively low cost storage and processing power that is scalable, so you mostly only pay for what you need.
• Software tools that enable data to be transformed to produce information and insight that can be displayed in a way that people can easily grasp.
• Social and business ecosystems that set expectations and enable us to share and transact without relying on a single point of control.
• Rating sites such as TripAdvisor, blogs, PayPal and social media channels all provide social and commercial models that increase individual knowledgeand empowerment.

These elements have only just started to penetrate energy, which has been held back significantly by the current governance structures. Energy presents similar challenges to those of finance where changes which should benefit consumers come with new risks. However, giving people more freedom in how they buy and use energy should carry less risk than giving them freedoms over their pensions and other investments.

• Light Vehicles in the UK
• Plug-in vehicle sales
• Vehicle life
• Vehicle usage
• Consumer attitudes to plug-in vehicles
• Where to support charging
• Meeting vehicle charging requirements
• Network reinforcement costs
• Consumers, Vehicles and Energy Integration (CVEI) project
  • Consumer adoption: understanding the mass-market
  • Outputs –Modelling capability
  • Interim findings
  • Roadmap for efficient ULEV uptake and use
  • Trials will deliver further robust evidence

• Wave loads on semi-sub FWT platforms are sensitive to wind-driven inclination.
• The effects of geometric non-linearity can be pronounced in presence of heave plates.
• The wave load alteration due to heave plate vertical excursion is investigated.
• Significant heave plate excursion occurs when a FWT’s mean inclination reaches 5°
• The motion of a FWTis affected heave plate excursion in the 5 s to 15 s period range

• Application of both a genetic algorithm and particle swarm optimizer to design and optimize offshore wind farm layouts at Middelgrunden.
• Wind farm layouts designed using 3 different levels of constraint which are of interest to wind farm developers.
• Various degrees of constraint allow the impact of these constraints to be quantified and compared.
• Presentation of six new layout for Middelgrunden with reduced LCOE compared to the as-built case.

• Value of brine production: Lifetime T&S unit costs tend to increase with brine production for a given injection scenario (although some minor savings are observed for some of the units examined); however, more importantly, more injection scenarios with higher storage capacities become feasible with brine production.
• Cost effectiveness of brine production: Brine production allows significant increase in storage capacity at similar unit costs. In addition to achieving more CO₂ storage capacity with reasonable costs, a lower unit T&S cost is achieved with brine production at Firth of Forth and Tay.
• Optimal development/configuration plans: As CAPEX of clean water discharge infrastructure on platform is negligible, sub-sea brine production does not lead to significant savings in water treatment CAPEX. However, significant savings can be achieved in injection facility CAPEX (if high costs of installing platforms can be avoided with subsea brine production – e.g. if subsea facilities connected to a hub is the most cost-effective configuration for an injection scenario).

• Value and cost of brine production: Examination of potential impact of brine production on gas fields
• Optimal development/configuration plans: Examination of further brine production scenarios that will be provided by HWU (e.g. more optimised injection/brine production scenarios if necessary) and examining different infrastructure configurations with brine production (e.g. using a central water treatment facility, which can be connected to subsea facilities or oversea platforms via brine distribution pipelines
• Informing CO₂Stored database: Reviewing learnings from the initial analysis to consider how we could model other storage units in the CO₂Stored database

• Energy balancing is critical and extends beyond the electricity system
• Numerous opportunities to achieve balancing include:
  • Energy storage
  • Demand side flexibility
  • Vector integration
• Key decisions that lead to new energy systems will affect how much and what type of flexibility is needed.
• There is a huge amount of potential that we do not currently understand about balancing within a whole energy system.
• It is possible to assess the requirements for future flexibility – tools and evidence are being developed to help with this.

