Results: Browse all publications

• 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

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.

• 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

1. Splitting the retrofit process into delivery steps and supporting activities, adding a description / specification at each step for the future state, this future state is documented in deliverables 4.3 and 4.4.
2. Add the current state for the existing supply chain
3. Identify the transformation route from current state to desired future state, the participants required to take action, prioritisation and the likely costs / timeframes. The goal is the capacity to achieve 400,000 retrofits per year by 2020. The result of this activity is the transformation plan identified in this deliverable.

• Transformational roadmap, plan and high level budget
• Stakeholder review
• Commercial drivers
• Obstacles & Risks
• Geographical Considerations
• Material and Process Change Requirements

• The current supply chain is split by silos around the existing trades:
  • Windows and doors
  • Loft / Roof insulation
  • Heating and plumbing
  • External insulation
  • Internal insulation
• Delivery of retrofit is centred on these trade silos resulting in duplication in the supply chain and retrofit installation businesses
• There is a piecemeal approach to retrofit design and installation again split by function resulting in a failure to achieve the performance and cost benefits of a systems engineered approach
• The skills and qualifications demanded to work legally and to satisfy warranty provisions with products used in retrofit are mostly general and not “right sized, and fit for the purpose” for a future mass retrofit market
• The existing supply chain is not configured for the retrofit market (which has yet to emerge) and there is no clear strategy for distribution and consolidation of products to effectively support and enable retrofit businesses.
• Routes to obtain funding and investment in domestic retrofit are unclear and the team has been unsuccessful in engaging with the financial community on this project. The green deal mayinclude mechanisms but is unlikely to enable the whole house retrofit systems approach.
• The survey process requires in depth study to provide a robust system to remove risk from the retrofit process. This is likely to include a large element of continuous monitoring, feedback and improvement as the industry forms and matures.
• Current trade skills are inappropriate for retrofit being broad based with limited cover for cross trade working. The retrofit installation process also requires in depth study to understand the basic competences and optimise team working to achieve the best value balance of number of people on site and time taken for retrofit.
• Trade qualifications and legislation for working with gas, water and electricity are likely to limit the speed and effectiveness of the development of retrofit unless reviewed and brought into line with the competence approach suggested here.
• New products are required to simplify retrofit activities and increase the robustness of the end result. Pre fabrication and off site material preparation are also seen as a requirement to increase speed and quality of installation results.
• Significant cost erosion is required to allow whole house retrofit to be a financially attractive investment to home owners.

• a critique of the robustness of the evidence base based on both data and methodologies used;
• a measure of certainty behind the data reviewed; and
• details of the confidence the reviewer may have in interpreting the data.

• how sampling consistency will be assured;
• the design for the planned database;
• the roles and responsibilities between all parties involved in sampling, data collection and lab analysis.
• the rationale for the experimental approach

• the collection of electrical energy offshore from multiple renewable energy farms,
• the transportation of electrical energy generated by these offshore farms to the UK shoreline,
• the connection and integration into the onshore power system.

• a clear understanding of the key issues concerning the connection of multiple renewable energy farms off the UK coast
• assessments of the likely technical limits concerning the integration of offshore renewable energy systems into the UK power system
• recommendations for new, optimised solutions for the grid connection of multiple offshore renewable energy farms, including the provision of design concepts for offshore HVDC electrical systems
• identification of technology development opportunities for the industry.

• Distributed Smaller Windfarms
• Large Windfarms
• Very Large Windfarms
• Small Marine Case
• Medium Wave Case
• Large Tidal Case
• Combined Tidal and Wind Case

• the collection of electrical energy offshore from individual and multiple renewable energy farms,
• the transportation of bulk electrical energy generated by these offshore farms to the UK shoreline,
• the connection and integration of these offshore farms into the onshore power system.

1. Electricity costs need to be competitive with current (2010) onshore wind costs by 2020 and with conventional generation by 2050. This is illustrated in the Offshore Wind roadmap in Appendix D,
2. Increased yields: annual offshore farm availability to be increased to 97%-98% or better (currently 80% to 90%),
3. Reduce technical uncertainties to allow farms to be financed in a manner, and at costs, equivalent to onshore wind today.

