Network Options Assessment 2016/17
UK electricity transmission
JANUARY 2017 Network Options Assessment 2016/17 – January 2017 2
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We are in the midst of an energy revolution. The economic landscape, developments in technology and consumer behaviour are changing at an unprecedented rate, creating more opportunities than ever for our industry.
Our Network Options We will achieve this through our Assessment (NOA) publication, Network Options Assessment (NOA). along with our other future The NOA aims to make sure energy System Operator that the transmission system is publications, aims to encourage continuously developed in a timely, and inform debate, leading economic and efficient way, providing to changes that ensure a value for our customers. The results secure, sustainable and from ETYS 2016 have fed into NOA affordable energy future. 2016/17 to provide the required transmission capabilities. Your views, knowledge and insight have shaped the publication, helping To conduct the NOA, we asked each us to better understand the future of of the Transmission Owners in GB energy. Thank you for this valuable (SHE Transmission, SP Transmission input over the past year. and the TO business within National Grid) to identify investment options, Now our 2016 analysis is complete, timings and costs to improve the we have been able to look holistically capability of a number of stressed at the results. They point to some system boundaries that we had important themes and messages. identified during the ETYS process.
As highlighted in our Electricity Ten I hope that you find this document, Year Statement (ETYS) 2016 we along with our other System Operator continue to see increasing new low- publications, useful as a catalyst for carbon generation together with fossil wider debate. For more information fuelled plant closures and increasing about all our publications, please see interconnector activity putting page 7– 8. additional stress on the network. Our role is to maintain an efficient Please share your views with us; and economic balance between you can find details of how to investing in further infrastructure and contact us on our website http:// constraining the use of the system www.nationalgrid.com/noa. when necessary – striking a balance between the risk of stranding assets Richard Smith from investing too early; and the Head of Network Capability potential high costs of constraints (Electricity) from investing too late. Getting this balance right will deliver the best value for consumers. Network Options Assessment 2016/17 – January 2017 02
Contents
Chapter one Chapter five
Aim of the report...... 10 Investment recommendations...... 84 1.1 Introduction ...... 10 5.1 Introduction...... 84 1.2 How the NOA fits in with the FES 5.2 Recommended delivery dates...... 87 and ETYS ...... 11 5.3 Critical options’ least regret analysis....93 1.3 What NOA can do...... 12 5.4 Recommendation for each option...... 97 1.4 What NOA cannot do...... 13 5.5 Onshore competition...... 101 1.5 The NOA Report methodology...... 14 1.6 Navigating through the document...... 15 1.7 What’s new...... 16 Chapter six 1.8 Stakeholder engagement and feedback...... 17 Interconnection analysis...... 104 6.1 Introduction...... 104 Chapter two 6.2 Interconnection theory...... 105 6.3 Current and potential interconnection...... 106 Methodology...... 20 6.4 Methodology...... 107 2.1 Introduction...... 20 6.5 Outcome...... 109 2.2 NOA process...... 21 6.6 Summary...... 115 2.3 Economic analysis...... 24 2.4 How the NOA connects to the SWW process...... 30 Chapter seven 2.5 Interaction between NOA results and FES...... 32 2.6 Other options...... 33 Stakeholder engagement...... 118 7.1 Introduction...... 118 7.2 Continuous development...... 119 Chapter three 7.3 Stakeholder engagement...... 120
Boundary descriptions...... 36 Chapter eight 3.1 Introduction...... 36 3.2 North...... 37 3.3 East...... 53 3.4 South...... 55 Appendix A – SWW projects...... 122 3.5 West...... 60 8.1 Shetland Link...... 122 8.2 Orkney Link...... 124 8.3 Western Isles Link...... 126 8.4 Eastern subsea HVDC Link from Chapter four Peterhead to Hawthorn Pit (E4DC)...... 128 8.5 Eastern Scotland to England Link: Torness to Hawthorn Pit Offshore Proposed options...... 66 HVDC (E2DC)...... 132 4.1 Continuous development...... 66 8.6 North West Coast connections 4.2 Reinforcement options – project...... 135 Scotland and North of England...... 67 8.7 Hinkley Point C connection project...... 137 4.3 Reinforcement options – Appendix B – Meet the NOA team...... 140 East of England...... 76 Appendix C – List of options’ four-letter codes.141 4.4 Reinforcement options – Appendix D – Glossary...... 145 South of England...... 78 Disclaimer...... 150 4.5 Reinforcement options – Wales and the West of England...... 81 Network Options Assessment 2016/17 – January 2017 03
Executive summary
Using the 2016 Future Energy Scenarios (FES) and ETYS 2016, the System Operator (SO) recommends the options which the GB Transmission Owners should invest in for the upcoming year. Below, we present a summary of the key points from our economic analysis.
Key points
The SO recommends investment of option earlier than necessary. Where the £83m in 2017/18 across fourteen decision cannot be delayed any further, projects to maintain the option to deliver our economic analysis assesses the cost projects worth almost £3.8bn. This year’s impact of not investing in this financial investment will allow us to manage the year. As a result of this analysis, the SO capability of the GB transmission networks recommends to delay spend of over £2.5m against the uncertainty of the future. on three options for this investment year. This will make sure that the networks can The table below is an overview of the NOA continue supporting the transition to the 2016/17 investment recommendations future energy landscape in an efficient, where the decision must be made this year. economical and coordinated way. Our Interconnection analysis has As the energy landscape is uncertain, the demonstrated that the planned first window SO must make certain that all investment Cap and Floor interconnection will be is truly necessary. We performed analysis beneficial for GB consumers under all FES of over 80 different investment options energy scenarios and will provide benefit proposed by the GB Transmission Owners. to GB and European markets. The SO’s We identified 32 options where no decision analysis suggests a total interconnection was yet required, allowing the SO to delay capacity between 14.8 to 17.3 GW between the recommendation to a later investment GB and European markets by 2030 would year. This ensures that we never make provide optimal benefit. an investment recommendation for an
£83m 14 17.3 GW Investing £83 million Through 14 options Up to 17.3 GW interconnection Network Options Assessment 2016/17 – January 2017 04
Executive summary
Optimal Delivery Date Last Year’s 2016/17 Reasons for Option EISD Gone Consumer Slow No Local No Local Recommendation Recommendation Change Green Power Progression Progression Contracted Contracted BBNO1 New Beauly Not optimal at to Blackhillock 2025 N/A N/A N/A N/A N/A N/A Delay Do not Proceed this time 400kV double circuit
Reinforcement is LDQB required due to No Decision Lister Drive 2020 2020 2020 2020 2021 N/A N/A Proceed heavy constraint Required quad booster build up in early years on B7a
WHTI2 Turn-in of West Boldon 2020 2020 2020 2020 2020 N/A N/A Proceed Proceed No Change to Hartlepool circuit at Hawthorn Pit
LNRE Regret Reconductor No Decision analysis gave a Lackenby to 2022 2022 2022 N/A N/A N/A N/A Delay Required recommendation Norton single to delay this year 400kV circuit
MRUP Generation Uprate the background Penwortham to change has Washway Farm 2023 2023 2023 2023 2026 N/A N/A N/A Proceed made this to Kirkby 275kV reinforcement double circuit viable to 400kV
This reinforcement is new for NOA 2016/17 as a 4 GW OENO net reduction Central of power on 2024 2024 2025 2024 2024 N/A N/A N/A Proceed Yorkshire the west of reinforcement the country in some scenarios changes the power flow balance between east and west
E4DC Eastern subsea HVDC Link 2024 2024 2024 2024 2026 N/A N/A Proceed Proceed No Change from Peterhead to Hawthorn Pit
Coordination E2DC between Eastern subsea No decision reinforcements in HVDC Link 2024 2024 N/A N/A N/A N/A N/A Proceed required the North make from Torness to this reinforcement Hawthorn Pit viable
1 The new Beauly to Blackhillock 400kV double circuit (BBNO) was critical in NOA 2015/16 but recommended to delay. For NOA 2016/17, BBNO is now considered not optimal and therefore we recommend ‘Do Not Proceed’ at this time. 2 WHTI is a modified version of ELEU which was presented in last year’s NOA. Network Options Assessment 2016/17 – January 2017 05
Optimal Delivery Date Last Year’s 2016/17 Reasons for Option EISD Gone Consumer Slow No Local No Local Recommendation Recommendation Change Green Power Progression Progression Contracted Contracted
NOR1 Reconductor 13.75km of Reinforcement No Decision Norton to 2022 2025 2023 2022 2026 N/A N/A Proceed has become Required Osbaldwick critical this year 400kV double circuit
TLNO Low cost Torness to reduces the North East 2028 N/A N/A 2028 N/A N/A N/A N/A Proceed regret of England AC proceeding reinforcement
Driven by WEOS changing Western HVDC 2019 2023 2025 2025 2024 N/A N/A Proceed Delay generation Link fast de- patterns in north load scheme west England
BMMS Reinforcement 225MVAr No Decision 2023 2024 2028 2026 2023 2023 N/A Proceed has become MSCs at Required critical this year Burwell Main
SCRC South East 2018 2018 2018 2018 2018 2018 2018 Proceed Proceed No Change coast reactive compensation
FLRE Fleet to 2020 2020 2020 2020 2020 2020 2020 Proceed Proceed No Change Lovedean reconductoring
KLRE Kemsley to 2021 2021 2021 2021 2021 2021 2021 Proceed Proceed No Change Littlebrook circuits uprating
Reinforcement SEEU is required due Reactive to the large compensation 2021 2021 2021 2021 2021 2021 2021 N/A Proceed number of protective interconnectors switching connecting in scheme the region
WYTI Wymondley 2020 2029 2024 2030 2020 2029 2029 Delay Delay turn-in
No Change. We recommend HSNO proceeding Hinkley Point to 2023 2026 2027 2031 2034 2024 N/A Proceed Proceed with the SWW Seabank new project based on double circuit the contracted connection date
WPNO Proceed Wylfa to Pentir because of 2024 2030 2030 2029 N/A 2025 N/A Delay Proceed3 second double customer circuit agreement
3 Work on the Wylfa to Pentir second double circuit has already started, and should continue due to a local customer agreement in place. Network Options Assessment 2016/17 – January 2017 06
Executive summary
It is important to recognise that these We welcome your views recommendations represent the best view at Our customers and stakeholders have a snap-shot in time. Investment decisions taken contributed to the production of this NOA by any business should always consider these publication from the very beginning, by being recommendations in the light of subsequent involved in Ofgem’s Integrated Transmission events and developments in the energy sector. Planning and Regulation project and shaping our Future Energy Scenarios. The project options we have recommended in this NOA 2016/17 will make sure that the GB We want to evolve this process and report, transmission network can continue supporting year on year, to better serve your interests. the transition to the future energy landscape in So we’d welcome your views on the content an efficient, economical and coordinated way. and scope of this year’s document and would like to know what changes you’d like us to This year NOA recommends the options make to future versions. There are five ways that meet the Ofgem criteria for onshore to tell us what you think: competition. These can be found in Customer seminars. Chapter 5 section 5. Operational forums. Email us at transmission.etys@ nationalgrid.com Feedback via survey at https://www. surveymonkey.com/r/2016-17NOA Bilateral stakeholder meetings.
The Stakeholder Engagement chapter sets out further information on our 2016 ETYS and NOA stakeholder activities programme. Your continuing support and feedback on our Future of Energy processes and documents are important to us. Please get in touch. Network Options Assessment 2016/17 – January 2017 07
Continuing the conversation
Future energy publications We build our long-term view of the gas National Grid has an important role to play in and electricity transmission capability and leading the energy debate across our industry operability in our Future Energy Scenarios and working with you to make sure that (FES), Ten Year Statements (ETYS and together we secure our shared energy future. GTYS), Network Options Assessment (NOA), As System Operator (SO), we are perfectly gas Future Operability Planning (FOP) and placed as an enabler, informer and facilitator. electricity System Operability Framework The SO publications that we produce every (SOF) publications. To help shape these year are intended to be a catalyst for debate, publications, we seek your views and share decision making and change. information across the energy industry that can inform debate. The starting point for our flagship publications is the Future Energy Scenarios (FES). The FES The Gas Ten Year Statement (GTYS) describes is published every year and involves input from in detail what and where entry and exit capacity stakeholders from across the energy industry. is available on the gas National Transmission System (NTS). The GTYS provides an update These scenarios are based on the energy on projects we are currently working on. It also trilemma (security of supply, sustainability provides our view of the capability requirements and affordability) and provide supply and and network development decisions that demand projections out to 2050. We use these will be required for the NTS over the next ten scenarios to inform the energy industry about years. If you are interested in finding out more network analysis and the investment being about the longer-term view of gas capability planned, which will benefit our customers. and operability, please consider reading our Future Energy Scenarios (FES), and gas For short-term challenges around gas and Future Operability Planning (FOP) publications. electricity transmission, we produce the Summer and Winter Outlook Reports every The Electricity Ten Year Statement (ETYS) six months. We publish them ahead of each applies Future Energy Scenarios to network season to provide a view of gas and electricity models and highlights the capacity shortfalls supply and demand for the coming summer on the GB National Electricity Transmission or winter. These publications are designed to System (NETS) over the next ten years. You support and inform your business planning can find out more about the longer-term view of activities and are complemented by summer electricity capability and operability by reading and winter consultations and reports. our Future Energy Scenarios (FES) and System Operability Framework (SOF) publications. Network Options Assessment 2016/17 – January 2017 08
Executive summary
Our gas Future Operability Planning (FOP) The System Operability Framework (SOF) publication describes how changing uses the Future Energy Scenarios to examine requirements affect the future capability future requirements for the operability of of the NTS beyond 2050. It also considers GB electricity networks. It describes how these requirements may affect NTS developments in operational needs and operation and our processes. The FOP provides information that can help towards may highlight a need to change the way developing new technology, codes and we respond to you or other market signals. solutions that improve system operability. This, in turn, may lead us to modify our If you are interested in finding out more about operational processes and decision making. the longer term view of electricity capability This publication helps to make sure we and operability, please consider reading our continue to maintain a resilient, safe and Future Energy Scenarios (FES), Electricity Ten secure NTS now and into the future. If you Year Statements (ETYS) and Network Options are interested in finding out more about Assessment (NOA) publications. the longer-term view of gas capability and operability, please consider reading our Future Energy Scenarios (FES) and Gas Ten Year Statement (GTYS). Chapter one 09 10
Aim of the report the Aim of
one Chapter Chapter 2017 – January 2016/17 Assessment Options Network Chapter one projects mightprojects be suitable for competition. the of which Ofgem to recommend to also (ETYS) Ten Statement Year Electricity the in defined as requirements withproceed to meet the future network to projects which to as Britain Great across (TOs) Owners Transmission the to Its purpose is to make recommendations of and quality supplysecurity standard. the national electricity transmission system of electricity transmission, consistent with system economic and coordinated efficient, The The further. it to develop us tell you what we’ll use produced for you, our stakeholders, and It’s 2016/17 published. to be second the is The The (SO). Operator the System as it works produces with the publications Grid that National the chapter NOA This introduces Introduction 1.1 ofAim the report Network OptionsAssessment2016/17 –January2017 NOA Network Options (NOA) Assessment Network is the driver for developing an an developing for driver the is . A key aim is is aim . Akey
FES FES on 2017 based is and ETYS The The Transmission System (NETS). potential options for the National Electricity and requirements of picture full the give ETYS the together, read When and electricity transmission networks. the potential development of both the gas (FES) byunderpinned our Future Scenarios Energy This is report one of the publications and explains how explains how and NOA . This means that the NOA the that means . This have a consistent base for assessing assessing for base aconsistent have 2016/17 was published in January January 2016/17 in published was 2016.
and NOA and and the the and
10 Chapter one 11
can can
and NOA ETYS , and ETYS emphasises reinforcing the network the reinforcing emphasises NOA document. The FES be read together form to an evolutionary network. electricity GB’s of importantIt’s note that to while we recommend optionsmeet to system needs, the TOs or other relevant parties will ultimately decide on what, where and when invest. to Some of the alternative options we have evaluated are reduced build options as Methodology. – 2 Chapter in explained and consistent voice in the development development the in voice consistent and The Network Options Options Network Assessment 2017 January and we are keen embrace to innovative ways doto so.
Electricity Ten Electricity Ten Statement Year November 2016 fits in with the FESthe with in fits to assess to the network in November and the TOs 2016 , we summarise each reinforcement publication. Further explanation of this this of explanation Further publication. UK gas and electricity transmission Future Energy Future Scenarios JULY 2015 JULY Future Energy Energy Future Scenarios July 2016 We useWe the FES published were requirements These NETS. GB in the ETYS the reinforcing for options with responded network. Our economic analysis of these the for foundation the forms then options NOA process and each of the publications can be found in Chapter 2 – Methodology. In the NOA option and our cost–benefit analysis of those options. The report also identifies our each for options or option recommended region of the GB network, based on the cost–benefit analysis. For some options, summary Strategicthe a included of have we Wider Works (SWW) analysis in this document. requirements for power flows across the The SO produces a suite of publications on the the on publications of suite a produces SO The future of energy for Great Britain (see page 7–8). These aim inform to the whole energy debate through addressing specific issues in each 1.2 NOA the How 2017 – January 2016/17 Assessment Options Network
Future Energy Scenarios
No. 4031152 www.nationalgrid.com Registered in England and Wales Registered Gallows Hill, Warwick. Gallows Hill, Warwick. CV34 6DA United Kingdom National Grid House, Park, Technology Warwick National Grid plc Chapter one What 1.3 ofAim the report Network OptionsAssessment2016/17 –January2017 market-driven analysis. socio-economic welfare based on to maximise order in grids electricity of interconnection to other European NOA benefit. most the deliver will that atime at completed are they sure to make projects current continue or delay NOA in world. an uncertain transmission networks to manage risk their in invest should TOs the when NOA
can indicate the optimum level level optimum the indicate can can recommend whether TOs should can recommend how, where and and how, where recommend can NOA can do do can
are eligible for onshore competition. NOA options. SWW for should begin developing the needs case NOA can indicate to Ofgem whether options they to whether TOs indicate can
12 Chapter one 13
cannot list all of the options that the cannot evaluate the network cannot forecast or recommend NOA TOs develop as some reach only a low level of maturity and are discarded early. It is for the develop TOs to options and consult with options. on variations on stakeholders NOA possible of challenges technical and interconnectors. It can only evaluate the completed a welfare socio-economic provide. would interconnector NOA future interconnection levels. It indicates indicates It levels. interconnection future interconnection. of level optimum the
cannot do NOA cannot comment on options’ specific cannot evaluate options’ specific maintenance assess network cannot cannot insist that options be pursued.