• All three case studies demonstrate that planting energy crops can increase the profitability of the land over a 23-year lifetime. Initial investment costs are expected to be paid back within the first six to seven years.
• When optimising the use of land across the farm, impacts on food production can be minimised or avoided. in two case studies, food impacts were minimised by using land which delivered poor arable yields, and by minimising the reduction in sheep numbers through higher stocking densities (the number of sheep per hectare). in the third case study, the crop was planted on unused land so no food production was displaced.
• Land which is less suitable for food production or grazing can be suited to energy crops as they can be successfully planted on poorer quality soils, and land which is more prone to waterlogging or weed problems. They are also suited to less accessible fields as they require less intensive management than arable crops.
• The farmers in these case studies chose to grow energy crops for a variety of reasons - making better use of difficult or underutilised land, diversifying income and reducing workload. In addition, all farmers cited the importance of obtaining secure fixed-term contracts with buyers in their decision making. This reinforces findings from previous ETI work on enabling UK biomass.
• Discussions with land agents suggest that land used to grow biomass crops should not be valued differently to other agricultural land, as land should be valued on its productive capacity. however, the specific price offered by a buyer will be affected by their objectives in buying the land and their understanding of bioenergy crops. The presence of a profitable contract for the crop and a willingness from the buyer to continue with bioenergy cropping may have a beneficial impact on the land value. If the buyer wishes to change the land use, is uncertain how to manage a bioenergy crop, or if there are limited market outlets for the crop, the land value may be lower than if it weren’t planted with a bioenergy crop.
• Qualitative evidence from the Miscanthus farmers indicate an increase in wildlife, particularly birds, since growing the crop. In the Short Rotation Coppice (SRC) Willow case study, the farm carried out an environmental impact assessment (EIA) before planting.

• Despite new entrants, the supply chain is very fragamented.
• There are a number of planned network logistics investments which have the potential to benefit the sector.
• There are lessons that can be learned from established supply chains in other comparable industries
• Confidence in the sector is much needed to attract further investment in supporting infrastructure and supply chain synergies.
• Rail is vital to the UK’s economic prosperity. Rail links with ports and airports are essential to support the transportation of goods
• The extent to which rail transport and freight specifically will be a constraint to the biomass logistics supply chain is dependent upon a range of factors; primarily the Government’s energy policy on biomass, willingness of the Government to protect capacity and promote rail freight growth on the network, the extent to which biomass will replace coal and the cost efficiency of using imported fuel sources and rail haulage, as opposed to local fuel supplies and other transport modes

• ensure a wider, more detailed representation of possible bioenergy pathways
• raise the overall data quality and level of confidence in the model
• improve the user interface
• increase the options for use cases and scenarios

• D3.3: Parameterised sub-system models
• D3.4: Model requirements and specifications and modelling strategy
• D3.5: Model and sub-model user documentation

• T6 denotes dedicated biomass oxy-firing combustion
• T7 Biomass combustion, with CO₂ capture by post-combustion carbonate looping
• T8 Dedicated biomass chemical-looping-combustion using a solid oxygen carrier

• This deliverable is number 2 of 7 in Work Package 2.
• It presents the initial approach to the costing methodology for thermal efficiency improvements to be employed by the project and incorporated into the computer model being developed.
• Accurate cost information for retrofit interventions is key to ensuring the identification and development of the optimum solutions for each housing archetype previously identified in deliverable D2.1.
• Costs of two types are considered:
  • Unit costs
  • Other fixed costs
• Costs are input for:
  • Loft insulation
  • Cavity wall insulation
  • Hot water tank insulation
  • Floor insulation
  • Replacement windows

• Pre-1919 detached houses
• Pre-1919 mid-terraced houses
• Pre-1919 converted flats
• 1919-1944 semi detached houses
• 1945-1964 semi detached houses

• To address the needs and requirements from a broad range of stakeholders in the national retrofit process
• To formulate a preliminary hierarchy of value of ‘home thermal efficiency’ for stakeholders
• To understand the various barriers and obstacles to the success of a national retrofit implementation plan
• To capture views from the participants and propose a strategy for capturing responses from other under-represented groups.
• To translate the outputs of the workshop into a framework for future deliverables to use as measures of success

1. To cover a sufficient range of house types to gain a good picture of the issues involved with implementing a mass retrofit programme
2. To take the whole house solutions in WP3.3 and examine them with regards to buildability, cost, carbon effectiveness and customer acceptance
3. To test out whole house solutions proposals on the most frequently occurring house types across the UK, focusing on the variations in construction and housing typology in England, Scotland, Northern Ireland and Wales

1. 1) Preparation to 2020
2. 2) Retrofit rollout 2020 to 2030
3. 3) Future scenarios 2030 to 2050.