1. This project has provided the ETI with valuable data on TLP floating foundation design and cost to inform the ETI Offshore Wind programme’s future work (2010 to 2015):
2. The Turbine and TLP are not afully integrated system. In the next phase (if taken forward), further work would need to be done on modelling the interactions between waves, TLP, the tower and the nacelle. Existing commercial software will need to be enhanced to meet this need.Currentcommercial software models support structures fixed to the seabed / ground.

1. Electricity costs need to be competitive with current (2010) onshore wind costs by 2020 and with conventional generation by 2050,
2. Increased yields: annual offshore farm availability to be increased to 97%-98% or better,
3. Reduce technical uncertainties to allow farms to be financed in a manner, and at costs, equivalent to onshore wind today.

• This project has provided the ETI with valuable data on TLP floating foundation design and cost. This information has helped shape the next stage of the ETI Offshore Wind programme.
li>Our analysis has concluded that the cost of energy from the deep water high wind sites is competitive with that of the typical Round 3 sites.
• Further optimisation of the TLP floating foundation design could further improve energy costs.

1. Evaluate the potential role and economics of plug-in vehicles in the low carbon transport system: generate a quantified understanding of the market potential, cost models and carbon benefits case under defined scenarios of infrastructure investments, government intervention packages and finance model options across a number of key plug-in vehicle type/size/capability points; and
2. Develop the technology tool-kit for delivering an intelligent infrastructure: create a verified open interoperability architecture and generate information to aid infrastructure planning (e.g. to indicate how many recharging points are needed and where they should be located, what mix of power levels are required, how the impact of plug-in vehicle recharging on the electricity distribution network should be managed, how the overall system can be simplified for consumers, etc).

• Moderate uptake of plug-in vehicles could cause significant challenges for distribution networks if demand from recharging is uncontrolled
• Traditional network reinforcement, by way of substation upgrades and cable reinforcement, is likely to be increasingly inefficient
• Distribution Network Operators (DNOs) will need to move away from the conventional, passive reinforcement approach towards a ‘smart grid’ approach
• Success isalso reliant on effective consumer engagement, the costs of which are challenging to forecast.

• Low cost heat networks
• The use of syn-gas generated from EfW technologies to create fuels / chemicals 
• The use of pyrolysis to create transport fuels 
• The injection of bio-gas and syn-gas from EfW technologies into the gas grid 
• The injection of bio-gas and syn-gas from EfW technologies into the gas grid with CCS

• Applying forecast values for low to high waste availability and conversion efficiencies, the amount of useful energy from waste (both heat and power) which may be generated ranges from 5 to 230TWhrs.
• Projected achievable electrical generation is approximately 25TWhrs per year
• This equates to between 5% and 8% of the UK?s electricity demand
• For each of the technology and waste arisings scenarios, the deployment of advanced energy from waste technologies is projected to contribute to a net decrease in UK CO₂e emissions of between 5 and 10 MTCO₂e/year at midpoint technology conversion and waste arisings scenarios
• Greater emissions reductions are associated with high total conversion efficiency technologies, both to electricity and from utilising heat.

The aim of the workshop was to bring together academics and practitioners from different disciplines and backgrounds in order to ultimately inform more effective approaches to public communication of, and engagement with, climate change and energy reduction. The overarching question to be addressed by the workshop was, “What can empirical and theoretical studies of communication and behaviour change tell us about how we might move towards a more ‘climate-friendly’ (low-carbon, climate resilient) society?”. More specifically the workshop objectives were to: share cutting-edge research and practice; foster learning across disciplines and contexts; identify gaps in understanding; form new interdisciplinary contacts and networks; consider and generate new insights; stimulate novel collaborations; provide the contents for a book and a workshop report that would be useful for academics, practitioners and policy-makers. Central to the workshop were three sessions relating to the overarching question: models, messages and media. These sessions involved 10 minute presentations from each of three presenters and a 10 minute response from an invited discussant.