details, such as how they are planned or delivered. It is the TOs who decide how equipment, of choice the as such designs These impacts. environmental or route connections. customer individual or projects for how, whenfor how, and where they invest in their networks. NOA options. their implement they NOA types of decisions can only be made by the TOs when the options are in a more stage. advanced NOA NOA canWe only recommend based upon our responsible ultimately are TOs The analysis. What 1.4 2017 – January 2016/17 Assessment Options Network Chapter one methodology was published in July 2016. the refinement, and discussions more after 2016 May in and, website our on published the methodology for NOA of draft initial The Ofgem. and TOs onshore the with 2016, working early in methodology NOA the started We detail. finer the the the The The The 1.5 ofAim the report Network OptionsAssessment2016/17 –January2017 NOA NOA
NOA NOA process should work and establishes Report methodology Report sets out how Report methodology methodology Report 2016/17 was was 2016/17 Report Report
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14 Chapter one 15
in future publications. publications. future in six five
seven Chapter Chapter Chapter be proceeded for this investment year. 103 page analysis Interconnection interconnection our presents 6 Chapter analysis results. describe We the optimum between interconnection European of levels GB and European markets and explain the theoryeconomic interconnector behind benefit to the consumer. This is an important areyou interestedif chapter in the future of interconnection. European 117 page engagement Stakeholder Chapter 7 discusses how we can work with you improve to the NOA This is a useful chapter like see to if how you’d opinion. and feedback your us give can you in whether we recommend options to to options recommend we whether in an important chapter if you are interested Investment recommendations page 83 page recommendations Investment investment our presents 5 Chapter is This 2017/18. for recommendations document in a logical document in manner
or if process and process process analysis but are described in Chapter 4 – Proposed Options. Chapter 2 – Methodology two four
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1 Chapter Chapter Chapter
covers why these other options are kept separate from our analysis. Some options are not in our NOA 1 to help you understand reach recommendations our you help we to how and conclusions. Boundary 35 descriptions page Chapter 3 describes how we divide the GB and analysis for boundaries into network 65 page options Proposed Chapter 4 introduces and describes the increase can which options reinforcement Methodology page 19 page Methodology Chapter 2 describes the NOA the economic theory behind it. This is a good overview if you are unfamiliar with NOA like understand to you’d more about how we perform the cost–benefit analysis of options. gives a description of each boundary as well as an overview of the types of generation you can find within each boundary. This is a good introduction like improve to if you’d network. GB the of understanding your Systems’ Transmission Electricity National the (NETS’s) capability. This is a good description of the types of options being proposed by the TOs. We have structured NOA the have We Navigating throughNavigating the document 1.6 2017 – January 2016/17 Assessment Options Network Chapter one decide which party will deliver the project. the deliver will party which decide to process tender acompetitive through go may options some that means This by Ofgem. options against the competition criteria provided these evaluate also will we year. addition, In this to proceed recommend we options the lists recommendations 5–Investment Chapter works wider our of description aclearer has now 2–Methodology Chapter clearer, even results and analysis our to make order In evaluate the future optimum interconnection – Interconnection analysis. This chapter will 6 Chapter forms now but Interconnectors’ Onshore competition competition Onshore 3 1.7. explanation Detailed of our economic analysis 2 1.7. ‘ titled report a separate previously NOA the of part as assessment This year we have included our interconnection analysis Interconnection 1.7.1 improveand the NOA Acting we feedback, stakeholder on continue to evolve What’s new? 1.7 ofAim the report new additions for the NOA Network OptionsAssessment2016/17 –January2017
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2016/17: from an economic perspective. value delivered by proposed reinforcements the assess we how and analysis cost–benefit economical system of electricity transmission. and coordinated efficient, an of part as the development of interconnector capacity timing of any increase. capacity This facilitates ideal the and scenarios, four our of each for markets European and GB between capacity can further develop it to meet your needs. your to meet it develop further can we how know us to let hesitate don’t so NOA the improving continue can we how We always want to hear suggestions on
16 Chapter one 17 To help encourage your feedback, you you feedback, your encourage help To will see that included we’ve prompts such as this for engagement throughout the in areas highlight these and publication each section like where your views. we’d
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we’ve included in this publication and publication this in included we’ve be delightedwe’d hear to from you any by appropriate means. are We also keen to know prefer how share you’d to your views and help us develop the NOA for engagement Stakeholder – 7 Chapter more information. Stakeholder engagement and feedback questions the to limited isn’t Feedback 1.8 2017 – January 2016/17 Assessment Options Network Chapter one Network OptionsAssessment2016/17 –January2017 18 Chapter two Methodology Methodology two Chapter Network OptionsAssessment2016/17 –January2017 20 19 Chapter two Methodology Introduction 2.1 Network OptionsAssessment2016/17 –January2017 It also explainsIt also how NOA NOA for chapterThis the highlights used the methodology and explains the economic theory behind our analysis. our behind analysis. explains and theory the economic ties in with the SWW process. in with ties the SWW
20 Chapter two 21
or methodology. methodology. may recommend a
. It follows the five stages of the NOA NOA a project or projects in development to boundary or capacity additional deliver alternative system benefits, as identified Statement Year in the Ten Electricity document.” equivalent We defineWe them as: “ In accordance with our licence condition, condition, licence our with accordance In Transmission Electricity National Major System reinforcements are defined in Paragraph of the NOA 21 change the to delivery of these works. If this happens, we will work with those stakeholders and keep them informed. shows theFigure steps we take 2.1 produce to the Some users’ connection agreements have have agreements connection users’ Some works. enabling their as reinforcements major This means that the NOA Report process.
. We have. We published this methodology describes how we we how describes methodology process methodology on our website below: website our on methodology NOA NOA The 2.2 NOA 2017 – January 2016/17 Assessment Options Network year’s methodology on our website. It also also It website. our on methodology year’s interconnectors for methodologies the includes and SWW. As the NOA is derived from the two the (NDP), Policy Development Network methodologies are can similar. find You a copy alongside methodology NDP original our of assess Major National Electricity Transmission Transmission Electricity National Major assess System (NETS) reinforcement options meet to the requirementsthat the SO finds from its analysis of the FES the www2.nationalgrid.com > UK Sites > Industry Information (more information) > Future of Energy > Network Assessment Options www2.nationalgrid.com /WorkArea/DownloadAsset. aspx?id=8589936185 www2.nationalgrid.com /WorkArea/DownloadAsset.aspx?id=34153 Chapter two Methodology are: scenarios four The analysis. economic and studies our for foundation the form and future background conditions to assess against FES the with The The Scenarios Future Energy 2.2.1 NOA process Figure 2.1 Network OptionsAssessment2016/17 –January2017 Consumer Power. No Progression. Slow Progression. Gone Green. UK generation engagement and demand NOA Stakeholder scenarios process F Input E process for the NETS planning starts starts planning NETS the for process S
. They are a plausible range of of range aplausible are . They Future transmission and requirements Network analysis Requirements capabilities E T Y S meet requirements Network analysis Reinforcement options to Options Network OptionsAssessment(NOA) > fes.nationalgrid.com at: find can you which FES the see please created, are they FES our on information more For FES document. analysis ofoptions preferred options Selection of Economic Selection
recommendations NOA publication GB investment and how Output 2016, 2016,
22 Chapter two 23 process With this varied list of options, we move onto the fourth stage of the NOA ‘Selection’. We use our understanding of of understanding our use We ‘Selection’. constraint costs carry to out a cost–benefit analysis of all the options. This narrows the list of proposed options into a list of our the are believe we which options, preferred best ones at the time that provide the most benefit for GB consumers.You can find the full Chapter in recommended options our of list 5 – Investment recommendations. How we perform the cost–benefit analysis is described in greater detail in the following section. www.nationalgrid.com/etys
to transmission transmission to . We encourage. We a range of is the second stage in the NOA 2016, which you 2016, can find at: ETYS As well as these build options, both the opportunities propose can SO and TOs Reduced build options. build reduced for options are solutions that require very maximise of use instead and little build ways. innovative in often assets existing can findYou a full list of the options that we analysed in Chapter 4 – Proposed options. In order to create an electricity transmission transmission electricity an create to order In network fit for the future,TOs propose needs reinforcement the meet to options outlined ETYS by assets existing upgrading include that options or creating new assets in order ensure to that we have a strong selection of options from assess. to which 2.2.3 Assessment Options Network 2.2.2 Statement Year Electricity Ten 2017 – January 2016/17 Assessment Options Network The process. apply We the FES system models and calculate the power flow network. transmission the across requirements do this we haveTo developed the concept of physically exist don’t Boundaries boundaries. but are insteadconceptual a split of the network into two adjacent parts. As power transfers between these areas, we can see which parts of the network are under the most stress and where network reinforcement would be most suitable. The capability of the network and its future requirements are published in ETYS Chapter two Methodology than its EISD. We need to take this into account account into this to take We EISD. need its than earlier delivered be cannot option an and (EISD) date’ service in ‘earliest the It’s called analysis. our in factor important an is delivered be can option an that year earliest The others. than with some options taking longer to implement network the to TOs upgrade the for time takes it However, time. right the at options right the in to TOs invest to the recommend must we consumer, the to benefit to maximise order In years Optimum 2.3.2 unconstrained area of the network. Balancing an in generation with energy this replace we balance, energy an to maintain order In output. their to limit area affected the within generators When we constrain the network, we ask network. the ‘constraining’ to as referred is transfer power of limiting This assets. dangerously overloading the transmission to avoid transfer power the reduce must room SO’s the control capability, boundary’s that above is boundary system a transmission locations. When the power required across demand are typically situated in different boundaries occurs because generation and network our across energy of transfer The networks. their in to TOs invest the recommend we why understand first must we To understand our investment recommendations, Theory 2.3.1 Economic analysis 2.3 Network OptionsAssessment2016/17 –January2017
optimum year. optimum its in delivered to be option an to time aim we and benefit, most the realises that delivery of year optimum an has option each best value for consumers. Consequently, the achieve will right balance this Getting late. too by investing costs constraint high potentially incur nor early, too invest to unnecessarily We want don’t options. of timing optimal the we’re considering when network and constraining it. the in investing between balance best the find to order in places right the in time right the at together to upgrade the transmission networks work TOs and SO The to constrain. need the without transferred be can power more that meaning network the of capability the raise also ‘options’ and although they cost money they as investments potential to these We refer new overhead lines and underground cables. creating as such network, the in invest should process when we’re assessing whether we is factor an important in our decision-making Assessment of these future constraint costs constraint costs begin to accumulate. these then regularly amounts by large network the constraining are we if money, and costs off the network by switching generation on and
24 Chapter two 25
Scenario D 2021 Scenario C 2020 Optimum of Delivery Year the risk between recommending the TOs to proceed a critical option so it may be delivered on its EISD or delaying it so it may be delivered closer itsto optimum year. As we are only interested in making investment we options, critical for recommendations utilise ‘single year regret’ analysis. As each recommended be either can option critical ‘proceed’to there or are ‘delay’, a number of For recommend. could we action of courses region same the in options critical two example, courses different possible four produce would of action as demonstrated 2.2. in Table the option missing its optimum Because year. the decision must be made this these year, critical These ‘critical’. considered are options options are entered into our single year least regret analysis where we ultimately decide the investment recommendation for this year. Scenario B 2019
Scenario A 2019 EISD 2019
Critical Option In the above example, the earliest year that the option can be delivered The is 2019. optimum year of delivery varies across the scenarios, but for Scenarios A and B it’s option. critical a is this therefore 2019 also recommendation right the scenarios, those For would be for the proceed TOs to this option maintainto for However, its EISD of 2019. scenarios C and D the right recommendation would be not to proceed with this option and allow its EISD slip make to back To 2020. to a recommendation the to TOs, we must analyse the potential regretof making one recommendation and not the other. Example of a critical option’s optimum years of delivery Example of a critical option’s Table 2.1 Table The uncertainty of the future means that the optimum year of delivery for an option will likely not be the same for each of the energy understand must we Therefore scenarios. 2.3.3 least year Single regret analysis If an optimum option’s year of delivery is later than its EISD, then no decision on whether whether on decision no then EISD, its than proceedto with the option needs be to made ifyet. However, an optimumoption’s year is the same year as its EISD then the decision cannot be delayed any longer without risking 2017 – January 2016/17 Assessment Options Network Chapter two Methodology the option brings over its lifetime can be be can lifetime its over brings option the benefit the Therefore network. to the brings it constraint costs due to the additional capability in savings to see begin will we complete, is implementation. Once the relevant project associated with their construction or acost have will options investment All Economic regret 2.3.4 Network OptionsAssessment2016/17 –January2017 of economic regret. economic of concept the utilise we to risk, exposure and investment of level the to balance order In Possible coursesofactionfortwocriticaloptionsinaregion Table 2.2 Example ofthecosts(investmentand savings)eachoptionprovides Table 2.3 constraint costs constraint in reduction Consequent cost Initial investment ofCourse action 4 ofCourse action 3 ofCourse action 2 ofCourse action 1 Regret benefit Gross accordingly. This means that an option that that option an that means This accordingly. recommendations for an option may adapt As our energy landscape is changing, our EISD. its maintain and year by one forward progressed be can option an so amount right the just to TOs invest to the to recommend us allows analysis regret least year Single
£70m £45m 1 Option - £30m - £75m -
Delay both Options A and B Aand Options both Delay Proceed Option B but delay Option A Proceed Option A but delay Option B B Aand Options both Proceed £0m £40m + £130m 2 Option - £90m and benefits of three example options. example three of benefits and The table below demonstrates the costs regret. of concept the explains it however year single than regret to lifetime closer is in constraint costs. The following description of implementation and the consequent savings cost the between difference the as viewed the consumer. its planned completion date remains best for that to ensure year each revaluated is project ongoing an that is analysis regret least year single the of robustness The versa. vice and year this delayed to be recommended be may year last to proceed recommended we
£15m £75m 3 Option £25m + - £50m
26 Chapter two 27
Option 3 £15m £45m £0m £45m £45m £0m £185m Option 2 £0m £185m £100m analysis shows that Option 3 minimises regret across all four scenarios, as regret will be no more than million. £45 This approach provides a more stable and robust decision against the worst regret we could potentially incur option. that selecting by uncertainties, minimises and of range the exposure significant to regret. The same option won’t always deliver the the deliver always won’t option same The same value across every scenario, so it will have more regret in some scenarios and less in others. As a result, the best option for one scenario might not be the best option for another scenario. regret results 2.3’s Table were for just one scenario.cannot We predict the future, so we analyse an regret option’s across all four credible scenarios and note However, asHowever, we face an uncertain future we must consider the regretof our investments across each of the four energy scenarios.
£10m £70m Option 1 £70m £0m £20m
Scenario A Scenario B Scenario C Scenario D Regret Worst regret Worst Example of least regret analysis with option 3 having the least regret Example of least regret analysis with option 3 Table 2.4 Table The preferred option is selected based upon based selected is option preferred The regret. worst smallest the has option which In the above example, each scenario has 2 Option choice. worst a and choice best a may be the best choice for Scenarios A and butD, would be a much poorer choice under either of the other two scenarios. Least regret In economic analysis, an ’regret‘ option’s is defined as the difference in benefit for that option against the benefit of the best option. Therefore the best option will have regret a of zero, and the other options will have different levels of regret depending how they compare the to best option. In table Option 2.3, 2 is the best option, so there is no regret in choosing it. If we were select to Option3 we would see a cost saving of £25 million which is almost as good, but we would regret the is which 2 Option select didn’t we as decision option the choosing Clearly, better. million £15 with least regret makes economic sense. 2017 – January 2016/17 Assessment Options Network Chapter two Methodology Chapter 2 of ETYS 2of Chapter energy scenarios that we described in future the all account into year, taking next the for action of course best the on decide NOA the of analysis cost–benefit full the in factor important an are which constraints, of costs econometric analysis work. It forecasts the 2016/17 from it using for We began Consulting. Management Pöyry from BID3, tool, economic anew 2016 purchased we March In costs. these to determine (ELSI) we’ve used the Illustrator Scenario Electricity consumers of the different options. Historically, to benefits the establish and to analyse tool assessment costs aconstraint We use Economic tools 2.3.5 Network OptionsAssessment2016/17 –January2017 BID3 toolinputs Figure 2.2 construction cost) and uplift (boundary capability solutions Transmission Scenarios Future Energy EISD . We use this information to help us us to help information this . We use
2016. Economic analysis modelling BID3 constraint n n n Input data Forecast constraint prices. capabilities. Existing network/boundary Physical constraints.
to the minimum. flexibility this with associated cost the keeping investment decision-making, while also our in flexible to be us allow approach this respond to market or policy-driven changes, is still the best solution. So, when we strategy preferred the that sure to make year every results analysis and assumptions data, our revisit –we time over changes analysis cost–benefit our in use we information the so The future energy landscape is uncertain, configurationand benchmarking. BID3 work, our to review appointed were and Dr Iain Staffell, Imperial College London) Strathclyde of University Bell, Keith (Professor reviewers independent two and ELSI against the model has been extensively benchmarked to BID3, transition To asuccessful ensure lifetime costs with strategies transmission of Suite
28 Chapter two 29
– BID3’s other – BID3’s input data , which provides further information further information provides which , webpage. nationalgrid. com/noa Assumptions on why we selectedBID3, what we will use it for and more detail on the inputs BID3. to takes account of fuel cost forecasts, plant interconnected in prices and availabilities states. member European If you want know to more about BID3, there are a number of resources available on our website. A copy of the independent reviewers’ report is available, as well as our Long Term Modelling Constraint Network and Market Report main the at available are reports The NOA
– BID3 assesses – these were calculated calculated were these – using a separate power system analysis package. BID3 is the tool for calculating the market driven flow across the boundaries Figure 2.2 shows the various inputs to BID3. BID3. to inputs various the shows 2.2 Figure The inputs fall broadly into three categories: their and capabilities boundary Existing development future and takes capabilities as an input. The input capability in increase the includes BID3 to that the option provides, its capital cost and the EISD. Scenarios Energy Future against reinforcements network for options all Scenarios. Energy Future detailed the of each The resulting analysis takes us up 2036 to (the values from are 2037 extrapolated from 2036 forecasts so we can estimate full costs). lifetime 2017 – January 2016/17 Assessment Options Network Chapter two Methodology 2009/10in prices: criteria shown below. Once again, all costs are the of all to meet needs Scotland in option An 2009/10 in prices: are costs All SWW. as considered to be below needs to meet at least one of the criteria Wales and England in option An option. an such for case needs the develop who TOs, by the led are SWW SWW. to as referred criteria shown below, then this option is the of one satisfies that infrastructure large involves it but recommended is option an If options. recommended our forward put and options, potential of benefits and costs We use the NOA the We use How the NOA 2.4 Network OptionsAssessment2016/17 –January2017 provision of the TO’s price control settlement. other any under recovered be cannot Costs benefits. system wider or (orboundary capability sub-boundary) The output will deliver additional cross- £100 million for SPT. and Transmission SHE for million £50 than more of costs delivery total has option The scenarios, but would require consents. most in required not is and customer, one by only supported is £100 million, than less of cost aforecast has option The in most scenarios. required not is and customer, one by only £100 million and £500 million, is supported between of cost aforecast has option The than £500 million. more of cost aforecast has option The process to look at the the at to look process connects to the SWW process to connects the SWW
DownloadAsset.aspx?id=8589936185 www2.nationalgrid.com/WorkArea/ Options Assessment >Network Energy of >Future information) (more Information >Industry Sites > UK www2.nationalgrid.com methodology: to the alink is Below needs case submissions on our website. SWW TO-led into input for process SO the We have published our methodology for funding. SWW’s the to justify analysis detailed the to pursue TO needs the sooner the is date this closer The building. to start option is needed in service, determines when the which at date the with combined This, option. the to deliver taken time the is factor important Another formula. funding SWW the trigger they whether and factors,on certain including the forecast costs depending projects SWW for work case needs the economic analysis. The TO initiates the TO with the supports SO the but projects, SWW for cases needs developing on leads TO relevant the to that note It’s important
30
Chapter two 31
The Joint Regulators Group on behalf on Group Regulators Joint The competition and economic UK’s the of discounting a recommend regulators costs all discounts that approach calculated as costs financing (including based on a weighted average cost of capital and or WACC) benefits at rate This (STPR). is known as the for used is and approach Spackman reinforcements. our all HM Treasury’s social time preference We mayWe vary the process where modelling the base network is not straightforward. case, by case assessed, are variations Such with Ofgem.
cost–benefit analysisexamines the economic benefit of a range of reinforcement options their across network base the against lifetimes. The base is usually nothing’ ‘do or minimum’ ‘do and has no associated capital costs. Constraint costs are forecast for the base and eachnetwork option across scenarios.all constraint of value present the calculate We savings compared the to base for each subtracted then are These solution. network from the present value (PV) of capital network each with associated expenditure option, giving a net present value (NPV) for each of the network options. Taking these NPVs, we use lifetime least regret analysis determineto a preferred network option and an optimal delivery The year. results changing how determine to analysed are savings constraint and costs capital project conclusions. affect the would When an option is deemed be to SWW, 2.4.1 Summary SWW of analysis economic methodology 2017 – January 2016/17 Assessment Options Network Chapter two Methodology analysis for these two chapters is done in in done is chapters two these for analysis The markets. European and GB between the future optimum interconnection capacity describes analysis 6–Interconnection Chapter and consumers, GB for benefit maximum the providing on based reinforcements, SO’s recommended options for onshore Investment recommendations explains the and European interconnection. Chapter 5 – future of the electricity transmission networks NOA the In NOA between Interaction 2.5 Network OptionsAssessment2016/17 –January2017 , the SO sets out its vision for the the for vision its out sets SO , the results and FES and results Interconnection analysis. interconnection analysis in Chapter 6 – We’ve described the methodology for 2017/18 for assumptions ETYS credible to the contribute therefore will and 2017our FES influence will results of sets Both another. one upon dependent not are and assumptions credible from derived be can they so this to do other. It’sthe important drive not does results of set one so parallel, and NOA and analysis analysis .