• The 4 hour detailed survey with 2 people is possible (even for the most difficult house) and there is scope to reducethis further.
• It has been shown to be possible to retrofit the two levels of intervention, Retro Fix and Retro Plus, across the modelled house types in 10 elapsed days or less (depending on property size/ complexity and weather permitting) using a team of 4 poly-competent retrofitters.
• Increasing competencies will be vital to deliver retrofit brilliantly and at scale - new training systems are required to provide an up-skilling route for people wishing to enter the retrofit industry.
• New or simplified accreditation and warranty systems are needed for retrofit
• Standard retrofit solutions will help generate efficiency gains and simplify the provision of materials.
• Progress has been made to understand how cost is built up within the supply chain but further work is needed to allow key players to share cost information.
• Retrofit cost of under£10,000 for most house types is feasible but challenging for most house types based on our understanding of how cost is built up within the supply chain. More specific cost data will be generated for common house archetypes; these will be presented in follow up reports for this work package.

1. the individual building level, and
2. the UK housing stock level.

• A stock model that uses a simplified energy model as its calculation engine.
• A simplified model for individual dwelling calculations (the same model as used in the stock model).
• A detailed simulation model (or models) for individual dwelling modelling in situations where such a model is necessary.

• Develop a multi-skill site approach which enables seamless, cost-effective site work with minimal disruption to householders; instead of a series of trade based activities.
• Develop factory prepared kits, ready to fit, with short leadtimes; which speed up installation, minimise disruption and give assured quality performance.
• Generate supply solutions that treat retrofit as a System solution instead of a series of bolt on interventions. With product and service providers acting together there will be more potential to improve overall thermal performance, reduce cost and minimise householder disruption.

• a summary of 52 semi-structured interviews with householders who have experienced a building retrofit
• interviews were held with both owner occupiers and with tenants of social housing
• key conclusions from the interviews include
  • need to design out delays from the retrofit process,
  • provide suitable advice as and when the householder wants it,
  • consider the reduction of VAT from retrofit works and
  • design solutions which allow for the use of local tradesmen
  • minimal levels of maintenancegoing forwards.

• 15 one to one interviews,
• 10 focus groups and
• a survey of 20,000 people (932 responses) carried out by the consortium.

• A: Detailed Survey Methodology
• B: Survey Questionnaire
• C: Postal Survey Covering Letter with Glossary
• D: Email covering letter
• E: Survey Responses
• F: Focus Group Structure
• G – Example Focus Group Screener
• H – Virtual Retrofit Interview Script
• References

• The need for a major programme of training and skills development;
• Legislation to help bring the private rental sector into retrofit;
• Consolidation of advice, funding and policy streams;
• Focus on developing a link between asset value and energy performance
• Roles for a project manager or single-point-of-contact liaison officer would help ensure retrofit packages meet customer expectations.

• the existing methodologies available
• the choice of the Experian Mosaic-Green system.
• the ten customer segments are discussed along with their geographic distribution
• A first draft of the metrics is shown
• Further development of the segmentation model is discussed
• Appendices:
  • A: Extract of Micro DE 1.3 Report
  • B: Key datasets

• A summary of the Work Package and its deliverables;
• A final summary of the customer segmentation with segment profiles;
• A detailed summary of potential early adopter segments;
• Synthesis conclusions and recommendations;
• Evaluation of the deliverable and suggestions for future work.

• Validation of House Type and Customer Type Combinations
• Profiles of early adopters terms
  
  • Older Established
  • Stretched Pensioners
  • Transitional Retirees
  • Early Entrepeneurs

1. demographic profile
2. top house types
li>attitudes to refits
3. energy perceptions and behaviours

• A summary of the Work Package and its deliverables;
• A final summary of the customer segmentation;
• The early adopter segments;
• Synthesis conclusions and recommendations;
• Evaluation of the deliverable and suggestions for future work.

• existing methodologies
• choice of Experian Mosaic-Green
• work with Experian to refine the customer segments from their model in this specific context
• summarises the ten resulting customer segments
• presents a diagram showing their relationship to age and affluence
• describes the further work to be done

• English housing stock has been split into 36 different archetypes based on the dates of construction and the dwelling configuration.
• This is to support the analysis of retrofit interventions identified on an individual dwelling basis, and their subsequent extrapolation to the entire English housing stock.
• Data on key characteristics relevant to thermal efficiency or the costs of improvement are presented for each of the housing archetypes.

• Frequency
• Current notional CO₂ emissions
• Predominant wall type & presence of wall insulation
• Roof type
• Percentage of glazing
• Type of glazing
• Presence of bay windows
• Floor area
• Wall area
• Roof area
• Existing loft insulation thickness
• Notional CO₂ reductions following EPC recommended measures
• Presence of ‘additional part’ (an extension or extension-like area)
• Wall finish