• Borehole Storage: Southampton, Sheffield, Nottingham, Leicester
• Aquifer Storage: Birmingham, Southampton, Manchester

• Demand for On Highway Heavy Duty Vehicles will grow from 3.34m vehicles in 2015 to 4.24m vehicles in 2030 (in the 6 large markets studied).
• The majority of this growth will be in the >7.5 ton vehicle sector, as the Chinese and Indian road transportation markets mature from an “owner operator” model towards a “fleet operator” model. The increase in vehicle weight will increase demand for larger displacement engines (>6 litres) and also encourage further uptake of Automatic Manual Transmissions (AMT) at the expense of manual transmissions.
• Diesel will remain as the dominant fuel type for HDVs with ~85% HDVs powered by Diesel Internal Combustion Engines in 2030.
• It is expected that City Buses will have greater levels of hybridisation and there will be a variety of technical solutions for City Buses, including fully electric, as inner city air quality concerns and legislation increases.
• Emissions legislation will continue to develop in the various regions, with increasing harmonisation between the standards. There is a trend towards increasing number of regulated pollutants, over a larger number of tests and an increased duration (life) that the vehicle must meet the targets. Some regions are beginning to use CO₂ / fuel efficiency regulations and it is expected that this trend will spread to other regions over time

1. Electricity costs need to be competitive with current (2010) onshore wind costs by 2020 and with conventional generation by 2050,
2. Increased yields: annual offshore farm availability to be increased to 97%-98% or better,
3. Reduce technical uncertainties to allow farms to be financed in a manner, and at costs, equivalent to onshore wind today.

• The consortium indentified that sufficient improvements could be made through technology innovation to deliver energy costs that are comparable with current (2010) onshore wind costs: one of ETI’s objectives for this programme.
• This involves innovation in rotor aerodynamics, rotor diameter, drive train technologies and electrical systems.
• The consortium also indentified that theoptimum turbine size for offshore is significantly larger than the current ‘state of the art’.

• Representative electricity transmission network model: Electricity networks modelled for 275kV and 400 kV network capacity
  • The increase in the costs is proportional to the increase in the network length for the same network capacity and installation date.
  • For the same installation date, NPV total per km is higher for the higher capacity network.
• Representative Electricity Distribution Model: Electricity network modelled in rural, semi-urban, urban and London context
  • The share of costs represented by each of the Assemblies changes slightly from 2020 to 2040, following the same trend in all contexts, except for London.
  • Residential connections represent one of the highest costs in all contexts.
  • The LV network makes a high contribution to total cost in the urban context while in London the LV substations make the highest contribution.
  • First costs per capita increase as the context changes from rural through to urban areas.
  • First costs per capita decrease slightly from urban to London contexts.
  • The NPVs per capita increase as the density increases.
  • One additional factor that influences costs in different contexts is their different lifecycle profiles.
• Generic upgrade costs at transmission scale: upgrading existing 275kV and 400kV lines to increase capacity by ~100%
  • For the same installation date, Capex NPV per km is higher for the installation of a higher voltage network.
  • Opex NPV per km is higher for higher voltages
• Rapid car charging: upgrading existing distribution networks to allow for connection of rapid car charging units
  • Costs for the upgrade of the distribution network are dominant in all variations and contexts.
  • For the same number of connection points at the same installation date the installation of rapid charge connections is more costly in the semi-urban context.
  • he first costs and NPV per connection fall as the number of connections increases, which indicates that it is more cost effective to install a group of charging points than isolated single charging points.
• Rapid car charging: impact of network reinforcement that could be required due to significant increase in electric vehicles in a residential context (semi-urban and urban)
• The analysis is based on the assumption that there is a 50% increase in peak load due to a significant increase in the use of EVs.
• The LV network represents the highest share of reinforcement costs in all contexts, with costs per capita being higher in urban areas than semi-urban areas.
• Storage v reinforcement: analysis to explore the costs of storage compared with conventional reinforcement in three different applications –increase in local demand; distributed energy exporting to grid; installation of rapid car charging units
  • The analysis suggests that considering current prices for electricity storage,l reinforcement is cheaper both in terms of Capex and Opex.
  • Car charging: local generation may improve the potential for storage if the existing OHL has limited potential to charge batteries during periods of low demand.
• Fault Current Limiter v Reinforcement
  • Conventional reinforcement is currently more cost effective than refurbishment of the substation with the installation of the FCL
• Power electronics: assessing the costs of using power electronics using STATCOMS for rural windfarms with utility scale battery storage
  • STATCOMs: the costs of the complementary utility scale battery dominate. 
  • The impact of the utility scale battery on the costs of the project increases at the later installation date
• Power electronics: assessing the costs of using power electronics using back-to-back HVDC connection for coupling DNO networks
  • The costs of the back-to-back converter dominate
• Cost comparison of up grading HVAC vs installing new HVDC at transmission level in rural areas–within an existing wayleave and in a new wayleave
  • One of the main differences between HVDC and HVAC is intransmission losses.
  • There is significant uncertainty with the planning consent process for installing new or refurbishing existing HVDC OHLs in the UK