32 Chapter two 33
for projects where the has TO started the Western Isles. Western Isles. Shetland Isles. Orkney NOA SWW Needs Case process, even though they boundary capability. provide won’t The following projects connect to the Scottish islands are in this category: project Connection Coast West North The is driven a customer. by We willWe include a summary of results in the
for another reason, such as links to the Scottish islands that trigger the SWW category) options that provide benefits, such as minimum, summer the over control voltage boundary no capabilitybut improvement (this is an area where we would welcome feedback) your inspection, by where, options of analysis the costs for the expected benefits would prohibitive be options that are more than twenty years in the future, referred as to long-term options. conceptual (unless they are specifically included projects with no boundary benefit While this report looks at options that could help meet major NETS reinforcement needs, include: doesn’t it 2.6.1 Excluded options 2.6 Other options 2017 – January 2016/17 Assessment Options Network Chapter two Methodology and cost. Development of reinforcement in in reinforcement of Development cost. and benefit for assesses SO the which comparison, and analysis for TOs by the provided options of range awide receives SO the this, For consumers. for value best the to deliver develop their electricity transmission networks and evolve to constantly able are TOs the which through strategy along-term provides process This years. twenty next the over options for dates delivery optimum year, and investment its recommended options for the upcoming NOA the Through options conceptual Long-term 2.6.2 Network OptionsAssessment2016/17 –January2017 process, the SO states states SO the process, the long-term future network. conceptualised reinforcements to support more with SO the provide also TOs the analysis, cost–benefit our in reinforcements eventual long-term these to represent order In unknown. are future the in far so reinforcements although the designs and costs for such years, twenty these after long continue will that process acontinuous be will network the
34
Chapter three 35 36
three Chapter Chapter 2017 – January 2016/17 Assessment Options Network Boundary descriptions Chapter three ETYS GBboundaries Figure 3.1 ETYS year’s this in description fuller You’lla NETS. find the on boundaries to the This section provides a introduction short Introduction 3.1 descriptions Boundary Network OptionsAssessment2016/17 –January2017 B1 B1 B3b B2 a B4 B5 B3 NW4 b Ardmor SW1 Harris SC1 NW3 To SW1 B6 B1 B8 B10 e Ireland Stornowa NW2 B7 Dunvegan 2 Broadfor To B9 y NorthernIreland B1 d NW1 B16 1 Carradal Indian Queens e B13
Pembroke Port Deani Nant Inveraray T Quoich aynuil Ann Crossai Grudie Bridg Cruachan Dunoo e Caennacro t Culligran Hunterston Auchencrosh Whistlefiel Clacha Fort Willia g Corriemoilli n B0 Hunterston Aigas Saltcoat Arecleoch Spango Dalmally Va North e Meadowhead n lley Luichart c d s Hunterston Glenluc m Kinlochleven Kilmorac Stewar Newton Maybol East Strathleven Fasnakyl e Markhill Devol Kilwinning Hadyar Mossford Moor Sloy Cassle Auchenwynd Morriso Glen Kilgallioc Ay Swansea Nort Invergarry Wylfa Inverarnan Landulph e Neilsto Erskine e Beaul r Cashli Kilmarnock t d Helensburg To k Baglan Ba wn Rannoch Alverdiscott Fort e Orrin y n Tu n Killin B1 Glenlee y Kilmarnoc Whitelee Extn h Coylto e South mmel Bridge Glendoe Augustus Busby To Lochay TRANSMISSION SCOTTISH HYDRO-ELECTRI Windyhill Whitelee New Cumnoc h Foyers Shi ngland Pentir Dingwal h y Langage Ffestiniog n Inverness n Lambhill Dinorwig Margam Strathaven 3 Kendoo Finlarig Carsfad Earlstoun Errocht Errocht Bonnybridg k Lairg Sout Kilbride East Gwynt yMo Clydes Mil Tr To Coalbur l h St. Fillans Denny Knocknagael Pyl awsfynydd Cumbernal Alness Ireland Rhyl Flats Robin Rig Stirling Easterhouse Wishaw Elvanfoo k y y n Coatbridge Bodelwydda Harestanes e Wa B7 Tu l W Newarthil Dounrea mme e n lney I&II Devonside est ofDuddon Errochty PowerStatio Aberthaw Abham Upper Boat d Bainsford r Dumfrie Linnmil Nairn t Mo g l Alpha Steel Black Law Longanne Garten Boat of Bror Dunbeat Kincardine a Grangemout ff y Bathgat n l at Black LawExtension Burbo Bank SP Livingsto Broxbur l s a Hinkley Poin Clyde (North Ormonde Cluni Exeter C Rassau Dunfemlin TRANSMISSION e Clyde (South) Ecclefecha North Hoyle h Cardif n t n Deesid East Te Burghmuir Chapelcross Cilfynyd e Gorgie lford Rd Capenhurst Currie Charleston Inverkeithin e h Thurso Barrow Mybster ) Uskmouth f Ta Blackhilloc Tr Elgin n Mossmorra Glenrothe e W Axminster . t Shrubhil Kaimes emorfa unton Whitehouse Glenniston n d estfield Imperial Dunlaw Extension Connah Park Gretna Smeaton Portobelllo Kirkby g Te Stanah Glenagne Redhouse l Legac aling LT Rocksavage Cupar L Cockenzi k Whitson s Leven yndhurst D Rainhil ’s n Bridgwate Quay Harker y Shrewsbury Heysha W Farm Seaban s Dudhope Ta ashway Crystal Ri Keith l Dudhope Penwortham Chickerell e Hawic Middleton Fallago rland Frodsham Galashiels Kintore Quernmor Carrington r South Manchester m Dunbar Milton ofCraigie Kearsle k g Hutto k Ironbridge Bishops Wo Fiddler Ferry n Arbroath Moray Firth y Iron Craigiebuckler Padiha e Wa Penn Wo Rochdale s Macduff Eccles To Strichen Ocker Hill lham Acton B1 odhill Berwick rness od Daine Rugeley Dyce Whitegat Fiddes m Mannington Bredbur Fourstones Melksham Macclesfiel s Stalybridge Bushbur Kitwel Persley 7 Stella W Cellarhea Clayhill e Willenhal Redmos Willowdal Marshall Meadows Fraserburgh Spennymoo y Feckenha Minety Oldbury Firth ofForth Stocksbridge l Bradford W Winco Bank y Sheff Neepsen Nechells St. Fergus est s est d Elland Peterhead B1 s B1 Marchwoo l Jordanthorpe d B2a e ield City Bustlehol Norton m Chesterfield r Willington Te Berkswel Hams Hall d Kirkstal Knaresboroug mpleborough B0 Pitsmoor Nursling Grangetow a Fawley d m Ferrybridge Coventry Blyth Drakelow l B2 Saltholme T W l Grange Skelto South Shields ynemout Of est Boldon Stoke Bardolph ferto Hawthorne Pi Norton Lees W Melton Bramle n n Hartmoor h est East Claydo Aldwarke Botley W on Soar Ratclif T n Thurcroft a Hartlepool Staythorpe Enderby Brinsworth h Poppleton od Point Didco Fryston Monk Lackenby Cowley Eggborough y Culham Greystones fe Marnha Hig t Thorpe ood Mars Amersham Main Osbaldwick Lovedean . Figure 3.1 t h n Drax Te h esside m Patford Thornton Bridge W Fleet est W Leighton Keadby Laleham Buzzard W Burto est Cottam Killingholm Iver Grendon eybridge n B14 Wa North Saltend Creyke Beck B5 Ealin Willesde tford Sout Mill Hill B2 Sundon Bank Humber Socon Eaton e Chessington g St Johns h W ood Wymondle Bicker Fen B6 Rye House Elstre Brimsdown Wimbledon n Saltend Sout Spaldin Nort T ottenham Hedo Humber Refinery Grimsby W City Rd B4 h e Bolney Cross New g We y n We st Ham Bridge Sutton EC3 Rowdown Beddington stermost Roug Burwell Main
h Redbridg Hurs est Major GeneratingSitesIncludingPumpedStorage Hackne Barkin Cross Wa Pelham Wa We Humber Gatewa t Rampion st ltham g lpole Thurrock System Boundarie Interconnectors 132kV Circuit 220kV Circuit 275kV Circuit 400kV Circuit 132kV Substation 275 kVSubstations 400kV Substation e Hydro Generation Connected at275kV Connected at400k Littlebrook y Inner Dowsing EC1 East Northfleet Wa Braintre h L Ti rley Singlewel ynn lbury Ninfiel Lincs l e y Kingsnorth Rayleigh Main d Necton Grain Kemsley Race Bank Coryton Tr iton Knol s s s s SC2 Nort Canterbur Kentish Flats Dungeness Cleve Hill Gunfleet SandsI&II Bramford h Dogger Bank Sellindge l s s s B1 V y Sheringham Shoa B1 Norwich Main B10 1 Dudgeon for this year’s analysis. considered have we boundaries the all shows 5 B1 Hornsea Sizewel l Thanet London 5 Scroby sands l B12 Array SC2 SC1 Greater Gabbard500M East Greater Gabbard2ndpart To B8 France B7 Anglia a W B9 EC5 B7 B16 To Netherland EC5 s 36 Chapter three 37
Boundaries Boundaries affected radial radial radial radial B0 B0 B0 B0 B0 B1a B1, B1a B1, B1a B1, B1a B1, B1
can improve boundary capability, has been provided the by two Scottish transmission a combination In Grid. National and owners reinforcement might affectother boundaries. The following boundary information, which boundary information, following The relates potential to reinforcements that
Reinforcement title Reinforcement Dounreay to Orkney, Bay of Skaill subsea link link subsea Ronaldsay South Orkney, to Bay Gills link subsea Hoy South Orkney, to Dounreay Dounreay to Orkney, Bay of Skaill and Dounreay to Orkney, South Hoy subsea link subsea Hoy South circuit reconductoring circuit Augustus Fort at Beauly to Shin to Loch Buidhe double 132kV circuit reconductoring Beauly to Fyrish 275kV double circuit reconductoring and generation Beauly to Loch Buidhe 275kV double circuit reconductoring and generationreconfiguration connection double 275kV Dounreay to Buidhe Loch and Buidhe Loch to Beauly New Beauly to Loch Buidhe 275kV double circuit Reactive compensation Tummel at Melgarve and Tummel at compensation Reactive Reactive compensation at Tummel and Melgarve and inter-bus Transformers New Beauly to Kintore 400kV double circuit New Beauly to Blackhillock 400kV double circuit connection reconfiguration connection
Unique reference Unique DSNO GSNO DHNO D2NO BLR1 FBRE BLR2 BDRE BLN2 TURC TMRC B1RC BKNO BBNO Effective reinforcement options Table 3.1 Table The following section describes the NETS in NETS the describes section following The Scotland and Northern England. The onshore owned is Scotland in network transmission Transmission SP and Transmission SHE by but is operated National by Grid as SO. 3.2.1 Introduction 3.2 North 2017 – January 2016/17 Assessment Options Network Chapter three Boundary descriptions Boundary Network OptionsAssessment2016/17 –January2017 HPNO NOHW NOR3 NOR2 NOR1 LNRE HAEU WBQB WOSR WHTI E4DC TLNO E2DC DWNO WLTI ECU4 ECUP ECU2 RKEU NEEU BLQB Unique reference New east–west circuit between the north east and Lancashire and east north the between circuit east–west New circuit double 400kV toOsbaldwick Norton the of 55km uprate Thermal circuits of length full –reconductor circuit double 400kV toOsbaldwick Norton circuit 1400kV number toOsbaldwick 13.75km Norton of Reconductor circuit double 400kV toOsbaldwick 13.75km Norton of Reconductor circuit 400kV single toNorton Lackenby Reconductor Harker SuperGrid Transformer 6 replacement circuit toOfferton Boldon West in booster quad Install circuit toOfferton Boldon West on FACTS device Deploy Pit Hawthorn at circuit toHartlepool Boldon West of Turn-in Pit toHawthorn Peterhead from Link HVDC subsea Eastern AC reinforcement England East toNorth Torness Pit toHawthorn Torness from Link HVDC subsea Eastern reinforcement 400kV toWishaw Denny 275kV North substation toDenny in turn circuit 275kV toLongannet toLambhill Windyhill East Coast onshore 400kV reinforcement East Coast onshore 400kV incremental reinforcement East Coast onshore 275kV upgrade circuit to Kintore Rothienorman substation with reconductoring of the 275kV Rothienorman reinforcement network 275kV and 400kV east North from Knocknagael New 275kV phase shifting transformers at Blackhillock on the circuits Reinforcement title
B6, B7,B6, B7a, B8 B7 B7,B6, B7a B7 B7,B6, B7a B7 B6 B7 B6, B7 B6, B7,B6, B7a B7, B6, B5, B7a B1, B1a, B4, B2, B2a, B7,B6, B7a B7, B6, B5, B7a, B8 B6 B5, B4, B5 B1, B1a, B5 B2, B4, B1, B1a, B2, B4 B1, B1a, B5 B2, B4, B2a B2a B1 affected Boundaries 38 Chapter three 39 Boundaries Boundaries affected B7a B6, B7, B7 B6, B7 B6 B7a B7a B8 B7a, B6, B7, B8 B7a, B6, B7, and B9 B8 B7a, B6, B7, and B9 B8 B7a, B6, B7, B8 B7a, B7, B6, B7a B8, B9 B7, B8 B7a, B8 B8 B8 B8
Reinforcement title Reinforcement to 400kV New east–west circuit between the north east and Lancashire Lackenby to Thornton double circuit – uprate cable and thermal uprate Lackenby to Thornton double circuit – uprate cable section and Osbaldwick to Thornton 1 circuit thermal upgrade booster quad Drive Lister Uprate the Penwortham to Washway Farm to Kirkby 275kV double circuit reinforcement Yorkshire Central Install series reactors at Thornton Install series reactors at Thornton Reconductor Drax to Thornton double circuit Reconductor Garforth to Keadby Tee leg of the CreykeBeck to Keadby Drax to Eggborough 1 circuit – reconductor and replace cable section Generator circuit breaker replacement to allow Thornton to run two-way split West Burton to High Marnham circuit – complete gantry works to match Reconductor theKeadby to Cottam 400kV circuits scheme de-load fast Link HVDC Western Treuddyn to Connah’s Tee Quay reconductoring Treuddyn to Legacy Tee thermal upgrade overhead line sections line overhead sections reconductor Circuit Killingholme to rating circuit Unique reference Unique NPNO LTR1 LTR2 OTHW LDQB MRUP OENO THS1 THS2 TDRE GKRE DERE DREU WHRE KCRE WEOS TCRE TLH1 2017 – January 2016/17 Assessment Options Network Note that the unique reference code applies only to this year’s document. Chapter three The 275kV overhead line takes a direct route route adirect takes line 275kV overhead The Beauly. from north extending lines overhead double circuit and 132kV double circuit 275kV existing the across cuts boundary The sparse. relatively is transmission infrastructure north of Beauly Sutherland and Orkney. The existing Beauly, Highland, comprising north Caithness, of north area the separates B0 Boundary Geographic representationofboundaryB0 Figure B0.1 Transmission SHE North –Upper B0 Boundary 3.2.2 descriptions Boundary Network OptionsAssessment2016/17 –January2017 Ardmor Harris e
Stornoway Dunvegan Deanie Grudie Bridge Culligran Corriemoillie B0 Aigas Luichart Kilmorack Fasnakyl Mossford Cassley Beaul e Orrin y Shi Dingwall
n Inverness Lairg Knocknagael Alness Dounreay Nairn high transfers across the B0 boundary. B0 the across transfers high Thurso. High renewables output causes from link subsea a33kV via connected is Orkney Thurso. and Mybster Dunbeath, grid supply points at Alness, Shin, Brora, along the east coast and the serves local route alonger takes line 132kV overhead the while to Dounreay, Beauly from north Bror Dunbeat a h Thurso Mybster Blackhillock Elgin Keith Kintor e Moray Firth Macduf Strichen Dyce f Persley Fraserburgh St. Fergus Peterhead B0
40 Chapter three 41 e Peterhead St. Fergus Firth of Forth Fraserburgh Redmoss Willowdal Clayhills Persley f Fiddes Dyce e oodhill Strichen Macduf W Craigiebuckler Arbroath B1 e Milton of Craigi Kintor rland Dudhope Keith Ta Dudhope g yndhurst Leven L Cupar ealin Glenagnes T n estfield W Glenrothes n Elgi Blackhillock Charleston e Burghmuir C Cluni n Boat of Garte l Nairn Errochty Power Statio Devonside mme Tu Alness Knocknagael St. Fillans to Blackhillock, the 275/132kV interface at Keith Keith at interface 275/132kV the Blackhillock, to south running circuit double 275/400kV the and output renewables High Augustus. Fort from causes high transfers across this boundary. Errochty Errochty s Finlarig Inverness Dingwall Foyer SCOTTISH HYDRO-ELECTRI TRANSMISSION Lochay Augustus Glendoe mmel Bridge y Killin
Tu d Orrin e Fort Rannoch Cashlie Beaul Inverarnan Invergarry Glen Morrison
Sloy Mossfor Fasnakyl Kilmorack Kinlochleven
m
Luichart n Dalmally Aigas Corriemoillie Fort Willia Clachan Culligra Caennacroc Cruachan Grudie Bridge aynuilt Quoich T Inveraray Nant Deanie Broadford Dunvegan e
Ardmor B1 from the southern and eastern regions. regions. eastern and southern the from double 275kV the boundary crosses The Knocknagael from eastwards running circuit Boundary B1 runs from the Moray coast coast Moray the from runs Boundary B1 near Macduff the to west coast near Oban, separating the North West of Scotland Figure B1.1 3.2.3 Boundary – North SHE Transmission B1 West of boundary B1 Geographic representation 2017 – January 2016/17 Assessment Options Network Chapter three B1a to Peterhead and Kintore and the 275/400kV 275/400kV the and Kintore and to Peterhead double circuit running eastwards from Keith 275kV another and route adirect on to Kintore circuit running eastwards from Blackhillock The crosses boundary the 275kV double from the southern and eastern regions. Scotland of West North the separating Oban, near coast west to the Macduff near B1aBoundary runs from the Moray coast Geographic representationofboundaryB1a Figure B1a.1 B1aBoundary West 1a –North Transmission SHE 3.2.4 descriptions Boundary Network OptionsAssessment2016/17 –January2017 Ardmor
e Dunvegan Broadfor d Deani Nant Inveraray T Quoich aynuilt Grudie Bridge Cruachan e Caennacroc Culligra Clachan Fort William Corriemoillie Aigas Dalmally n
Luichart
Kinlochleven Kilmorack Fasnakyl
Mossfor Sloy Morrison Glen Invergarry Inverarnan Beaul
Cashlie Rannoch Fort e Orrin d Tu Killin y mmel Bridge Glendoe Augustus Lochay TRANSMISSION SCOTTISH HYDRO-ELECTRI Foyers Dingwal Inverness Finlarig Errocht Errocht for transmission reinforcement across B1a. requirement B1a B1 the and drive boundaries and Kintore. Additional generation between the critical circuits between Blackhillock consider to 2016, specifically November in ETYS in B1a introduced was high transfers across this boundary. Boundary Augustus. High renewables output causes double circuit running south from Fort l St. Fillans Knocknagael Alness y y Tu mme Devonside Errochty PowerStatio Nairn l Garte Boat of n Cluni C Burghmuir e Charleston Blackhillock Elgin n Glenrothes W estfield T Glenagnes ealing Cupar L Leven yndhurst Dudhope Ta Keith Dudhope rland Kintore Milton ofCraigi Arbroat Craigiebuckler W Macduf Strichen 2016, published oodhill h e Dyce Fiddes B1a f Persley Clayhills Redmoss Willowdal Fraserburgh Firth ofForth St. Fergus Peterhead e
42 Chapter three 43 B2
e Firth of Forth Marshall Meadows Willowdal Redmoss Clayhills Persley Fiddes e h rness Berwick oodhill To Eccles W Craigiebuckler Arbroat e g Milton of Craigi Dunbar Kintor rland Fallago Dudhope Crystal Ri Ta Dudhope g n D yndhurst Leven L Cockenzie Cupar LT Redhouse ealin Glenagnes T Portobelllo Smeaton r Dunlaw Extension estfield Glenniston Whitehouse Kaimes Shrubhill . W Glenrothes Mossmorra n e Inverkeithing Charleston Currie lford Rd Gorgie e Burghmui Te n TRANSMISSION Dunfemlin C Cluni n Broxbur Livingston SP Black Law Extension Bathgate Grangemouth Kincardine Boat of Garte Black Law Longannet l Linnmill Bainsford d circuit overhead line running south from Fort Augustus. As a result it crosses all the main the from routes north–south transmission North of Scotland. High renewables output causes high transfers across this boundary. Errochty Power Statio Devonside mme Newarthill Tu Coatbridge y y Wishaw Easterhouse Stirling Cumbernal Denny St. Fillans h Clydes Mill East Kilbride Sout Bonnybridge Errocht Errocht Finlarig Strathaven Lambhill Foyers Whitelee Windyhill TRANSMISSION SCOTTISH HYDRO-ELECTRI Lochay Busby Augustus Glendoe mmel Bridge Whitelee Extn Killin Tu n Fort Rannoch wn To Helensburgh Kilmarnock Cashlie Erskine Neilsto Inverarnan Invergarry Glen Morrison Sloy Moor Kilwinning Devol Strathleven East Kinlochleven Hunterston lley Meadowhead North Va Dalmally Spango Saltcoats Hunterston Fort William Whistlefield Clachan Hunterston Caennacroc Dunoon Cruachan Crossaig Ann aynuilt Quoich T Inveraray Nant Port d Broadfor
B2 Boundary B2 cuts across the Scottish between coast east the from mainland Aberdeen and Dundee nearto Oban on the west coast. The boundary cuts across the two double275kV circuits single and a 132kV circuit in the east as well as the double 275/400kV Figure B2.1 3.2.5 Boundary – North B2 SHE South Transmission to of boundary B2 Geographic representation 2017 – January 2016/17 Assessment Options Network Chapter three towards Rothienorman. Peterhead power power Peterhead Rothienorman. towards towards Rothienorman and Blackhillock Kintore Persley, via to Kintore Peterhead from lines overhead circuit 275kV double the across cuts boundary The converge. Kintore and Peterhead Keith, from lines overhead the where Rothienorman and Deer New Peterhead, B2aBoundary is a enclosing local boundary Geographic andsingle-linerepresentationofboundaryB2a Figure B2a.1 B2a –Peterhead Boundary 3.2.6 descriptions Boundary Network OptionsAssessment2016/17 –January2017 Keith Kintore Moray Firth W Macduf Strichen oodhill Dyce f