• Firstly, questions around the configuration and cost of representative (or ‘generic’) networks applicable to particular situations.
• Secondly, questions around the potential impact of selected, identified innovations on specific types of network.

• Representative Gas Distribution Model: connecting networks to transport sitesat different capacities for different network lengths, in rural, semi-urban, urban and London contexts
  • Context is a strong influencer of costs, with costs increasing from rural through to urban and London. .
  • Pipe costs dominate the overall network cost, particularly for the longer network lengths.
  • Pipe capacity and hence size has some influence over cost at the longer network lengths where pipe costs are the most significant element.
  • Normalised costs (ie costs per km) fall with increasing network length.
• Generic decommissioning costs (transmission), 100km length at different capacities / pipe sizes, rural context
  • Decommissioning costs are of the order of £90k/km.
  • Decommissioning of the pipework comprises around 80%-85% of cost, with the remaining 15%-20% relating to decommissioning the conversion station.
  • Pipe size has a minimal impact on cost.
• Generic decommissioning costs (distribution)for different contexts and populations
  • Decommissioning costs range from around £250k/km in London down to £60k/km in rural areas.
  • The relative importance of the different Assemblies in terms of share of cost varies with context: decommissioning the LP network represents the largest share of cost in rural areas (60%) and decommissioning domestic connections represents the largest share of cost in London areas (58%)
• Generic operational costs associated withremaining part of apartially decommissioned network (distribution)
  • In each context, reduction in Opex with increasing decommissioning is linear.
  • Direct costs represent approximately 80% of the overall Opex for gas distribution infrastructure
  • Decommissioning (abandonment) costs make up a small share of overall cost
  • After partial decommissioning, NPV of the partially decommissioned network per connection served increases as the percentage of network decommissioned rises.
• Gas transmission network: repurposing to hydrogen for different network lengths in a rural context
  • Overall the innovation of repurposing existing natural gas transmission networks to carry hydrogen is roughly half the cost of abandoning those same networks and building hydrogen pipelines from scratch
• Gas transmission network: repurposing to carbon dioxide for single network length in rural
  • The task compared repurposing existing gas transmission pipelines to carry gas phase CO₂ compared with building new transmission pipelines to carry dense phase CO₂.
  • Although operational conditions of pressure and and semi-urban contexts were different, they maintain the same CO₂ capacity flow
  • Both first costs and NPV are higher for new build than for repurposing.
  • All costs are higher in a semi-urban context than a rural one
• Natural gas conversion: installation of Biomethane to Grid injection points with different network lengths and capacities in rural and urban contexts
  • The cost of installing Biomethane to Grid plant is higher in urban areas than in less dense rural ones
  • Normalised costs per km fall with increasing network length
  • Normalised costs per m³ gas decrease with increasing gas injection capacities