Persley Willowdal Fraserburgh B2 St. Fergus Peterhead e a B2 a KI NT OR E FETTERESSO network in this area. this in network and other generation connected to the 132kV this to accommodate 275kV circuits existing the on capacity limited is There area. this in Interconnector are contracted to connect windfarm and theOffshore Connect North future developments such as Moray addition, In area. this in connected is station TA RL TEAL AN D IN PER G SL EY CR FI BR DDE AI EC PE GI HI S TE EB NG RH UC RI EAD KL D ER ST MOBIL . FERGUS GRANGE PETERHEAD ST . FERGUSGAS AR STRICHEN BR MI OA LT FRASERBURG ON TH OF CR AI H GI
E B2a B2a 44 Chapter three t 45 B4 h n Hartmoor Hawthorne Pi ferto est Boldon Of ynemout South Shields W T Blyth est Firth of Forth Marshall Meadows Stella W Fourstones e h rness Berwick To Eccles Arbroat ss g Milton of Craigi Dunbar GalashielGalashiel Fallago Hawick Dudhope Crystal Ri Dudhope Harker g n D yndhurst Leven Cockenzie L Cupar LT Redhouse ealin Glenagnes T Portobelllo Smeaton Gretna r Dunlaw Extension estfield Glenniston Whitehouse Kaimes Shrubhill . W Glenrothes Mossmorra ) e Inverkeithing Charleston Currie lford Rd Gorgie e Chapelcross Burghmui Te n Ecclefechan Clyde (South) TRANSMISSION Dunfemlin C Cluni Clyde (North s Broxbur Livingston SP Black Law Extension at Bathgate ff Grangemouth Kincardine Longannet Black Law Mo 220kV cables from Crossaig Hunterston, to line overhead circuit double 275/400kV the into Denny North interface andthe 275/132kV at Inverarnan. High renewables output causes high transfers across this boundary. Linnmill Dumfrie Bainsford d Devonside n Newarthill Harestanes Coatbridge Elvanfoot Wishaw Easterhouse Stirling Cumbernal Denny St. Fillans h Coalbur
Clydes Mill East Kilbride Sout Bonnybridge Earlstoun Carsfad Finlarig Kendoon Strathaven Lambhill n h ongland New Cumnock Whitelee Windyhill SCOTTISH HYDRO-ELECTRI TRANSMISSION Lochay T Busby mmel Bridge Sout Coylto Whitelee Extn Kilmarnock Glenlee Killin Tu n Rannoch wn To Helensburgh d Kilmarnock Cashlie r Erskine Neilsto e Inverarnan Ay Kilgallioch Auchenwynd Sloy Moor Hadyar Kilwinning Devol Markhill Strathleven East Maybol Newton Stewart Hunterston Glenluce lley Meadowhead North Va Dalmally Spango Arecleoch Saltcoats Hunterston Whistlefield Clachan Auchencrosh Hunterston Dunoon Cruachan Crossaig Ann aynuilt T Inveraray Nant Port Carradale Northern Ireland To
B4 of Tay in the eastof Tay near to the head of Loch Long in the west. The boundary is crossed 275kV by double circuits Kincardine to and Westfield in the east and double two 132kV circuits from Sloy Windyhill to in the west, as well as the Boundary B4 separates the transmission transmission the Boundary separates B4 network at the SP Transmission and SHE Transmission interface running from the Firth Figure B4.1 3.2.7 SP Transmission to Boundary B4– SHE Transmission of boundary B4 Geographic representation 2017 – January 2016/17 Assessment Options Network Chapter three between B4 and B5. and B4 between located are substations 275kV Westfield and Windyhill, Lambhill, Bonnybridge, Mossmorran from served groups demand the with together Cruachan, at station storage pumped The east. the in Forth of Firth to the west the in Clyde of Firth the from runs and system Transmission SP to the internal is B5 Boundary Geographic representationofboundaryB5 Figure B5.1 to Transmission South SP –North B5 Boundary 3.2.8 descriptions Boundary Network OptionsAssessment2016/17 –January2017 B5
To NorthernIreland Carradale Port Nant Inveraray T aynuilt Ann Crossaig Cruachan Dunoon Hunterston Auchencrosh Clachan Whistlefield Hunterston Saltcoats Arecleoch Spango Dalmally Va North Meadowhead lley Hunterston Glenluce Stewar Newton Maybol East Strathleven Markhill Devol Kilwinning Hadyar Moor Sloy Auchenwynd Kilgallioch Ay Inverarnan e Neilston Erskine r Cashlie Kilmarnock t d Helensburgh To wn Rannoch Tu Killin Glenlee Kilmarnock Whitelee Extn Coylto Sout mmel Bridge Busby T Lochay TRANSMISSION SCOTTISH HYDRO-ELECTRI Windyhill Whitelee New Cumnock ongland h n Lambhill Strathaven Kendoon Finlarig Carsfad Earlstoun Bonnybridge Sout Kilbride East Clydes Mill Coalbur h St. Fillans Denny Cumbernald Stirling Easterhouse Wishaw Elvanfoot Coatbridge Harestanes Newarthill n Devonside Bainsfor Dumfries Linnmill Mo Black Law Longannet Kincardine Grangemout ff Bathgat d at Black LawExtension Hunterston also cross the boundary. The 220kV cables between Crossaig and and Longannet 275kV substations in the east. Kincardine of each from one and west, the in routes: one from Windyhill 275kV substation three comprises boundary 275kV double circuit The existing transmission network across the SP Livingston Broxbur Clyde (North) Cluni C Dunfemlin TRANSMISSION e Clyde (South) Ecclefechan n Te Burghmuir Chapelcross e Gorgie lford Rd Curri Charleston Inverkeithin e h e Mossmorran Glenrothes W . Shrubhill Kaimes Whitehouse Glenniston estfield Dunlaw Extension Gretna Smeaton Portobelllo g T Glenagnes ealing Redhouse LT Cupar Cockenzi L Leven yndhurst D Harker Dudhope Crystal Ri Dudhope e Hawick Fallago Galashiel Dunbar Milton ofCraigie g s Arbroat Eccles To Berwick rness h Fourstones Stella W Marshall Meadows Firth ofForth est Blyth T W South Shields ynemouth Of est Boldon ferto Hawthorne Pi Hartmoor n t B5 46 Chapter three 47 B6 eesside T Greystones Lackenby od Point Hartlepool n T Hartmoor Hawthorne Pit ferto est Boldon Of ynemouth South Shields W T Saltholme Blyth Grangetown n Norto est Spennymoor Marshall Meadows Stella W Fourstones rness Berwick To Eccles ss g GalashielGalashiel Fallago Hawick Crystal Ri Harker D LT significantly more installed generation capacity farms. wind from increasingly demand, than Peak power flow requirements are typically from north south to at times of high renewable north to south large while output generation power flows can occur during periods of low output. generation renewable Portobelllo Smeaton Gretna Dunlaw Extension Whitehouse Kaimes ) Currie Gorgie Chapelcross n Ecclefechan Clyde (South) TRANSMISSION Clyde (North Broxbur Livingston SP Black Law Extension at d Bathgate ff Black Law Mo Linnmill Dumfries Bainsfor n Newarthill Harestanes Coatbridge Elvanfoot Wishaw Easterhouse Robin Rigg Cumbernald h Coalbur Clydes Mill East Kilbride Sout Earlstoun Carsfad Kendoon Strathaven Lambhill n h ongland New Cumnock Whitelee Windyhill T Busby Sout Coylto Whitelee Extn Kilmarnock Glenlee Wigtown Bay wn To d Kilmarnock r Erskine Neilston e Ay Kilgallioch Auchenwynd Moor Hadyar Kilwinning Devol Markhill Strathleven East Maybol Newton Stewart Glenluce Hunterston s Meadowhead North Arecleoch Saltcoat Hunterston g Auchencrosh Hunterston Crossai e Carradal
Northern Ireland To B6 Boundary B6 separates the SP Transmission Transmission Electricity Grid National the and (NGET) systems. The existing transmission boundary primarily the across network consists of two double-circuit 400kV routes. There are also some limited capacity 132kV circuits across the boundary. The key 400kV routes are from Gretna Harker to and from Eccles Blyth/Stella to West. Scotland contains Figure B6.1 3.2.9 NGET to Boundary B6 – SP Transmission of boundary B6 Geographic representation 2017 – January 2016/17 Assessment Options Network Chapter three Net generation output from between the west. the in one and east the in two circuits: double 400kV by three characterised is It Teesside, cutting across Cumberland. B7Boundary bisects England south of Geographic representationofboundaryB7 Figure B7.1 B7 North –Upper Boundary 3.2.10 descriptions Boundary Network OptionsAssessment2016/17 –January2017 To B7 Ireland
Auchencrosh Arecleoch Glenluce Stewart Newton Kilgallioch T ongland Earlstoun To Ireland Robin Rigg Wa W lney I&II est ofDuddon Dumfrie Burbo Bank s Ormonde Ecclefechan Chapelcross Barrow Stanah Harker Heysham W Farm ashway
Penwortham Middleton Quernmor Kearsley Hutto
n Padiham e Rochdale Whitegate Fourstones Stella W Spennymoor Bradford W est est Elland Norto driven by renewables output in Scotland. in output by renewables driven to be B7 tend across exports to south north so small, is B7 boundaries and B6 Te Kirkstal Knaresborough mpleborough n Grangetown Ferrybridge l Saltholme T W Grange Skelto South Shields ynemout Of est Boldon ferto Hawthorne Pit n Hartmoor T n Hartlepool h Poppleton od Point Fryston Monk Lackenby Eggborough Greystones Thorpe Mars Osbaldwick Drax T eesside h Thornton Keadby Killingholme North Saltend Creyke Beck Saltend Sout Hedon Humber Refiner W estermost Rough h Humber Gatewa y y T riton Knol l
Hornsea
B7 48 Chapter three a 49 B7
Hornsea Dudgeon Sheringham Shoal l riton Knol T Race Bank Lincs ynn L Inner Dowsing y Humber Gateway est h estermost Rough W Grimsby W Humber Refiner Hedon Saltend Sout Bicker Fen h Humber Bank Sout Creyke Beck Saltend North m n Killingholme Cotta est Burto W Keadby Thornton h Drax Osbaldwick Mars Thorpe High Marnham Eggborough n Lackenby Monk Fryston Poppleton Brinsworth Staythorpe Thurcroft Aldwarke est Melto W Norton Lees Stoke Bardolph Skelton Grange l Ferrybridge Grangetown Pitsmoor B7a is a modifiedB7a versionB7 of in which the west side is brought south below to Penwortham. This move puts the group of generation around Heysham north of the of monitoring closer boundary allows and the circuit heading south from Penwortham. mpleborough Knaresborough Kirkstal Te Chesterfield field City Jordanthorpe Elland est Neepsend Shef Winco Bank W Bradford Stocksbridge y Cellarhead Stalybridge Macclesfield Bredbur Whitegate Daines s Rochdale e Padiham n Ferry
Fiddler Hutto
Kearsley South Manchester Carrington Quernmor Frodsham Middleton Penwortham ashway Farm W Heysham Quay Rainhill Rocksavage Legacy Stanah Kirkby Connah’s Barrow Capenhurst Deeside North Hoyle Ormonde Burbo Bank a est of Duddon lney I & II W Wa Bodelwyddan Rhyl Flats Ireland g To B7 Gwynt y Mor Dinorwig Ffestinio Pentir Wylfa
Ireland To Boundary B7a bisects England south of of south England bisects Boundary B7a Teesside, across Lancashire and into the Mersey Ring area. It is characterised by three 400kV double circuits (two in the east, one in the west) and one circuit. 275kV Figure B7a.1 of boundary B7a Geographic representation 3.2.11 – Upper North Boundary B7a 2017 – January 2016/17 Assessment Options Network Chapter three consisting of four 400kV circuits that export export that circuits 400kV four of consisting EC1Boundary is an enclosed local boundary Geographic andsingle-linerepresentationofboundaryEC1 Figure EC1.1 EC1 –Humber Boundary 3.2.12 descriptions Boundary Network OptionsAssessment2016/17 –January2017 Eggborough Thorpe Mars Drax h Keadby W Burto est Cotta Killingholme
n m North Saltend Sout Bank Humber h Saltend Sout Hedon Humber Refiner Grimsby W h est Humber Gatewa y EC1 y encloses an area of high generation. high of area an encloses boundary The substation. to Keadby west power EC1 50 Chapter three 51 Anglia B8 East l Scroby sands Sizewel Dudgeon Norwich Main Sheringham Shoal l Bramford riton Knol T Race Bank Necton Lincs ynn L e Inner Dowsing lpol y Humber Gateway Wa est h Burwell Main Sutton Bridge Grimsby W Humber Refiner Hedon North Spalding Saltend Sout Bicker Fen h Eaton Socon Humber Bank Sout m n Grendon Killingholme Cotta est Burto W Keadby h Drax t Mars Thorpe High Marnham fe Eggborough n Enderby Brinsworth Staythorpe Thurcrof Ratclif on Soar Aldwarke est Melto W Norton Lees crosses four major 400kV double circuits, with with circuits, double 400kV major four crosses two of these passing through the East Midlands and the other two passing through the West to connection 275kV limited a and Midlands, Yorkshire. South Stoke Bardolph l Drakelow Coventry Ferrybridge m Pitsmoor mpleborough Hams Hal Berkswell Te Willington Chesterfield Bustlehol field City y Jordanthorpe l Elland Nechells Neepsend Shef y Winco Bank Stocksbridge Oldbur Feckenham y Willenhal Cellarhead Kitwell Bushbur Stalybridge Macclesfield e Bredbur Whitegate Rugeley Daines ood Ocker Hill Rochdal Penn Ferry Fiddlers Bishops W Ironbridge Kearsley South Manchester Carrington Frodsham Penwortham ashway Farm W Shrewsbury Quay Rainhill Rocksavage Legacy Kirkby Connah’s Capenhurst Deeside North Hoyle Burbo Bank r Bodelwyddan Rhyl Flats Ireland g awsfynydd To Tr Gwynt y Mo Dinorwig Ffestinio Pentir Wylfa
Ireland To B8 The North Midlands to boundary B8 is one of the wider boundaries that intersects the centre of Great Britain, separating the northern Northern Scotland, including zones generation England and North Wales, from the Midlands and southern demand centres. The boundary Figure B8.1 3.2.13 Boundary B8North – Midlands to of boundary B8 Geographic representation 2017 – January 2016/17 Assessment Options Network Chapter three Midlands from the southern demand centres. demand southern the from Midlands the generation northern zones and the The Midlands to B9 South separates boundary Geographic representationofboundaryB9 Figure B9.1 –Midlands B9 to South Boundary 3.2.14 descriptions Boundary Network OptionsAssessment2016/17 –January2017 To Ireland B9
Wylfa Pentir Ffestinio Dinorwi Gwynt yMor Tr To awsfynydd g Ireland Rhyl Flats g Bodelwyddan Burbo Bank North Hoyle Deeside Capenhurst Connah’s Kirkby Legacy Rocksavage Rainhill Quay Shrewsbury W Farm ashway Penwortham Frodsham Carrington South Manchester Kearsley Ironbridge Fiddlers Bishops W Ferry Penn Rochdale Ocker Hill Daines Rugeley ood Whitegate Bredbur Macclesfield Stalybridge Bushbur Kitwell Cellarhead Willenhall y Feckenham Oldbur Stocksbridge Winco Bank y Shef Neepsend Nechells Elland Jordanthorpe y field City Bustlehol Chesterfield Willington Te Berkswel Hams Hal mpleborough Pitsmoor m Ferrybridge Coventry Drakelow l l Stoke Bardolph Norton Lees W including London. hubs, demand southern to the distance a long over north the from power transporting circuits, double 400kV major five crosses boundary The Melto est Aldwarke on Soar Ratclif Thurcroft Staythorpe Brinsworth Enderby n Eggborough fe Marnham High Thorpe Mars Drax h Keadby W Burto est Cotta Killingholme Grendon n m Sout Bank Humber Socon Eaton h Bicker Fen Saltend Sout Spalding North Hedon Humber Refiner Grimsby W Bridge Sutton Burwell Main h est Wa Humber Gateway y lpol Inner Dowsing e L ynn Lincs Necton Race Bank T riton Knol Bramford l Sheringham Shoal Norwich Main Dudgeon Sizewel Scroby sands l East Anglia B9 52 Chapter three 53
Boundaries Boundaries affected EC5 EC5 EC5 EC5 EC5 EC5 EC5 EC5 EC5 EC5 EC5 considered local, based on the generation generation the on based local, considered connected. currently demand and
Reinforcement title Reinforcement 225MVAr MSCs at Burwell Main Reconductor remainder of Bramford to Braintree to Rayleigh route circuit double Norwich to Bramford Reconductor A new 400kV double circuit between Bramford and Twinstead South east to East Anglia HVDC link Reconductor remainder of Coryton South to Tilbury circuit Reconductor remainder of Rayleigh to Tilbury circuit Main Rayleigh to Braintree to Bramford second formed newly Reconductor circuit (following Bramford to Twinstead new double circuit) (following circuit Pelham to Bramford second formed newly Reconductor Bramford to Twinstead new double circuit) Uprate non-conductor components of Bramford to Pelham double circuit(following Bramford to Twinstead new double circuit) Braintree to Bramford formed newly of components non-conductor Uprate double new Twinstead to Bramford (following circuit double Main Rayleigh to Main Rayleigh at circuit)
Unique reference Unique BMMS BRRE NBRE BTNO SGDC CTRE RTRE RBRE PRRE BPEU RMEU Table 3.2 Table Effective reinforcement options The East region includes the counties counties the includes region East The network in the area. This boundary is 3.3.1 Introduction of Norfolk and Suffolk. The transmission transmission The Suffolk. and Norfolk of transmission the covers boundary EC5 3.3 East 2017 – January 2016/17 Assessment Options Network Note that the unique reference code applies only to this year’s document. Chapter three the east. to directly lies that zone 3offshore Round wind projects, including the large East Anglia offshore of connection the for attractive are Anglia East around waters and coastline The towards London. power export mainly that circuits 400kV four crosses It Bramford. and Sizewell Norwich, at most of East Anglia with 400kV substations EC5Boundary is a enclosing local boundary Geographic andsingle-linerepresentationofboundaryEC5 Figure EC5.1 EC5 Anglia –East Boundary 3.3.2 descriptions Boundary Network OptionsAssessment2016/17 –January2017 Littlebrook Inner Dowsing Eas Northfleet Wa Braintre t L Ti rle Singlewel ynn lbury y Lincs l e Kingsnorth Rayleigh Main Necton Grain Kemsley Race Bank Coryton North Canterbury Kentish Flats Cleve Hill Gunfleet SandsI&II Bramford Sheringham Shoal Norwich Main Dudgeon
Sizewel Thanet London Scroby sands l Array Greater Gabbard500M East Greater Gabbard2ndpart Anglia W EC5 To Netherlands EC5
nuclear generation development. new for selected sites approved the of one is Sizewell at site generation nuclear existing The EC5 54 Chapter three 55 Boundaries Boundaries affected SC1 SC2, B15 SC1, SC2 SC1, SC2 SC2 SC1, SC2 SC1, SC1 SC1, B15 SC1, B13 SC1 SC1 B14e B14e B14e Europe is present on the south coast and influences power flows in the region by being able import to and export power with Europe. boundaries B13, includes region South The and SC1 SC2. B14,
Reinforcement title Reinforcement Bramley to Fleet circuits thermal uprating compensation reactive coast East South Bolney and Ninfield additional reactive compensation scheme switching protective compensation Reactive Lovedean to Ninfield thermal uprate coast south the and London South between route transmission 400kV New (there are three alternative designs for this option) Fleet to Lovedean reconductoring Kemsley to Littlebrook circuits uprating circuit double new Seabank to Point Hinkley Reconductor Hinkley Point to Taunton double circuit Alverdiscott to Taunton double circuit thermal uprating turn-in Wymondley boosters quad Wymondley diversion Ealing cable 275kV Wimbledon to Willesden
Unique reference Unique BFHW SCRC BNRC SEEU LNHW SCN1/SCN2/SCN3 FLRE KLRE HSNO THRE ATHW WYTI WYQB WEC1 Effective reinforcement options Table 3.3 Table The South region stretches from London London from stretches region South The across Devon to and Cornwall. It has a high concentrationof power demand and found demand the of much with generation, Thames the in generation and London in continental to Interconnection Estuary. 3.4.1 Introduction 3.4 South 2017 – January 2016/17 Assessment Options Network Note that the unique reference code applies only to this year’s document. Chapter three entering from the north can be heavily heavily be can north the from entering a small amount of generation. The circuits characterised by high local demand and B14Boundary encloses London and is Geographic andsingle-linerepresentationofboundaryB14 Figure B14.1 B14Boundary –London 3.4.2 descriptions Boundary Network OptionsAssessment2016/17 –January2017 W Fleet est W Leighton Laleham Buzzard Iver eybridge B14 Wa Ealin Willesden tford
Mill Hill Sundon Chessington g St Johns W Wy ood Rye House Elstree Brimsdown Wimbledon mondley To ttenham City Rd Cross Ne West Ham w Rowdown Beddington Redbridg Hurs Hackney Barking Cross Wa Pelham West t ltham Thurrock e Littlebrook East Northfleet Wa Braintre T rle Singlewel