• Representative hydrogen transmission model: transmission pipeline of different lengths required to transport hydrogen from production facilities to power generation sites and vehicle refuelling sites
  • Pipe lengths (NTS 32”) modelled for connection to production sites were 5km and 10km without the need for a compression station; pipe lengths (LTS 16”) for connection to refuelling sites were modelled at longer distances up to 200km, with a compression station required for anything over 100km
  • NPV/km for connecting to power stations was £5.4m for installation in 2025
  • NPV/km for connections to refuelling sites was in the range £3.0m to £3.5m depending on network length with the higher cost relating to the need to add in a compression station
  • The additionalcost of the power station scenario was due to the need to use larger diameter and hence more expensive pipe
• Representative hydrogen distribution model: distribution pipelines (LP/MP) required to connect production facilities to vehicle refuelling stations at different capacities and contexts
  • Context is a strong influencer of costs, with first costs per km increasing from rural through to urban and London. This is due to the higher costs of installing pipework in more congested areas.
  • Pipe costs dominate the overall network cost, particularly for the longer network lengths.
  • There is a small increase in cost per km for the higher capacity scenarios
• Hydrogen transmission and the impact of including storage:
  • Connecting a single large storage site into the network is considerably less expensive than connecting multiple storage sites of the same capacity
  • As the pipe lengths modelled were relatively short (5-10km) the storage costs dominated the overall project cost
  • Costs per mcm are considerably higher for the multi-storage option
  • The main benefit of the storage options is the storage itself and not the first cost savings associated with it.
• Hydrogen transmission network and the impact of pipeline material change: comparison of stainless steel 316L pipe with conventional steel using same pipe diameter (32” NTS)
  • First costs per km are higher for the stainless steel innovation
  • There is a slight reduction in cost/km for the longer stainless steel pipe lengths

UKERC hosted an international workshop in Oxford on 30-31 March to discuss the implementation of the Kyoto Protocol. The objective of the workshop was to determine whether and how Kyoto countries intend to deliver their Kyoto targets.

40 participants from Government, business, academia, think-tanks and nongovernmental organisations attended the workshop from 16 countries including several European Member States, Russia, Japan, Canada and Ukraine.

• Evaluation of the potential benefits of current and emerging DE technologies inexisting domestic buildings
• Categorisation of
  • The stock of existing domestic UK buildings
  • Building occupants into groups of similar energy use behaviours
  • The main appliance types (energy use patterns, control strategies, etc)
• Evaluation of the platform technologies and standards likely to be used in developingbuilding control systems
• Analysis of the potential benefits of building energy service controls
• Provisional model of existing UK domestic housing stock as the basis for predictingμDE impact out to 2030
• Identification of development and demonstration opportunities (including an outline ofhow to test these in an appropriate environment)

• DE equipment, as installed, does not reach the full potential of its laboratory promise
• Buildings Energy Management Systems (BEMS) are required to maximise the efficiency of both existing heating systems and micro DE systems
• Energy storage is essential to maximise use of generated energy within the home and reduce use of supplemental energy

• There are a number of important issues in the onshore grid system that is a function of the grid network, rather than the technologies themselves.
• New wide band-gap materials such as silicon carbide (SiC) andgallium nitride have the potential to deliver increased power electronic device voltage ratings, reduced switching losses, and raised operating temperatures. This has the potential for significant impact on the cost and performance of power electronic converters.
• The deployment of TCSCs on selected transmission corridors in the UK may improve the grid system’s ability to recover to stable operation following selected (unplanned) double circuit outages.
• In some circumstances, HVDC transmission can provide benefits by enabling long distance power transmission, eliminating reactive power flows from long HVAC cable circuits and enabling asynchronous system connections.
• The conversion of selected transmission corridors from AC to HVDC may improve the grid system’s ability to recover to stable operation following selected (unplanned) double circuit outages
• Multi-terminal HVDC (necessary for embedding DC interconnectors in a meshed system) is feasible with both LCC and VSC technologies.
• For a given transmission tower (‘pylon’) size significantly more power can be transmitted on a DC circuit than on an AC circuit (typically two to three times).
• There appears to be no benefit case for converting individual transmission lines in the UK Grid to HVDC to gain additional transmission capacity
• A total of 26 specific technology opportunity areas were identified by the project consortium as worth further examination by the ETI.