ilbury y
l e to the continent. the European interconnectors export when stressed further are circuits The loaded during winter peak conditions. B14/B14e
56 Chapter three 57 France To SC1 Thanet y Sellindge Cleve Hill Dungeness Kentish Flats Canterbur North n Coryton Kemsley Grai Kingsnorth l y Ninfield n ilbur Singlewel T Northfleet East Littlebrook Thurrock st Rampio We Barking Hurst Beddington Rowdown st Ham We New Cross Bolney City Rd Wimbledon ood W St Johns g Chessington Willesden Ealin eybridge Iver Laleham est W Fleet W Lovedean ood y Botley W Bramle Fawley Nursling Interconnector activity significantly influences boundary power Crossing flow. the boundary are three 400kV double circuits with one in the east, one in the west and one midway between Bramley. and Fleet Marchwood Melksham Mannington Acton Iron Chickerell Seabank Bridgwater Whitson h emorfa Axminster aunton Tr T ff Uskmout East Cardi Exeter Hinkley Point Alpha Steel Abham Aberthaw e Pyl Margam Langage Alverdiscott Landulph
Indian Queens SC1 The south coast boundary runs SC1 parallel with the south coast of England between the Severn and Thames estuaries. times At of peak winter GB demand, the power flow is typically north south to across the boundary. Figure SC1.1 of boundary SC1 Geographic representation 3.4.3 Boundary Coast – South SC1 2017 – January 2016/17 Assessment Options Network Chapter three Lovedean. At times of peak winter GB demand, demand, GB winter peak of At times Lovedean. and Bolney between end west its at and Hill Cleve and Kemsley between route circuit double the cuts it end, east At its Sussex. and Kent in takes SC2 boundary coast south The Geographic andsingle-linerepresentationofboundarySC2 Figure SC2.1 Coast SC2 –South East Boundary 3.4.4 descriptions Boundary Network OptionsAssessment2016/17 –January2017 Didcot Cowley Culham Amersham Main Lovedean SC2 W Fleet est W Leighton Laleham Buzzar Iver eybridge d Wa Ealing Willesden tford Mill Hill Chessington St Johns W
ood Wymondley Rye House Elstre Brimsdown Wimbledon T ottenham City Rd e Bolney Cross New We st Ham Rowdown Beddington Redbridge Hurst Hackney Barking Cross Wa We Rampion st ltham Thurrock Littlebrook East Northfleet Wa Braintre Ti rle Singlewel lbury y Ninfield l e Kingsnorth Rayleigh Main Grai Kemsley Coryton n SC2 North Canterbury Kentish Flats Dungeness Cleve Hill Gunfleet SandsI&II Sellindge Thanet London Array SC2 boundary power flow. power boundary influences significantly activity Interconnector across the boundary. north to south typically is flow power the Greater Gabbard2ndpart To France To Netherlands
SC2 58 Chapter three 59 y Bramle g Fawley Nurslin Marchwood Melksham are the Hinkley Point Melksham to 400kV double circuit and the 400kV circuits from Fawley. and Nursling to Mannington Mannington Chickerell Bridgwater emorfa Axminster aunton Tr T ff East Cardi Exeter Hinkley Point Abham Aberthaw 3 Langage B1 Alverdiscott Landulph
3 B1 Indian Queens Wider boundary is defined B13 as the the below Britain, Great of tip southernmost Point encompassing Hinkley Estuary, Severn in thesouth west and stretching as far east as boundary circuits The crossing Mannington. Figure B13.1 representation of boundary B13 Geographic and single-line 3.4.5 West – South Boundary B13 2017 – January 2016/17 Assessment Options Network Chapter three Note that the unique reference code applies only to this year’s document. year’s tothis only applies code reference unique the that Note Effective reinforcementoptions Table 3.4 North for those as such related, closely are boundaries the of Some West. South the and on the system including Wales, the Midlands The West region covers the remaining boundaries Introduction 3.5.1 West 3.5 descriptions Boundary Network OptionsAssessment2016/17 –January2017 CIQB PWTI SEC1 HCC1 PTRE PTC2 PTC1 PTNO PBRE BCRE WPDC WPNO Unique reference
Quad booster installation at Cilfynydd North toSwansea turn-in circuit toWalham Pembroke Severn Tunnel 400kV cable circuit uprate upgrade cables) (Hinksey cables toWalham Cowley and toMinety Cowley line sections overhead remaining the –reconductor circuits toTrawsfynydd Pentir circuit toTrawsfynydd Pentir existing the on section line overhead an of reconductor and phase per core –second 2cables 1and toTrawsfynydd Pentir phase per core –single replacement 1cable toTrawsfynydd Pentir circuit second toTrawsfynydd Pentir and 2 circuits 1 Quay toConnah’s toBodelwyddan Pentir the of legs Pentir Reconductor 2circuits 1and Quay toConnah’s toBodelwyddan Pentir the of legs Quay Connah's the Reconductor Link HVDC Wales toSouth Wales North route circuit double second toPentir Wylfa Reinforcement title boundaries such as B17. Wales, but the region also covers large wider
SW1 SW1 SW1 SW1 NW2 NW2 NW2 NW2 NW2 NW2, NW3 SW1, NW3 NW2, NW1 affected Boundaries 60 Chapter three 61 B17 circuits but internally the circuits in and around 275kV. mostly are Birmingham
B17 Enclosing the West Midlands, boundary B17 is boundary B17 Midlands, West the Enclosing heavily dependent on importing power from the north because of insufficient local generation. Boundary is crossed B17 five by 400kV double Figure B17.1 representation of boundary B17 Geographic and single-line 3.5.2 Midlands West – Boundary B17 2017 – January 2016/17 Assessment Options Network Chapter three NW3 power station. Pentir pumped storage connects Dinorwig from spur cable double-circuit 400kV A short substations. Trawsfynydd and Pentir, Deeside connects that ring circuit a400kV comprises The onshore network in North Wales Geographic representationofNorthWales boundariesNW1,NW2andNW3 Figure NW.1 NW1,Boundary Wales NW2 NW3 and North 3.5.3 descriptions Boundary Network OptionsAssessment2016/17 –January2017 To NW2 Ireland NW1
Pembroke NW1 Swansea North Wylfa Baglan Bay Pentir Ffestinio Dinorwig Margam Gwynt yMo Tr To Pyl awsfynydd g Ireland Rhyl Flats Bodelwyddan e Wa W lney I&II est ofDuddon Aberthaw Upper Boat r Alpha Steel NW2 Burbo Bank Ormonde Rassau North Hoyle Cardi Deeside East Cilfynydd NW3 Capenhurst Barrow Uskmout ff three ‘NW’ are boundaries local boundaries. The area. this in capacity for factor limiting main the is which circuit, 400kV by asingle Snowdonia National Park and are connected the within are Trawsfynydd and Pentir Tr emorfa Imperia Connah’s Park Kirkby Stanah h Legacy Rocksavage Whitson l Rainhill Quay Shrewsbury Heysham W Farm Seabank ashway Penwortham Middleton Frodsham Quernmor Carrington South Manchester Kearsley Hutto Ironbridge Bishops W Fiddlers Ferry n Iron Padiham e Wa Penn Rochdal Ocker Hill lham Acton ood Daines Rugeley Whitegate e
62 Chapter three y 63 Minet
Melksham
cton lham nA Wa Iro Seabank Bridgwater l Whitson h Park Imperia emorfa t aunton Tr T f Uskmout Cilfynydd East Cardif Rassau Hinkley Poin Alpha Steel Upper Boat Aberthaw of new generation capacity are expected to by powered generators including connect, tidal. and gas wind, Boundary NW3 – Anglesey, Merionethshire and Caernarvonshire further capacity for provides Boundary NW3 those to addition in connections, generation is It NW2. and boundaries NW1 behind definedby a pair of 400kV double circuits from Pentir Deeside to and from Trawsfynydd theto Treuddyn Tee. Pyle Margam
Alverdiscott Baglan Bay Swansea North Pembroke
SW1 Boundary encloses SW1 South Wales and is considered a local boundary. Within the boundary are a number of thermal generators. Some of the older power stations are expected closeto in the future but significant amounts SW1 Figure SW1.1 Geographic representation of boundary SW1 3.5.4 Boundary Wales – South SW1 BoundaryNW1 – Anglesey 400kV double the crosses Boundary NW1 between Anglesey along runs that circuit Wylfa and Pentir substations. Pentir and Wylfa BoundaryNW2 – Anglesey and Caernarvonshire North Wales the bisects Boundary NW2 through crosses It Anglesey. to mainland close the Pentir the to Deeside 400kV double circuit and the Trawsfynydd 400kV single circuit. 2017 – January 2016/17 Assessment Options Network Chapter three Network OptionsAssessment2016/17 –January2017 64 Chapter four
65 66
Proposed options four Chapter Chapter 2017 – January 2016/17 Assessment Options Network Chapter four alongside the NOA comment and viewing for available is it and (OWW) Works Wider Offshore of assessment SO's the for methodology the drafted have we however identified: been have options offshore no year This risks. and costs higher rely on emerging technology and usually incur provide capability. boundary options Offshore can interconnect offshore generation and that options offshore provide also can SO the Depending on the status of offshore connections, reduced-build, and some background. or build is it whether option, the of status the included have we option each For SWW. are they butboundaries we’ve included them because particular benefiting than rather radial are The options for connecting the Scottish islands planning. of network part as capability NETS increase options chapterThis that could the reinforcement lists Introduction 4.1 optionsProposed Network OptionsAssessment2016/17 –January2017 methodology.
aspx?id=8589936186 /WorkArea/DownloadAsset. www2.nationalgrid.com Options Assessment >Network Energy of >Future information) (more Information >Industry Sites > UK www2.nationalgrid.com 66 Chapter four 67
MW.
MW and the MW subsea AC cable MW subsea AC cable MW subsea AC cable between Gills on the north Bay, east coast between Dounreay, on the north coast of south the at substation new a and Caithness, of Hoy on the Orkney Islands. cable Hoy to would be rated at 220 circuit double 132kV existing the Reconductor overhead line between Beauly, Shin and Loch a with construction) under (substation Buidhe existing the Replace conductor. rated higher phase shifting transformers at Beauly (PSTs) PSTs. capacity higher with substation 132kV circuit double 275kV existing the Reconductor overhead line between Beauly and Fyrish higher a with construction) under (substation rated conductor. Reconfigure generation (substation Buidhe Loch between connections release to Dounreay and construction) under the between circuits 275kV the on capacity substations. two between Dounreay, on the north coast of Caithness, and new a substation at Bay of Skaill on the west coast of the Orkney Islands. Install a 220kV 220 on substation new a and Caithness, of Install a 220kV 220 Install a 220kV subsea AC cable from Caithness, of coast north the on Dounreay, a newto substation at Bay of Skaill on the west coast of the Orkney Islands,and from Dounreay a new to substation at the south of Hoy on the Orkney Islands. The cable Bay to of Skaillwould be rated at 200 Install a 220kV 200 the on Ronaldsay South of coast east the Islands. Orkney FBRE Beauly to Fyrish 275kV double circuit generation and reconductoring reconfigurationconnection Scoping Status: B0 Boundary affected: BLR1 Beauly to Shin to Loch Buidhe 132kV reconductoring circuit double Scoping Status: B0 Boundary affected: Dounreay to Orkney, Bay of Skaill and Dounreay to Orkney, South Hoy linksubsea Optioneering Status: Radial Boundary affected: Dounreay to Orkney, South Hoy South Hoy Orkney, to Dounreay linksubsea Optioneering Status: Radial Boundary affected: Gills Bay to Orkney, South Ronaldsay linksubsea Optioneering Status: Radial Boundary affected: Dounreay to Orkney, Bay of Skaill linksubsea Optioneering Status: Radial Boundary affected: 4.2 and – Scotland North options Reinforcement of England of 2017 – January 2016/17 Assessment Options Network Chapter four Boundaries affected:Boundaries B1, B1a Status: Optioneering double circuit 400kV Kintore to Beauly New BKNO affected:Boundaries B1, B1a Status: Optioneering Transformers at Fort Augustus and Melgarve and inter-bus Reactive compensation at Tummel B1RC affected:Boundaries B1, B1a Status: Scoping and Melgarve Reactive compensation at Tummel TMRC affected:Boundaries B1, B1a Status: Optioneering Reactive compensation at Tummel TURC affected:Boundary B0 Status: Planning double circuit 275kV Buidhe Loch to Beauly New BLN2 affected:Boundary B0 Status: Scoping circuit reconductoring toBuidhe Dounreay 275kV double Loch and Buidhe Loch to Beauly BDRE affected:Boundary B0 Status: Scoping reconfiguration connection and generation double circuit reconductoring 275kV Buidhe Loch to Beauly BLR2 optionsProposed Network OptionsAssessment2016/17 –January2017
reactive compensation. reactive Tummel substation and install shunt at busbar a275kV double Establish Beauly. at transformers shifting phase two the and Shin and Beauly between decommission the 132kV double circuit line works, the of completion On line. new substation (under construction) onto the under construction) and transfer Fyrish (substation Buidhe Loch and Beauly between Construct a new 275kV double circuit Dounreay with a higher rated conductor. and Buidhe Loch between and Buidhe Loch and Beauly between line overhead circuit Reconductor the existing 275kV double 275kV circuits between the two substations. the on capacity to release Dounreay and generation connections between Loch Buidhe Reconfigure conductor. rated ahigher with Loch Buidhe (substation under construction) and Beauly between line overhead circuit Reconductor the existing 275kV double Beauly to Knocknagael. Beauly dismantle the 132kV double circuit line from the new 400kV double circuit has been built, Once Kintore. and Beauly between circuit substation and construct a new 400kV double Kintore at busbar double a400kV Establish inter-bus transformers at Augustus. Fort double busbar and install two 400/275kV compensation at on Melgarve the 132kV compensation. Install shunt reactive substation and install shunt reactive Establish a 275kV double busbar at Tummel double busbar. compensation at on Melgarve the 132kV compensation. Install shunt reactive substation and install shunt reactive Establish a 275kV double busbar at Tummel
68 Chapter four 69
The option would also re-profile theexisting Peterhead between line circuit double 275kV and Persley, and Persley and Kintore. Establish new substations 275kV at Alyth and Fiddes, re-profile 275kV thecircuits Alyth and Kincardine and Kintore, between uprate the circuits 275kV between Alyth, Tealing, Westfield and Longannet. Install two phase shifting transformers at Fiddes on the circuits275kV from Kintore Tealing to and the at compensation reactive shunt install Alyth substation. new Establish new 400kV substations at at 400kV substations new Establish Rothienorman and Peterhead and re- between circuits 275kV existing the insulate Peterhead Rothienorman, and Blackhillock and Rothienorman, and Rothienorman and operation. 400kV to substations Kintore Establish a new substation 275kV at Rothienorman and reconductor the double275kV circuit overhead line from Rothienorman Kintore to with a higher conductor. rated Construct a new 400kV double circuit circuit double 400kV new a Construct the Once Blackhillock. and Beauly between built, been has circuit double 400kV new from line circuit double 132kV the dismantle Beauly Knocknagael. to shifting phase 275kV new two Install transformers with bypass circuits at existing the on substation Blackhillock Knocknagael. from circuits 275kV
ECU2 upgrade 275kV onshore Coast East Optioneering Status: B2, B1a, B1, Boundaries affected: B4, B5 network reinforcement network Optioneering Status: B2a Boundary affected: RKEU substation withRothienorman reconductoring of the 275kV circuit Kintore to Rothienorman Optioneering Status: B2a Boundary affected: NEEU North 400kV east 275kV and BLQB BLQB shifting phase 275kV New Blackhillock at transformers BBNO New Beauly to Blackhillock 400kV circuit double Optioneering Status: B1 Boundary affected: on the circuits from Knocknagael Scoping Status: B1 Boundary affected: 2017 – January 2016/17 Assessment Options Network Chapter four Boundaries affected:Boundaries B4, B5, B6 Status: Design reinforcement Denny to Wishaw 400kV DWNO affected:Boundary B5 Status: Design 275kV substation North Denny to in turn circuit 275kV Windyhill to Lambhill to Longannet WLTI B5 B4, affected:Boundaries B1, B1a, B2, Status: Optioneering reinforcement 400kV onshore Coast East ECU4 B1, affected: B1a,Boundaries B2, B4 Status: Optioneering incremental reinforcement 400kV onshore Coast East ECUP optionsProposed Network OptionsAssessment2016/17 –January2017
enhanced rating.enhanced the cable sections at Longannet to match the uprate as well as Longannet and Westfield Tealing, between circuits the 275kV Re-profile Kincardine, Alyth, Kintore and Rothienorman. at 275/400kV transformers and Knocknagael at Blackhillock on the 275kV circuits from to 400kV. Install transformers phase shifting Kintore, Fetteresso, and Kincardine Alyth circuits Rothienorman, between Blackhillock, 275kV the re-insulating and Alyth and Kintore Rothienorman, at substations 400kV new east coast for 400kV operation by creating Upgrade the 275kV infrastructure on the Rothienorman. and Kintore Alyth, Kincardine, at 275/400kV transformers and Knocknagael from 275kV circuits the with bypass circuits at Blackhillock on operation. Install phase shifting transformers 400kV for Kincardine and Alyth Fetteresso, Blackhillock, Rothienorman, Kintore, Re-insulate the 275kV circuits between Coast 275kV Upgrade) for 400kV operation. substationAlyth (proposed under the East uprate and Kintore, and Rothienorman at 400kV. Establish new 400kV substations at to operate coast east the on route Rothienorman–Kintore–Alyth–Kincardine 275kV infrastructure along the Blackhillock– 275kV upgrade (ECU2) by upgrading the The option builds on the East Coast onshore at 275kV. at other the 400kV, at operate would route line overhead new the of side One belt. central double circuit route through the Scottish north-to-south afourth to establish sites associated reconfigure also would project The from Bonnybridge towards Newarthill. line overhead circuit double 400kV A new 275kV circuit. to Longannet North Denny asecond and toWindyhill to Lambhill Denny circuit North a275kV create would This substation. 275kV North Denny into 275kV circuit to Longannet to Lambhill Turn Windyhill the
70 Chapter four 71
GW HVDCGW subsea HVDCGW Replace the conductors in the Lackenby Lackenby the in conductors the Replace Nortonto single circuit with higher rated larger with cable the replace and conductor, cable of higher rating, increase to the circuit’s thermal rating. to provide additional transmission capacity. capacity. transmission additional provide to of construction the involve works onshore The associated the and stations converter AC/DC worksAC at Torness and Hawthorn Pit. actively to technology novel use would This control the power flows on this circuit and during thermally overloading it prevent faults. system control to circuit this into booster quad a Install the power flows within it. Harker at transformer existing an Replacing substation with a new one of higher rating to transmission following overloading it prevent faults. system link from the Torness area Hawthorn to Pit Construct a new offshore 2 subsea link from Peterhead inthe north east of Scotland Hawthorn to Pit in the north of the involve works onshore The England. stations converter AC/DC of construction and the associated works AC at Peterhead (refer north to east 400kV and network 275kV reinforcement – NEEU) and Hawthorn Pit. in theTurn West Boldon Hartlepool to circuit site Pit Hawthorn the passes currently which connectto it. This to would create new West Boldon Hawthorn to Pit and Hawthorn Pit to better ensure would This Hartlepool circuits. load flow sharing and increased connectivity in the north east ring. 275kV Construct a new offshore 2 transmission additional provides option This circuit double new a installing capacity by from a new 400 kV substation in the Torness North in point connection suitable a to area England. East