• Hydrodynamic interactions between WECs and TECs operating in arrays can be significant thereforemodelling of array effects is essential when estimating the energy yield of potential project.
• Wave tank testing of WEC arrays is extremely demanding and needs to be carefully planned and analysed. In particular the effects of reflections can be of the same order as effects of the interactions you are trying to measure. Despite the challenges, it is possible to measure significant interactions in the tank.
• Linear potential flow theory (used in WaveDyn) is sufficient to accurately model device interactions. Weakly non-linear wave kinematics (non-breaking) do not have a significant influence on device response and performance for operational conditions.
• The spectral approach in WaveFarmer is capable of accurately predicting energy yield for a large wave farm.
• Model-scale & full-scale validation of WaveDyn has been invaluable as has model scale validation of WaveFarmer. However, full-scale validation of WaveFarmer will be essential when data becomes available.
• The mean performance of a tidal device can be predicted usinga Reynolds Averaged Navier Stokes (RANS) model, however, more work is required in order to `correct’ this type of model so as to accurately capture wake recovery.
• Basin scale modelling using linear momentum actuator disc theory (LMADT) for one row of devices was successful. The limitations of the model are well understood, and the upper limit of energy extraction compares well to analytical methods. However, 3D models such as TidalFarmer are required for detailed assessment of annual energy production
• .Whilst progress has been made on the analysis of blockage effects of arrays and devices, further work is required to fully understand and model the flow reduction through the array.

• The launch of WaveFarmer & TidalFarmer is only the first step in increasing project developers’ confidence in their return on investment in WEC & TEC arrays.
• Effective commercial exploitation will be required to stimulate use of the tools.
• The resulting data generated by full scale deployments will enable further development of the tools and the reduction of uncertainty.
• The reduction of uncertainty could be accelerated by investment in trials to generate full scale data for validation

• the activities comprising the first five years of a development programme for the UK deployment of a Small Modular Reactor
• a timeline with milestones to accompany this programme definition
• the necessary capability of the SMR utility/developer organisation during this phase of a UK SMR development programme

1. Implementation of an First OfA Kind (FOAK) SMR is possible without facilitative action by Government
2. Pre-FID investor confidence is of critical importance for achieving the 2030 timeline
3. For an effective programme to achieve FOAK SMR deployment, significant Governmentcommitment and facilitative action is required from the outset
4. It is insufficient for the first 5 years of the deployment schedule to focus on just GDAand RegulatoryJustification
5. A strong and early marriage is required between developer / operator and vendor
6. The notion of a developer / operator / vendor ‘boot camp’ is proposed as a near-term risk mitigation activity
li>Deployment of a FOAK SMR in the UK is achievable by 2030underthe bounding scenario considered by this study
7. The scale of the recruitment challenge to establish a Nuclear Baseline should not be underestimated, with staged planning essential
8. Regulators will need tobe able to resource-up without adverse influence on current UK nuclear safety activity
9. A co-ordinated public communications plan is required, led by the prospective Licensee, supported by the vendor and facilitated by Government
10. Bounding assumptions were judged to be sound in the context of a deployment schedule leading to a UK FOAK SMR operating by 2030
11. The evidence gathered forms the basis of a toolkit which could be used to test or assess the feasibility of specific scenarios for SMR Deployment in the UK

The schedule for UK FOAK deployment operations would depend upon the associated assumptions. Such options may include:

• A risk-averse deployment plan which focusses on completion of GDA and Regulatory Justification to establish a credible design before commencing work on site specific aspects and developing a credible nuclear operator. This may suggest a schedule with risk of delay to FOAK first operation beyond 2030.
• A deployment plan for a less technology/design ready SMR. GDA would not commence until later in the schedule with possible plans to complete manufacturing and construction in a shorter timeframe.This may suggest a schedule with risk of delay to FOAK first operation beyond 2030.
• Assessment of developer / operators with different characteristics and different working arrangements and modes of engagement with the vendor. For example,a developer with a mature and capable licensee organisation which may suggest an opportunity for an accelerated deployment schedule.
• FOAK deployment at a site identified as potentially suitable for nuclear development in the Nuclear NPS.This may again suggest an opportunity for an accelerated deployment schedule

• the activities comprising the first five years of a development programme for the UK deployment of a Small Modular Reactor
• a timeline with milestones to accompany this programme definition
• the necessary capability of the SMR utility/developer organisation during this phase of a UK SMR development programme