LNRE Norton to Lackenby Reconductor 400kV circuit single Status: Project not started B7 Boundary affected: HAEU HAEU SuperGrid Transformer Harker WBQB WBQB Install quad booster in West Boldon to Offerton circuit Status: Project not started B6 Boundary affected: replacement 6 Status: Project not started B6 Boundary affected: WOSR Deploy device FACTS on West Boldon to Offerton circuit Scoping Status: B7 B6, Boundaries affected: WHTI Turn-in of West Boldon to Hartlepool circuit at Hawthorn Pit Scoping Status: B7a B7, B6, Boundaries affected: E4DC E4DC from Link HVDC subsea Eastern Peterhead to Hawthorn Pit Scoping Status: B2a, B2, Boundaries B1a, affected: B1, B7a B6, B7, B5, B4, TLNO North England East to Torness E2DC Link HVDC subsea Eastern from Torness to Hawthorn Pit Scoping Status: B8 Boundaries B7a, affected: B6, B7, B5, reinforcement AC Scoping Status: B7a B7, B6, B5, Boundaries affected: 2017 – January 2016/17 Assessment Options Network Chapter four Proposed optionsProposed Network OptionsAssessment2016/17 –January2017 Boundary affected:Boundary B7 started not Project Status: Osbaldwick number 1 circuit 400kV to Norton of 13.75km Reconductor NOR2 affected:Boundaries B6, B7, B7a started not Project Status: Osbaldwick double 400kV circuit to Norton of 13.75km Reconductor NOR1 Boundary affected:Boundary B7 started not Project Status: overhead line sections – uprate cable and thermal uprate circuit double Thornton to Lackenby LTR1 affected:Boundaries B6, B7, B7a started not Project Status: Lancashire and east north the New east–west circuit between NPNO affected:Boundaries B6, B7, B7a, B8 started not Project Status: Lancashire and east north the New east–west circuit between HPNO affected:Boundary B7 buildReduced option started not Project Status: to Osbaldwick double 400kV circuit Norton the of 55km uprate Thermal NOHW affected:Boundaries B6, B7, B7a started not Project Status: the circuits of rest the –reconductor circuit double 400kV Osbaldwick to Norton NOR3
and increase their thermal rating. to operate at higher temperatures, Osbaldwick circuits to allow them to Norton the of upgrade Thermal circuits’ thermal rating. higher rated conductor to increase the Norton to Osbaldwick double circuit with the in conductors the of rest the Replace rating. thermal rated conductor to increase the circuit’s the Norton to Osbaldwick circuits with higher of one in conductors the of some Replace rating. thermal higher rated conductor to increase the circuits’ Norton to Osbaldwick double circuit with the in conductors the of some Replace their thermal rating. operate at higher temperatures, increasing to them to allow circuit double to Thornton Lackenby the of sections of uprate Thermal options. outline two of second the is This determined. to be are points landing exact the time At this system. transmission the of rest the into England of north the from capability export power to increase England, of north the in circuit double 400kV anew Construct options. outline two of first the is This determined. to be are points landing exact the time At this system. transmission the of rest the into England of north the from capability export power to increase England, of north the in circuit double 400kV anew Construct
72 Chapter four 73
for fault level reasons through a high impedance path. This would allow some higher with circuit double Thornton to Construct a new 400kV double circuit in transfer power facilitate to Yorkshire central boundaries. relevant the across requirements Substation works might be required to circuits. new the accommodate substation Thornton at series reactors Install site the of parts the connect would which another one from disconnected operated flow sharing between the different parts of on overloads thermal reduce and site the circuits. connected Replace the conductors in the Drax circuits’ the increase to conductor rated thermal rating. Replacing the series reactor at Lister Drive Drive Lister at reactor series the Replacing with a quad booster allow to better control of power flows through the single cableto Birkenhead and avoid thermal overloads in the Mersey Ring area. Reinsulate the Penwortham Washway to Farm operation allow to circuit double Kirkby to at 400kV. Other associated works are at Kirkby substation transform to voltage from 400kV and 275kV to replace the Washway transformersfarm 275/132kV with 400/132kV transformers. The optionwould prevent circuits. these on overloads thermal Replace some of the conductors in the Lackenby Thornton to double circuit with the replace and conductor rated higher cable. rated higher new with sections cable the increase would activities two These rating. thermal circuits’ to Osbaldwick the of upgrade Thermal Thornton1 circuit allow to it operate to its increasing temperatures, higher at thermal rating.
TDRE Thornton Drax to Reconductor circuit double Status: Project not started B8 B7a, B7, B6, Boundaries affected: THS1/THS2 Install series reactors at Thornton Status: Project not started B8 B7a, B7, B6, Boundaries affected: and B9 OENO reinforcement Yorkshire Central Status: Project not started B8 B7a, B7, B6, Boundaries affected: MRUP MRUP Uprate the Penwortham to Washway Farm to Kirkby 275kV double circuit 400kV to Status: Project not started B7a Boundary affected: LDQB LDQB booster quad Drive Lister Status: Project not started B7a Boundary affected: OTHW circuit 1 Thornton Osbaldwick to upgrade thermal Status: Project not started option Reduced build B6 Boundary affected: LTR2 Lackenbyto Thornton double circuit – uprate cable section reconductor sectionsand Status: Project not started B7 B6, Boundaries affected: 2017 – January 2016/17 Assessment Options Network Chapter four Boundary affected:Boundary B8 started not Project Status: Quay reconductoring Tee Connah’s to Treuddyn TCRE affected:Boundary B8 buildReduced option Status: Design/development de-load scheme Western HVDC Link fast WEOS affected:Boundaries B7a, B8 started not Project Status: double circuit 400kV Cottam to Keadby the Reconductor KCRE affected:Boundary B8 started not Project Status: circuit rating match to works gantry – complete West Burton to High Marnham circuit WHRE affected:Boundaries B7, B8, B9 started not Project Status: split two-way run to replacement to allow Thornton Generator circuit breaker DREU affected:Boundaries B6, B7a started not Project Status: section reconductor and replace cable – 1circuit Eggborough to Drax DERE affected:Boundaries B7, B7a, B8 started not Project Status: Killingholme Circuit to Keadby to Beck Creyke the of leg Tee Keadby to Garforth Reconductor GKRE optionsProposed Network OptionsAssessment2016/17 –January2017
increase its thermal rating. and circuit Marnham to High Burton West the of uprating the to complete substation Marnham High at works gantry out Carry post fault. This would improve load on sharing circuits tolerated. be can level fault ahigher as winter in often more coupled run to be substation equivalents. This would allow Thornton owned circuit breakers with higher rated This reinforcement is to replace generator the circuit’s thermal rating. to increase rating, higher of cable larger with conductor, and replace the cable section Eggborough 1 circuit with higher rated to Drax the in conductors the Replace circuit’s thermal rating. circuit.three-ended This would raise the to Killingholme to Keadby Beck Creyke the of Replace the conductor on the Keadby leg thermal rating. thermal conductor. This would increase the circuits’ rated higher with circuit double Trawsfynydd to to Legacy Quay Connah’s the of leg Quay Replace the conductors in the Connah’s such conditions. during area local this in circuits of overload thermal prevent would This Flintshire. in point landing its near area the in faults Link following various transmission circuit HVDC Western the de-load instantaneously A scheme to automatically and almost rating. thermal rated conductor to increase the circuits’ higher with circuit double to Cottam Keadby the in conductors the Replace
74 Chapter four 75 Thermal upgrade of the to Treuddyn Tee Legacy circuits allow to them operate to their increase and temperatures, higher at thermal rating.
TLH1 Treuddyn to Legacy Tee upgrade thermal Status: Project not started option Reduced build B8 Boundary affected: 2017 – January 2016/17 Assessment Options Network Chapter four Boundary affected:Boundary EC5 started not Project Status: to circuit Tilbury Reconductor remainder of Rayleigh RTRE South to Tilbury circuit Reconductor remainder of Coryton CTRE affected:Boundary EC5 started not Project Status: link HVDC Anglia East to east South SGDC affected:Boundary EC5 started not Project Status: Bramford and Twinstead between circuit double 400kV A new BTNO affected:Boundary EC5 started not Project Status: double circuit Reconductor Bramford to Norwich NBRE affected:Boundariy EC5 started not Project Status: route Rayleigh to Braintree to Reconductor remainder of Bramford BRRE affected:Boundary EC5 started not Project Status: Main Burwell at MSCs MVAr 225 BMMS Reinforcement of options England –East 4.3 optionsProposed Network OptionsAssessment2016/17 –January2017 the rest of the transmission system. transmission the of rest the into Anglia East from capability export power Braintree–Rayleigh Main. It would increase Bramford– and Bramford–Pelham between run that circuits double to create point tee Twinstead and substation Bramford between Construct a new 400kV double circuit higher-rated conductor. with reconductored be would to Bramford The double circuits that run from Norwich to increase the circuit’s thermal rating. reconductored with higher rated conductor, been already not have that line overhead to Rayleigh to Braintree Bramford existing the of parts the in conductors the Replace future. in increase flows system as area Anglia East to the support voltage provide would Main Burwell at (MSCs) capacitors 225 switched MVAr new Three the circuits’ thermal rating. higher rated conductor. These would increase with reconductored been recently not have to and Rayleigh to circuits Tilbury that Tilbury Replace the conductors in the South Coryton transmission capacity. power the limiting area either in faults of effects the reduce and system, transmission the south east and East Anglia regions of the A 2 GW HVDC link to transfer power between between power to transfer link GW HVDC
76 Chapter four 77
to be utilised. be to Replace some components in Pelham Pelham in components some Replace Bramford the to connect that substation allow would This circuit. double Pelham to the full rating of the reconductored circuits Rayleigh in components some Replace Bramford the to connect that substation double Main Rayleigh to Braintree to utilised. be to circuits reconductored the of Replace the conductors in the newly formed formed newly the in conductors the Replace Rayleigh to Braintree to Bramford second conductor rated higher with circuit Main formed newly the in conductors the Replace second Bramford Pelham to circuit with higher circuit’s the increase to conductor rated thermal rating. rating full the allow would This circuit. to increase the circuit’s thermal rating. thermal circuit’s the increase to
at Rayleigh Main Rayleigh at Status: Project not started EC5 Boundary affected: RMEU components non-conductor Uprate of newly formed Bramford to double Main Rayleigh to Braintree to Bramford (following circuit circuit) double new Twinstead second Bramford to Pelham Pelham to Bramford second to Bramford (following circuit circuit) double new Twinstead Status: Project not started EC5 Boundary affected: BPEU components non-conductor Uprate double Pelham to Bramford of to Bramford (following circuit circuit) double new Twinstead Status: Project not started EC5 Boundary affected: PRRE PRRE formed newly Reconductor RBRE second formed newly Reconductor Bramford to Braintree to Rayleigh Bramford (following circuit Main circuit) double new Twinstead to Status: Project not started EC5 Boundary affected: 2017 – January 2016/17 Assessment Options Network Chapter four Boundaries affected:Boundaries SC1, SC2 started not Project Status: alternative designs for this option) three are (there coast south between South London and the New transmission route 400kV SCN1/SCN2/SCN3 affected:Boundaries SC1, SC2 buildReduced option started not Project Status: uprate thermal Ninfield to Lovedean LNHW affected:Boundary SC2 buildReduced option started not Project Status: switching scheme Reactive compensation protective SEEU affected:Boundaries SC1, SC2 started not Project Status: reactive compensation additional Ninfield and Bolney BNRC SC1, affected: SC2, B15Boundaries Status: Scoping compensation reactive coast East South SCRC affected:Boundary SC1 buildReduced option started not Project Status: thermal uprating Bramley to Fleet circuits BFHW Reinforcement options –South of England 4.4 optionsProposed Network OptionsAssessment2016/17 –January2017
system voltages following faults. of control better allow would This faults. quicklyvery following transmission system service of out or in switched to be equipment reactive existing to allow equipment, other and system, communications anew Provide network operating conditions. acceptable operational limits in future substations, to maintain voltages within Ninfield and Bolney at equipment Provide additional reactive compensation south east coast. to help maintain voltage stability on the power post-fault reactive provide would This coast. east south the SVC) on an as Install (known voltage dynamic support their thermal rating. at higher temperatures, and increase to operate them to allow circuits Fleet Thermal upgrade of the Bramley to south of London and the south coast. south the and London of south additional transmission capacity between the provide would works These work. associated out carry and London to south coast south Construct a new transmission route from the rating. thermal at higher temperatures, and increase their operate to them allow to circuits to Ninfield to Bolney Lovedean the of upgrade Thermal
78 Chapter four 79
at the Wymondley 400kV substation. The substation. 400kV Wymondley the at capability the improve would boosters quad controlto the power flows on the North circuits. London Modify theexisting circuit that runs from Pelham Sundon. to in the Turn circuit at Wymondley create to two separate circuits that run from Pelham Wymondley to and from Wymondley Sundon to improve to the balance of flows. Install a pair of quad boosters on the double Pelham to Wymondley from running circuits cable 275kV second a Constructing Ealing. to Willesden from route transmission modifying include would work Associated the rerouting by substation 275kV Ealing quad a into Wimbledon circuit Willesden to Ealing. at booster Establishing a new 400kV double circuit from power increase to Seabank. to Point Hinkley export capability from the South West into the rest of the transmission system. Point Hinkley the in conductors the Replace Thermal upgrade of the Alverdiscott to circuitsTaunton allow to them operate to their increase and temperatures, higher at thermal rating. Replace the conductors in the Fleet to Lovedean circuits with a higher rated ratings. thermal their increase to conductor The 400kV circuits running from Kemsley via LongfieldTeeto Littlebrook would be conductor. higher-rated with reconductored conductor rated higher with circuits Taunton to rating. thermal circuits’ the increase to
cable Ealing diversion Ealing cable Status: Project not started B14e Boundary affected: WEC1 275kV Wimbledon to Willesden WYQB WYQB Wymondley quad boosters Status: Project not started B14e Boundary affected: WYTI turn-in Wymondley Status: Project not started B14e Boundary affected: ATHW double Taunton to Alverdiscott THRE Reconductor Hinkley Point HSNO Hinkley Point to Seabank new to Taunton double circuit Status: Project not started SC1 Boundary affected: uprating thermal circuit Status: Project not started option Reduced build SC1 Boundary affected: KLRE circuits Littlebrook to Kemsley uprating design/development Status: B15 SC1, Boundaries affected: circuit double Scoping Status: B13 SC1, Boundaries affected: FLRE reconductoring Lovedean to Fleet design/development Status: SC1 Boundary affected: 2017 – January 2016/17 Assessment Options Network Chapter four Boundary affected:Boundary NW2 started not Project Status: phase per core –single replacement 1cable Trawsfynydd to Pentir PTC1 affected:Boundary NW2 started not Project Status: circuit second Trawsfynydd to Pentir PTNO affected:Boundary NW3 started not Project Status: 2circuits and 1 Quay Connah’s to Bodelwyddan to Pentir the of legs Pentir Reconductor PBRE affected:Boundaries NW2, NW3 started not Project Status: 2circuits 1and Quay Connah’s to Bodelwyddan to Pentir the of legs Quay Connah's the Reconductor BCRE affected:Boundaries SW1, NW2, NW3 started not Project Status: Link HVDC Wales South to Wales North WPDC affected:Boundary NW1 Status: Design/development circuit route double second Pentir to Wylfa WPNO of England Reinforcement options –Wales the West and 4.5 optionsProposed Network OptionsAssessment2016/17 –January2017
thermal rating. thermal rated conductor to increase the circuits’ Connah’s Quay double circuit with higher to to Bodelwyddan Pentir the on Quay between and Bodelwyddan Connah’s Replace the conductors in the sections area limiting the power transmission capacity. either in faults of effects the reduce would It Wales parts of the transmission network. South and Wales North the between power to transfer Pembroke and Wylfa between 2 offshore A new to Pentir. Wylfa from route Constructing a second 400kV transmission sections increasing the circuit’s thermal rating. cable alarge with 1circuit Trawsfyndd to Pentir the of sections cable Replacing constructing new cable sections. infrastructure and including corridor circuit existing the by using circuit 400kV to Trawsfynydd Pentir asecond Create to increase the circuits’ thermal rating. double circuit with higher rated conductor Quay to Connah’s to Bodelwyddan Pentir the on Bodelwyddan and Pentir between Replace the conductors in the sections GW HVDC subsea link link subsea GW HVDC
80 Chapter four 81
power other to lightly loaded circuits. 400kV substation on each of the Cilfynydd Cilfynydd the of each on substation 400kV Imperialto Park and Cilfynydd Seabank to the resolve would This 400kV circuits. rerouting by issues overloading thermal Turn-in the existing Pembroke to Walham Walham to Pembroke existing the Turn-in North Swansea substation the into circuit improveto load sharing in the local circuits. Cilfynydd at booster quad a Installating Replace the conductors in remaining parts of remaining in conductors the Replace the circuits between Pentir and Trawsfynydd further increase to conductor rated higher with rating. thermal circuits’ the circuit double of rating thermal Increase Construct a new cable tunnel with a single core per phase so there would be two cores per phase in each circuit. This would remove imposed capacity circuit the on restriction the theby existing cable and increase the circuits’ ratings. thermal Replace the conductors in part of the circuits between Pentir and Trawsfynydd with higher single second a Construct conductor. rated these on section cable phase per core increase would activities These two circuits. rating. thermal circuits’ the double per core single new a installing by circuit phase cable adjacent existing to cabled section, so each circuit would then have two cores.
turn-in to Swansea North Status: Project not started SW1 Boundary affected: CIQB installation booster Quad at Cilfynydd Status: Project not started SW1 Boundary affected: PWTI circuit Walham to Pembroke circuit uprate circuit Status: Project not started SW1 Boundary affected: SEC1 400kV cable Tunnel Severn overhead line sections line overhead Status: Project not started NW3 Boundary affected: HCC1 Cowley to Minety and Cowley (Hinksey cables Walham to upgrade cables) Status: Project not started SW1 Boundary affected: PTRE Pentir to Trawsfynydd circuits – remaining the reconductor PTC2 Pentir to Trawsfynydd 1 and 2 and reconductor of an overhead Pentir existing the on section line Trawsfynyddto circuit Status: Project not started NW2 Boundary affected: cables – second core per phase per core second – cables 2017 – January 2016/17 Assessment Options Network Chapter four Network OptionsAssessment2016/17 –January2017 82 Network Options Assessment 2016/17 – January 2017 83 Chapter five
Investment recommendations 84 Chapter five Investment recommendations Investing £83million thisyear next stepsnext for in region. each works required options the recommended and our preferred to identify us enable and scenario, each for strategy cost–benefit give results The thebest analysis. our cost–benefit from our investmentChapter 5presents recommendations Introduction 5.1 £83m Network OptionsAssessment2016/17 –January2017 from delaying options. from delayingoptions. and, asaresult, significantsavingsare possible necessary astheenergylandscapechanges lifetime. Ouranalysisconsidered whatistruly investment ofalmost£3.8billionovertheir million thisyearonoptionsthathaveatotal that theTOsare recommended toinvest£83 and 14haveaProceed decision.Thismeans This year17optionsare considered critical Key statistics
14 Through 14 options
economical andcoordinated way. future energylandscapeinanefficient, can continuesupportingthetransitionto will ensure thattheGBtransmissionnetwork analysis ourNOA2016/17recommendations scenario-based, single-yearleastregret this investmentyear. Through utilisingthe may havecommittedover£2millionofspend We recommend todelay3projects which £3.8bn Total worth of£3.8billion
84 Chapter five 85
ion t a alu v e r c e i s o d i m n n r o u cal i i l t i ena r cis This section lists all the options and their recommended delivery dates, as well as critical. are which those highlighting analysis regret least options’ Critical a have must options critical All recommendation made this year and so advance onto our single year least regret analysis. This measures and compares proceeding with associated regret the the against year one by option critical each regret of delaying it. If a region has multiple the compare we then options critical different delivering with associated regret each For options. critical of combinations region, we will always recommend the that options, of combination or option, minimises the levels of regret across all four an If sensitivities. any plus scenarios energy option is being driven a single by scenario then we will investigate the drivers behind that option further ensure to that the right made. being is really decision c c e econo ima s
t 2. d r d
e p ’ e o f n s r o
to be o e d s t delayed e ion s t t sid a ion p n t for 32 options recommended e o l o p
3 critical options 14 critical options t c 7 bmit o
a 1 No decision required u s 49
recommended to proceed s n o i t p o 8 8
Recommended delivery dates dates delivery Recommended Each option has an optimum year of completion which delivers the most benefit for the GB consumer under each energy scenario. If an optimum option’s delivery date is the same as its EISD then it is considered must decision a because option critical a be made this If the year. optimum delivery date is later than the EISD in all scenarios and sensitivities then no decision is required this year and the decision can be delayed whento we will have more information. Throughout this chapter, we take the options presented in Chapter 4 – Proposed options as the inputs our to cost–benefit analysis and geographical each for analysis perform this we Our scenario. energy each under region economic analysis provides us with three sets of results and this chapter is laid out cover to each set in turn. If you would like understand to the theory behind our cost–benefit analysis then please refer Chapter to 2 – Methodology. The three sets of results are as follows: 1. 2017 – January 2016/17 Assessment Options Network Figure 5.1 through the process How the options went Chapter five Investment recommendations in order to maintain the EISD. EISD. the to maintain order in Proceed: option by one year. this of delivery the to delay suspended be should progress in work Any EISD. by its option Delay: information. more have will we when years later in made be can Arecommendation required. yet not is adecision so and year this critical No decision required: time. this at Do not proceed: 3. Network OptionsAssessment2016/17 –January2017 North’ region is geographically very large and North’ region isgeographicallyverylargeand their connectiondates.Our‘Scotlandandthe our customerswere tohaveconnectedby Contracted’ sensitivityconsidersifnoneof by theirconnectiondate,and‘NoLocal every singlecustomerwere tohaveconnected The ‘LocalContracted’scenarioconsidersif ‘Local Contracted’and‘NoLocalContracted’. under twoofouradditionalsensitivities: we alsoanalyseanoption’s performance As wellasourfourfuture energyscenarios, Local ContractedandNo the following outcomes: of to one allocated be will options All a recommendation for each option. to make aposition in be will we analysis, Following the single year least regret Recommendation for each option It is no longer economic to deliver this this to deliver economic longer no is It Work should continue or commence This option is not optimal optimal not is option This The option is not not is option The
the consumer. its planned completion date remains best for that to ensure year each reevaluated is project ongoing an that is analysis regret least year single the of robustness The versa. vice and year this delayed to be recommended be may year last to proceed recommended we that option an that means This accordingly. recommendations for an option may adapt As our energy landscape is changing, our and theyare discussedafterTable 5.1. generation diversitytojustifythesesensitivities and theNorth’region withsufficientlylittle there are someareas withinthe‘Scotland Although notcredible forthewholeregion, which are smallenoughforthemtobecredible. sensitivities considered inourotherregions credible forthewholeregion. You willseeboth which meansneitherofthesesensitivitiesare has anumberofcustomersduetoconnect improve it. year leastregret process andwaysto Please giveusyourviewsonthesingle Stakeholder engagement
86
Chapter five 87
2026 2026 N/A 2020 N/A N/A N/A 2025 2026 N/A 2025 N/A No Progression 2025 2022 N/A 2020 2028 N/A 2029 2024 2024 2034 2024 2034 Slow Progression Optimum Delivery Date Delivery Optimum 2023 2023 2022 2020 N/A N/A N/A 2023 2024 N/A 2023 2029 Consumer Consumer Power be found in Chapter 4 – Proposed options. Some options are as marked they are as ‘N/A’ not optimal under that particular scenario or were which options 32 found We sensitivity. not optimal under any of the scenarios at this time and are therefore not included in the table. theyHowever, are available view to in our final with the recommendationtables 5.12 to 5.9 ‘Do Not Proceed’ and their descriptions can 2020 2025 2022 2020 N/A 2024 N/A 2024 2024 N/A 2024 2028 Gone Green Gone 2019 2022 2022 2020 2028 2024 2027 2020 2024 2027 2022 2021 EISD .
Reconductor of Norton 13.75km to Osbaldwick (NOR2) circuit 400kV 1 number Reconductor 13.75km of Norton to Osbaldwick Osbaldwick to Norton of 13.75km Reconductor 400kV double circuit (NOR1) Reconductor Lackenby to Norton single 400kV single Norton to Lackenby Reconductor (LNRE) circuit Turn-in of West Boldon to Hartlepool circuit at Hawthorn Pit (WHTI) Torness to North East England AC reinforcement(TLNO) Eastern subsea HVDC Link from Torness to Hawthorn (E2DC) Pit Denny to Wishaw 400kV reinforcement (DWNO) Windyhill to Lambhill to Longannet 275kV circuit turn in to Denny North 275kV substation (WLTI) Eastern subsea HVDC Link from Peterhead to to Peterhead from Link HVDC subsea Eastern Hawthorn (E4DC) Pit East Coast onshore 400kV incremental reinforcement reinforcement incremental 400kV onshore Coast East (ECUP) East Coast onshore 275kV upgrade (ECU2) upgrade 275kV onshore Coast East Reactive compensation at Tummel and Melgarve and Tummel at compensation Reactive (TMRC) Option name andcode Scotland and the North region Table 5.1 Table Tables 5.1 to 5.5 show 5.5 to the optimalTables 5.1 delivery date for each option before the next stage of analysis. Options whose optimum delivery date critical considered are EISD their as same the is options as a decision must be made this year. bold in are options Critical This section are that lists all options the seen be optimal to 5.2 Recommended delivery dates at this time and time recommended this their at delivery as dates well are which those as highlighting critical. 2017 – January 2016/17 Assessment Options Network Chapter five Investment recommendations nine critical options: are there region, North’ the and ‘Scotland For Scotland andtheNorthregion Table 5.1continued Network OptionsAssessment2016/17 –January2017 Option name and code and name Option reconductor full length of circuits (NOR3) – circuit double 400kV toOsbaldwick Norton Lancashire (HPNO) and east north the between circuit east–west New Lancashire (NPNO)Lancashire and east north the between circuit east–west New Lister Drive quad booster (LDQB) booster quad Drive Lister Kirkby 275kV double circuit to 400kV (MRUP) 400kV to circuit double 275kV Kirkby to Farm Washway to Penwortham the Uprate Central Yorkshire (OENO) reinforcement Install series reactors at Thornton (THS1) Thornton at reactors series Install Install series reactors at Thornton (THS2) Thornton at reactors series Install Western HVDC Link fast de-load scheme (WEOS) (TCRE) reconductoring Quay Tee toConnah’s Treuddyn Treuddyn Tee to Legacy thermal upgrade (TLH1) upgrade thermal Tee toLegacy Treuddyn Central Yorkshire reinforcement (OENO). YorkshireCentral reinforcement (MRUP).400kV to circuit 275kV double to Kirkby Farm to Washway Penwortham the Uprate (LDQB). booster quad Drive Lister Osbaldwick 400kV double circuit (NOR1) 13.75km to Norton of Reconductor circuit400kV (LNRE). Reconductor Lackenby to Norton single (WHTI). Pit Hawthorn at circuit to Hartlepool Boldon West Turn-in of reinforcement (TLNO). AC England East to North Torness (E2DC). Pit to Hawthorn Torness from Link HVDC subsea Eastern (E4DC). Pit to Hawthorn Peterhead from Link HVDC subsea Eastern
EISD 2021 2026 2026 2020 2023 2024 2021 2021 2019 2020 2020
Gone Green 2026 2027 N/A 2020 2023 2024 2022 N/A 2023 2027 2027 this time. at optimum not was boundaries these across Our studies showed that further reinforcement enough for these sensitivities to be credible. boundaries as the generation diversity is small B2a and B0 the for sensitivities Contracted Local No and Contracted Local We considered Power Consumer N/A N/A 2032 2020 2023 2025 2022 N/A 2025 N/A N/A Optimum Delivery Date Progression Slow 2028 N/A N/A 2020 2023 2024 2022 N/A 2025 N/A N/A Progression No N/A N/A N/A 2021 2026 2024 N/A 2022 2024 N/A N/A 88 Chapter five 89 No Local Local No Contracted N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A Local Local Contracted 2023 2024 2026 2027 2031 2031 2031 2031 2031 2031 2031 No Progression 2023 N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A Optimum Delivery Date Delivery Optimum Slow Progression 2026 2027 2032 2033 2033 2034 2034 2034 2034 2034 N/A Consumer Consumer Power 2028 2029 2030 2035 2035 2036 2036 2036 2036 2036 N/A Gone Green Gone 2024 2025 2026 2027 2031 2031 2031 2031 2031 2031 2032 EISD 2023 2020 2021 2023 2019 2020 2020 2019 2019 2019 2030
MVAr MSCs at Burwell Main (BMMS).
225 Option name and code 225MVAr MSCs at (BMMS) Main Burwell Reconductor Bramford Bramford Reconductor circuit Norwich double to (NBRE) Reconductor remainder remainder Reconductor of Bramford to Braintree to Rayleigh route (BRRE) A new 400kV double circuit between Bramford (BTNO) Twinstead and Reconductor remainder remainder Reconductor of Rayleigh to Tilbury (RTRE) circuit Reconductor newly newly Reconductor Bramford second formed to Braintree to Rayleigh (following circuit Main Bramford to Twinstead circuit) double new (RBRE) Reconductor newly newly Reconductor Bramford second formed to Pelham circuit (following Bramford to double new Twinstead (PRRE) circuit) Uprate non-conductor non-conductor Uprate Bramford of components circuit double Pelham to (following Bramford to double new Twinstead (BPEU) circuit) Reconductor remainder remainder Reconductor of Coryton South to (CTRE) Tilbury circuit Uprate non-conductor non-conductor Uprate newly of components formed Bramford to Rayleigh to Braintree circuit double Main (following Bramford to double new Twinstead Main Rayleigh at circuit) (RMEU) South east to East Anglia (SGDC) link HVDC For the East region, there is one critical option: critical one is there region, East the For Table 5.2 Table The East region 2017 – January 2016/17 Assessment Options Network Chapter five Investment recommendations South Import Table 5.3 presents demand, the with combined London, around and through transfer power the Europe, ‘export’. When there are exports to continental and ‘import’ are that sensitivities overall two for region South the studied We have The South region Network OptionsAssessment2016/17 –January2017 (HSNO) new double circuit Hinkley Point to Seabank (KLRE) circuits uprating Kemsley to Littlebrook reconductoring (FLRE) Lovedean to Fleet thermal uprate (LNHW) toNinfield Lovedean scheme (SEEU) switching protective compensation Reactive compensation (BNRC) additional reactive Bolney and Ninfield (SCRC) reactive compensation South East coast Option name and code and name Option
2023 2021 2020 2019 2021 2021 2018 EISD 2026 2021 2020 2023 2021 2023 2018 Gone Green 2027 2021 2020 2023 2021 2023 2018 Power Consumer 2031 2021 2020 2023 2021 2023 2018 Progression Slow a more accurate forecast. accurate a more to give 5.4 together 5.3 and tables to consider have we but 100% exports Table 5.4 assumes 94. page on topic this on information more from continental Europe. The ETYS imports are there when from issues different Optimum Delivery Date 2034 2021 2020 2023 2021 2023 2018 Progression No 2024 2021 2020 2023 2021 2023 2018 Contracted Local carries N/A 2021 2020 N/A 2021 N/A 2018 Contracted No Local 90 Chapter five 91 No Local Local No Contracted 2018 2023 2021 2023 2020 2021 2029 2030 2030 N/A Local Local Contracted 2018 2023 2021 2023 2020 2021 2029 2030 2030 2024 No Progression 2018 2023 2021 2023 2020 2021 2020 2024 2024 2034 Fleet to Lovedean reconductoring (FLRE). reconductoring Lovedean to Fleet uprating circuits Littlebrook to Kemsley (KLRE). (WYTI). turn-in Wymondley Optimum Delivery Date Delivery Optimum Slow Progression 2018 2023 2021 2023 2020 2021 2030 2031 2031 2031 Consumer Consumer Power 2018 2023 2021 2023 2020 2021 2024 2025 2025 2027 Gone Green Gone 2018 2023 2021 2023 2020 2021 2029 2030 2030 2026 EISD 2018 2021 2021 2019 2020 2021 2020 2020 2022 2023
South East coast reactive compensation compensation reactive coast East South (SCRC). Reactive compensation protective switching (SEEU). scheme Option name and code South East coast coast East South compensation reactive (SCRC) Bolney and Ninfield Ninfield and Bolney reactive additional (BNRC) compensation Reactive compensation protective switching (SEEU)scheme Lovedean to Ninfield (LNHW) uprate thermal Fleet to Lovedean (FLRE) reconductoring Kemsley to Littlebrook to Kemsley uprating circuits (KLRE) Wymondley turn-in turn-in Wymondley (WYTI) Wymondley quad quad Wymondley (WYQB) boosters Willesden to Wimbledon Wimbledon to Willesden Ealing cable 275kV (WEC1) diversion Hinkley Point to Seabank to Point Hinkley circuit double new (HSNO) For the South region, there are five critical options: Table 5.4 Table South Export 2017 – January 2016/17 Assessment Options Network Chapter five Investment recommendations No Local Contracted backgrounds were critical options. The Local Contracted and no are there region, West the For The West region Table 5.5 Network OptionsAssessment2016/17 –January2017 circuits (BCRE) 2 1and Quay Connah’s to to Bodelwyddan Pentir the of legs Connah's Quay Reconductor the (PTC2) circuit to Trawsfynydd Pentir existing the on overhead line section an of reconductor and phase per core –second 2cables and 1 toTrawsfynydd Pentir (PTC1) single core per phase – replacement 1 cable toTrawsfynydd Pentir second circuit (PTNO) toTrawsfynydd Pentir (WPNO) double circuit route second toPentir Wylfa Option name and code and name Option
2020 2021 2022 2023 2024 EISD 2031 2030 2030 2028 2030 Gone Green
2031 2030 2030 2028 2030 Power Consumer
2030 2029 2029 2027 2029 Progression Slow within the West region. for the North Wales boundaries which are Optimum Delivery Date N/A N/A N/A N/A N/A Progression No 2026 2025 2025 2024 2025 Contracted Local N/A N/A N/A N/A N/A Contracted No Local 92 Chapter five 93
Farm Kirkby to double 275kV circuit to 400kV (MRUP). reinforcementCentral Yorkshire (OENO). Eastern subsea HVDC Link from Peterhead Hawthornto Pit (E4DC). Eastern subsea HVDC Link from Torness Hawthornto Pit (E2DC). Torness North to East England AC (TLNO). reinforcement single Norton to Lackenby Reconductor (LNRE). 400kV circuit Reconductor of Norton to 13.75km (NOR1). circuit double 400kV Osbaldwick Lister Drive quad booster (LDQB). Uprate the Penwortham Washway to regret depending how they compare to the depending how they compare regret always choose the optionbest option. We all scenarios. across with the least regret For more information, please see Chapter 2 –For more Methodology. on analysis regret least performed the SO The shows below 5.6 Table combinations. 256 all (1) ranked performing combinations top the if no options were be to progressed, ranked (241). position at Having taken account of WHTI, this leaves this therefore and options critical eight with region combinations: different possible 256 also We’ve shown the levels (10). to of regret
’s ELEU (Eastern’s Link onshore works) and Economic regret is ‘regret’ option’s In economic analysis an in benefit for that defined as the difference option against the benefit of the best option for that scenario. Therefore in each scenario for that scenario. Therefore and of zero, the best option will have a regret levels of the other options will have different This section analyses critical the each region in options 5.3 leastCritical regret options’ analysis and compares regret their across values each scenario. 2017 – January 2016/17 Assessment Options Network For each region, there will be a combination of and economic most the be will which options efficient for the network. As there are a number of critical options that could be progressed this thereyear, are several combinations, one of which will have the lowest value of regret across the scenarios. The options that make up this proceed. recommended to be will combination The worst regret for each combination will be with combination the and bold in highlighted energy the across regret worst smallest the green. in highlighted be scenarios will Scotland and the North region present that options critical nine has region This option The combinations. possible different 512 ‘Turn-in of West Boldon Hartlepool to circuit at Hawthorn Pit’ (WHTI) has an optimum year of delivery that is the same as its EISD scenarios. all for This means that there is no requirement to perform single year regret analysis for this option, as progressing it maintain to its EISD is the correct course of action under all scenarios. worthIt’s noting that WHTI is a modification of NOA1 has an earlier EISD. Chapter five Investment recommendations minimised by both recommending proceed is risk therefore and costs end front low Slow Progression TLNO is optimal under Gone Green or E2DC either of Delivery case. needs SWW an to prepare forward taken is it that energy scenarios and so we recommend four all under optimal E4DC is TLNO. and E4DC, for E2DC proceed We recommend in Scotland. supply of security to benefits provide would TLNO) and (E4DC, E2DC options three the of each network, the across capability transfer to south north enhancing as well As following options: but including WHTI. This includes the LNRE except region this in reinforcements all to progress is option regret least The Regrets fortheScotlandandNorthregionoptions Table 5.6 Network OptionsAssessment2016/17 –January2017 (241) Progress no critical options and MRUP MRUP and (10) Progress all critical options except LDQB LNRE and MRUP and LNRE (9) Progress all critical options except LDQB, NOR1 and MRUP LNRE, except options critical all Progress (8) and NOR1 (7) Progress all critical options except LNRE and MRUP MRUP and NOR1 except options critical all Progress (6) (5) Progress all critical options except NOR1 NOR1 except options critical all Progress (5) (4) Progress all critical options (3) Progress all critical options except MRUP except options critical all Progress (3) and MRUP and LNRE except options critical all (2) Progress (1) Progress all critical options except LNRE LNRE except options critical all (1) Progress Combination OENO to meet its EISD of 2024. of EISD its to meet OENO 2023. of EISD its to meet MRUP 2020. of EISD its to meet LDQB 2022. of EISD its to meet NOR1 2028. of EISD its to meet TLNO 2024. of EISD its to meet E2DC 2024. of EISD its E4DC to meet