1. Implementation of an First OfA Kind (FOAK) SMR is possible without facilitative action by Government
2. Pre-FID investor confidence is of critical importance for achieving the 2030 timeline
3. For an effective programme to achieve FOAK SMR deployment, significant Governmentcommitment and facilitative action is required from the outset
4. It is insufficient for the first 5 years of the deployment schedule to focus on just GDAand RegulatoryJustification
5. A strong and early marriage is required between developer / operator and vendor
6. The notion of a developer / operator / vendor ‘boot camp’ is proposed as a near-term risk mitigation activity
li>Deployment of a FOAK SMR in the UK is achievable by 2030underthe bounding scenario considered by this study
7. The scale of the recruitment challenge to establish a Nuclear Baseline should not be underestimated, with staged planning essential
8. Regulators will need tobe able to resource-up without adverse influence on current UK nuclear safety activity
9. A co-ordinated public communications plan is required, led by the prospective Licensee, supported by the vendor and facilitated by Government
10. Bounding assumptions were judged to be sound in the context of a deployment schedule leading to a UK FOAK SMR operating by 2030
11. The evidence gathered forms the basis of a toolkit which could be used to test or assess the feasibility of specific scenarios for SMR Deployment in the UK

• A risk-averse deployment plan which focusses on completion of GDA and Regulatory Justification to establish a credible design before commencing work on site specific aspects and developing a credible nuclear operator. This may suggest a schedule with risk of delay to FOAK first operation beyond 2030.
• A deployment plan for a less technology/design ready SMR. GDA would not commence until later in the schedule with possible plans to complete manufacturing and construction in a shorter timeframe.This may suggest a schedule with risk of delay to FOAK first operation beyond 2030.
• Assessment of developer / operators with different characteristics and different working arrangements and modes of engagement with the vendor. For example,a developer with a mature and capable licensee organisation which may suggest an opportunity for an accelerated deployment schedule.
• FOAK deployment at a site identified as potentially suitable for nuclear development in the Nuclear NPS.This may again suggest an opportunity for an accelerated deployment schedule

• Examines initiatives (with a clear focus on heat), successes and lessons learned; their outcomes / next steps; and possible learnings for the UK
• Identifies the policies driving these initiatives
• Identifies who’s involved and why

• Recommended countries where there are many learnings for the ETI are Denmark and the Netherlands– heat pumps, market structures, district heating, and exploiting synergies between electric and gas networks.
• Specific projects / areas for investigation in these countries are pointed out
• Consider customer recruitment for trials at a very early stage and place the customer proposition at the heart of project design
• The ETI may be able to utilise platforms / hardware / software that has already been developed for other projects
• We see an absence, generally, of how gas, electricity and heat networks can work together, but some projects integrating two networks into a wider system. We believe this is a critically important aspect of a ‘smart heat system’
• Business models and market frameworks that the ETI could utilise
• Examples of highly relevant purely private sector innovations

1. tidal stream foundations
2. low-cost wave energy structures
3. optimised tidal stream blade technologies
4. optimised power take-off systems (wave & tidal)
5. wave energy sensors for control system optimisation and yield improvement.

• Approach to risk – for investability, a lower risk approach was taken.
• Approach to public safety – this affected CO₂ pipeline routings for example.
• Scale (upto 2-3 GWe), to be comparable with nuclear scales of operation. This impacted, for example, CO₂ store selection decisions while some sites were unable to host the largest scales of operation tested by the project.
• Ability to gain consents such as planning permission.
• Public acceptance – this impacted, for example, site locations near areas of high population in particular since the plant size is extremely large; and CO2 pipeline routing choices.

• Concentrated Solar Power (CSP) generated in the Sahara to be imported to theUK;
• 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

• 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

• Electricity transmission represents the least cost solution if electrical energy isrequired at the demand site
• Chemical energy carriers do however compare favourably with electricitytransmission where they can be used directly
• The use of electro-chemical energy storage media (i.e. a Zinc-Air Battery/shipconcept) is unlikely to represent an economically viable concept as the cost ofelectricity delivered is over six times that of the baseline transmission option

• The direct and immediate transfer of energy tothe point where it will be used via electricity networks or pipelines, i.e. transmission; or
• The generation and storage of energy in a mobile device that can be transported further down the supply chain where it can either be used continuously or intermittently as required, i.e. a transportable energy solution.

• hydrogen;
• hydrocarbons produced via the Fischer-Tropsch process;
• ammonia;
• zinc air batteries; and
• aluminium.