respectively. Both have have Both respectively. and and
£1200m £36.2m £35.9m £7.4m £2.6m 76m £7.6 £2.8m £2.8m 76m £7.6 £7.4m £2.6m Gone Green
£400m £28.0m £22.3m £19.4m £15.7m £8.9m £9.6m £9.6m £8.9m £3.2m £4.0m Power Consumer be delayed. NOA year’s this in option acritical not is it however NOA year’s last in ’proceed’ was WEOS 2015/16. NOA in recommendation a‘proceed’ given commented on the option below which was In addition to the options above, we’ve also 2024. in delivery for proceed recommend we therefore and E4DC option the of part integral an is it B2a, boundary local the for own its on proceed to recommended not is NEEU Although meet the SWW criteria. not do they as case needs SWW an require not do options These to proceed. OENO and NOR1, MRUP LDQB, recommend We also proceed with. conclusion as to which is the best option to aclear draw will study SWW the and future the in delivered to be either allows year. This this scheme (WEOS). de-load fast Link HVDC Western , and so we recommend the delivery to to delivery the recommend we so , and £400m £28.1m £28.1m £13.3m £12.0m £13.3m £12.0m £0.6m £1.9m £1.9m £0.6m Progression Slow £100m £3.5m £3.5m £3.5m £3.5m £3.5m £3.5m £3.5m £3.5m £3.5m £3.5m Progression No
£1200m £1200m £36.2m £35.9m £19.4m £15.7m £13.3m £12.0m £9.6m £8.9m £7.4m £4.0m Worst Regret Worst
94 Chapter five 95
WorstRegret £0.0m £190m No Local Local No Contracted £0.0m £0.0m Local Local Contracted £0.0m £190m 225MVAr MSCs225MVAr at Burwell Main (BMMS). Wymondley turn-in (WYTI). turn-in Wymondley which presents two different possible possible different two presents which courses of action – proceed with the option or do not proceed. The East region East The option critical one only has region This This means that there is no requirement to perform single year regret analysis upon the options these progressing as options, above maintainto their EISD is the correct course of region this Therefore scenarios. all under action analysed be to option critical one only has which presents two different courses of action – proceed with the option or do not proceed. No Progression £0.0m £1.4m
Slow Progression £0.0m £0.0m
as well Consumer Consumer Power £0.0m £0.0m Gone Green Gone £0.0m £0.0m
South East coast reactive compensation compensation reactive coast East South (SCRC). Reactive compensation protective switching (SEEU). scheme (FLRE). reconductoring Lovedean to Fleet uprating circuits Littlebrook to Kemsley (KLRE). Progress BMMS Progress Do not Progress BMMS as delayed connection of others. WEOS WEOS others. of connection delayed as has driver main the as critical longer no is completely. disappeared or delayed either BMMS has zero spend in its first year and therefore there is no regret in progressing this option. Therefore the SO recommends that option BMMS is proceeded maintain to its Table 5.7 Table EISD of 2023. region South The The South region has five critical options that different combinations. possible 32 present optimum their options, following the For years of delivery are the same as their EISDs scenarios. all for Regrets for the East region generation in all scenarios and marks a significant change FES to the 2015 This option is no longer critical this year year this critical longer no is option This due a change to in generation background. This includes early closure of some 2017 – January 2016/17 Assessment Options Network Chapter five Investment recommendations date for the new double circuit. double new the for date optimum actual the determine will This date. project based on the contracted connection SWW the with proceeding to recommend 2016/17 For to proceed. continue we project this 2015/16 NOA in recommended we and This reinforcement was considered critical (HSNO). circuit double new to Seabank Point region, the SO has analysed the Hinkley In addition to the critical options in the South progressed. not is WYTI option turn-in. Therefore the SO recommends that The least regret option is to delay Wymondley Regrets fortheSouthregion Table 5.8 Network OptionsAssessment2016/17 –January2017 WYTI Progress not Do Progress WYTI
£0.0m £0.6m Gone Green £0.0m £0.3m Power Consumer £0.0m £0.7m Progression Slow
£0.0m £1.9m Progression No be made this year. this made be to decisions investment necessary no are there This region has no critical options and therefore The West region £0.0m £0.6m Contracted Local £0.0m £0.6m Contracted No Local £0.0m £1.9m Worst Regret Worst 96 Chapter five 97
2016/17
NOA
Recommendation Do not proceed Do not proceed Do not proceed Do not proceed Do not proceed Do not proceed No decision required decision No Do not proceed Do not proceed Do not proceed Do not proceed Do not proceed Do not proceed No decision required decision No No decision required decision No Do not proceed Proceed No decision required decision No No decision required decision No
2015/16 NOA Recommendation 2015/16 Not featured in NOA 2015/16 Not featured in NOA 2015/16 Not featured in NOA 2015/16 Not featured in NOA Do not proceed 2015/16 Not featured in NOA 2015/16 Not featured in NOA 2015/16 Not featured in NOA Do not proceed Delay 2015/16 Not featured in NOA 2015/16 Not featured in NOA 2015/16 Not featured in NOA No decision required decision No 2015/16 Not featured in NOA Do not proceed Proceed 2015/16 Not featured in NOA Do not proceed give an indication whether an option could could option an whether indication an give be an SWW. SWW? Potential No No No Yes Yes No Yes Yes Yes Yes No Yes Yes Yes Yes Yes Yes No No
for comparison and comparison for
Option name Option Beauly to Shin to Loch Buidhe double 132kV circuit (BLR1) reconductoring Beauly to Fyrish 275kV double circuit reconductoring(FBRE) reconfiguration connection generation and Beauly to Loch Buidhe 275kV double circuit connection generation and reconductoring (BLR2) reconfiguration Beauly to Loch Buidhe and Loch Buidhe to Dounreay (BDRE) reconductoring circuit double 275kV New Beauly to Loch Buidhe 275kV double circuit (BLN2) Reactive compensation at Tummel (TURC) Reactive compensation at Tummel and Melgarve and Tummel at compensation Reactive (TMRC) Reactive compensation at Tummel and Melgarve and inter-bus Transformers at Fort Augustus (B1RC) New Beauly to Kintore 400kV double circuit (BKNO) New Beauly to Blackhillock 400kV double circuit (BBNO) New 275kV phase shifting transformers at Blackhillock Blackhillock at transformers shifting phase 275kV New on the circuits from Knocknagael (BLQB) North east 400kV and 275kV network reinforcement (NEEU) Rothienorman substation with reconductoring of the the of reconductoring with substation Rothienorman 275kV Rothienorman to Kintore circuit (RKEU) East Coast onshore 275kV upgrade (ECU2) upgrade 275kV onshore Coast East East Coast onshore 400kV incremental reinforcement reinforcement incremental 400kV onshore Coast East (ECUP) East Coast onshore 400kV reinforcement (ECU4) reinforcement 400kV onshore Coast East Eastern subsea HVDC Link from Peterhead to Hawthorn Pit (E4DC) Windyhill to Lambhill to Longannet 275kV circuit turn in to Denny North 275kV substation (WLTI) Denny to Wishaw 400kV reinforcement (DWNO) Table 5.9 Table Scotland and the North region In addition, we present the recommendation recommendation the present we addition, In from last year’s NOA This section presents recommendation the each for 5.4 each option for Recommendation option based upon how the options have performed have options the basedoption how upon economic the in analysis. 2017 – January 2016/17 Assessment Options Network Chapter five Investment recommendations Scotland andtheNorthregion Table 5.9continued Network OptionsAssessment2016/17 –January2017 Treuddyn Tee to Legacy thermal upgrade (TLH1) upgrade thermal Tee toLegacy Treuddyn Treuddyn Tee to Connah’s Quay reconductoring (TCRE) reconductoring Quay Tee toConnah’s Treuddyn Western HVDC Link fast de-load scheme (WEOS) circuit (KCRE) double 400kV toCottam Keadby the Reconductor works to match circuit rating (WHRE) rating circuit tomatch works gantry –complete circuit Marnham toHigh Burton West to run two-way split (DREU) split two-way to run Thornton toallow replacement breaker circuit Generator cable section (DERE) replace and –reconductor 1circuit toEggborough Drax Beck to Keadby to Killingholme Circuit (GKRE) Circuit toKillingholme toKeadby Beck Creyke the of leg Tee toKeadby Garforth Reconductor Reconductor Drax to Thornton double circuit (TDRE) circuit double toThornton Drax Reconductor Install series reactors at Thornton (THS1/THS2) Thornton at reactors series Install Central Yorkshire reinforcement (OENO) 275kV double circuit to 400kV (MRUP) to400kV circuit double 275kV toKirkby Farm toWashway Penwortham the Uprate Lister Drive quad booster (LDQB) (OTHW) upgrade thermal 1circuit toThornton Osbaldwick section and reconductor sections (LTR2) cable –uprate circuit double toThornton Lackenby thermal uprate overhead line sections (LTR1) and cable –uprate circuit double toThornton Lackenby (NPNO) Padiham and Norton between circuit east–west New Padiham (HPNO) and Pit Hawthorn between circuit east–west New 400kV double circuit (NOHW) toOsbaldwick Norton the of 55km uprate Thermal reconductor the rest of the circuits (NOR3) circuits the of rest the reconductor – circuit double 400kV toOsbaldwick Norton 1 400kV circuit (NOR2) circuit 1 400kV number toOsbaldwick 13.75km Norton of Reconductor double circuit (NOR1) 400kV toOsbaldwick 13.75km Norton of Reconductor (LNRE) circuit 400kV single toNorton Lackenby Reconductor Harker SuperGrid Transformer 6 replacement (HAEU) (WBQB) circuit toOfferton Boldon West in booster quad Install (WOSR) circuit toOfferton Boldon West on FACTS device Deploy Pit (WHTI) Hawthorn at circuit toHartlepool Boldon West of Turn-in Torness to North East England AC reinforcement (TLNO) AC reinforcement England East toNorth Torness Pit (E2DC) Pit toHawthorn Torness from Link HVDC subsea Eastern Option name
No No No No No No No No No No No No No No No No Yes Yes No No No No No No No No No Yes Yes Potential SWW? Do not proceed not Do 2015/16 NOA in featured Not Proceed 2015/16 NOA in featured Not 2015/16 NOA in featured Not 2015/16 NOA in featured Not 2015/16 NOA in featured Not 2015/16 NOA in featured Not 2015/16 NOA in featured Not option THSR) (previously a combined proceed not Do 2015/16 NOA in featured Not 2015/16 NOA in featured Not No Decision Required 2015/16 NOA in featured Not 2015/16 NOA in featured Not 2015/16 NOA in featured Not No decision required 2015/16 NOA in featured Not 2015/16 NOA in featured Not 2015/16 NOA in featured Not 2015/16 NOA in featured Not No Decision Required No Decision Required 2015/16 NOA in featured Not 2015/16 NOA in featured Not 2015/16 NOA in featured Not referred to as ELEU) toas referred Proceed (was previously No decision required No decision required Recommendation NOA 2015/16 2015/16
No decision required No decision required Delay Do not proceed not Do Do not proceed not Do Do not proceed not Do Do not proceed not Do Do not proceed not Do Do not proceed not Do No decision required Proceed Proceed Proceed Do not proceed not Do Do not proceed not Do Do not proceed not Do No decision required No decision required Do not proceed not Do No decision required No decision required Proceed Delay Do not proceed not Do Do not proceed not Do Do not proceed not Do Proceed Proceed Proceed Recommendation NOA 2016/17 98 Chapter five 99 2016/17 2016/17 NOA NOA Recommendation Recommendation Proceed Do not proceed No decision required decision No Proceed No decision required decision No required decision No No decision required decision No Proceed No decision required decision No required decision No No decision required decision No Do not proceed No decision required decision No Proceed No decision required decision No Proceed No decision required decision No Proceed No decision required decision No Do not proceed No decision required decision No Do not proceed Delay No decision required decision No No decision required decision No
2015/16 2015/16 NOA NOA Recommendation Recommendation 2015/16 No decision required decision No Not featured in NOA 2015/16 Not featured in NOA called (previously Proceed SCVC) 2015/16 Delay Not featured in NOA 2015/16 Delay Not featured in NOA 2015/16 Delay Not featured in NOA Delay Do not proceed 2015/16 Not featured in NOA Proceed 2015/16 Not featured in NOA Proceed 2015/16 Not featured in NOA Proceed 2015/16 2015/16 Not featured in NOA Not featured in NOA 2015/16 2015/16 Not featured in NOA Not featured in NOA Delay Delay No decision required decision No SWW? SWW? Potential Potential No No No No No No No No No No No No No No No No No Yes No No Yes No No No No
Option name Option Option name Option 225MVAr MSCs at Burwell Main (BMMS) Bramley to Fleet circuits thermal uprating (BFHW) Reconductor remainder of Bramford to Braintree to (BRRE) route Rayleigh (SCRC) compensation reactive coast East South Reconductor Bramford to Norwich double circuit circuit double Norwich to Bramford Reconductor (NBRE) Bolney and Ninfield additional reactive compensation (BNRC) A new 400kV double circuit between Bramford and (BTNO) Twinstead scheme switching protective compensation Reactive (SEEU) Reconductor remainder of Coryton South to Tilbury (CTRE) circuit Lovedean to Ninfield thermal uprate (LNHW) Reconductor remainder of Rayleigh to Tilbury circuit (RTRE) London South between route transmission 400kV New southand the coast (SCN1/SCN2/SCN3) Reconductor newly formed second Bramford to to Bramford second formed newly Reconductor (RBRE) circuit Main Rayleigh to Braintree Fleet to Lovedean reconductoring (FLRE) Reconductor newly formed second Bramford to Pelham (PRRE) circuit Kemsley to Littlebrook circuits uprating (KLRE) Uprate non-conductor components of Bramford to to Bramford of components non-conductor Uprate (BPEU) circuit double Pelham (HSNO) circuit double new Seabank to Point Hinkley Uprate non-conductor components of newly formed formed newly of components non-conductor Uprate Bramford to Braintree to Rayleigh Main double circuit (RMEU) Reconductor Hinkley Point to Taunton double circuit (THRE) South east to East Anglia HVDC link (SGDC) Alverdiscott to Taunton double circuit thermal uprating (ATHW) Wymondley turn-in (WYTI) turn-in Wymondley Wymondley quad boosters (WYQB) Willesden to Wimbledon 275kV cable Ealing diversion diversion Ealing cable 275kV Wimbledon to Willesden (WEC1) Table 5.11 Table The South region Table 5.10 Table The East region 2017 – January 2016/17 Assessment Options Network Chapter five Investment recommendations The West region Table 5.12 Network OptionsAssessment2016/17 –January2017 Quad booster installation at Cilfynydd (CIQB) Cilfynydd at installation booster Quad (PWTI) North toSwansea turn-in circuit toWalham Pembroke (Hinksey cables) upgrade (HCC1) cables toWalham Cowley and toMinety Cowley remaining overhead line sections (PTRE) the –reconductor circuits toTrawsfynydd Pentir the existing Pentir to Trawsfynydd circuit (PTC2) circuit toTrawsfynydd Pentir existing the on section line overhead an of reconductor and phase per core –second 2cables 1and toTrawsfynydd Pentir per phase (PTC1) phase per core –single replacement 1cable toTrawsfynydd Pentir Pentir to Trawsfynydd second circuit (PTNO) circuit second toTrawsfynydd Pentir Connah’s Quay 1 and 2 circuits (PBRE) 2circuits 1and Quay Connah’s to toBodelwyddan Pentir the of legs Pentir Reconductor Bodelwyddan to Connah’s Quay 1 and 2 circuits (BCRE) 2circuits 1and Quay toConnah’s Bodelwyddan to Pentir the of legs Quay Connah's the Reconductor Severn Tunnel 400kV cable circuit uprate (SEC1) uprate circuit cable 400kV Tunnel Severn North Wales to South Wales HVDC Link (WPDC) Link HVDC Wales toSouth Wales North Wylfa to Pentir second double circuit route (WPNO) route circuit double second toPentir Wylfa Option name
No No No No No No No No No No Yes No Potential SWW? Do not proceed not Do Do not proceed not Do Do not proceed not Do 2015/16 NOA in featured Not No decision required No decision required Delay CPRE) part of combined option (was proceed not Do CPRE) part of combined option (was proceed not Do Do not proceed not Do Do not proceed not Do mean proceed Delay but local conditions Recommendation NOA 2015/16 2015/16
Do not proceed not Do Do not proceed not Do Do not proceed not Do Do not proceed not Do No decision required No decision required No decision required Do not proceed not Do No decision required Do not proceed not Do Do not proceed not Do customer agreement meet to Proceed Recommendation NOA 2016/17 100 Chapter five 101 which which which means that that means which
The option must be new transmission new completely proposes it assets or a complete replacement of assets. transmission The option must be separable assets these between ownership that means and other (existing) assets can be clearly delineated. The option must value be high means that its expected capital of the new assets million is £100 or more. However, not allHowever, options are suitable for as criteria three proposed Ofgem competition. indicators that an option is eligible for onshore competition. The option must fulfil all criteria in order beto considered. EISDs have not been adjusted account to for any time that tendering might take.
. This is with https://www.ofgem.gov.uk/ Overview in Extending Competition the Through we project, (ECIT) Transmission Electricity are working with Ofgem increase to the role bring can this where tendering competitive of value consumers. to will We identify those competitively be could which options onshore tendered (Competitivelya CATO to Appointed be would who Owner) Transmission option. the delivering for responsible proposed on consultation a published Ofgem onshore competitive for arrangements for Arrangements 2015. October in tendering further were regime onshore competitive the on published consultation the in developed and Decision then May 2016 27 the ‘ECIT: on criteria, pre-tender and conflict mitigation 2016. November in published arrangements’ can findYou this document on the Ofgem website publications-and-updates/extending- competition-electricity-transmission- decision-criteria-pre-tender-and-conflict- mitigation-arrangements a view beingto ready run to competitive 2018. in tenders This section eligibility considers options’ the 5.5 Onshore competition for onshore competition. for 2017 – January 2016/17 Assessment Options Network Chapter five Investment recommendations The numberof‘proceed’projectsintheircostbands Table 5.13 project: SWW an of requirements the meet still but capability, boundary provide these of 2, all not Chapter per –as criteria The following projects meet the above provided, which were previously scrutinised. TO(s) have the that costs the We use more. or £100 is million criteria separable and new the capex for the assets which meet the ‘high value’ criterion we assess whether To assess whether the option meets the assets. existing from delineated clearly against whether the new assets can be ‘separable’ criterion, we test the options To assess whether the option meets the assets. existing of replacement the or assets new completely of whether they involve the implementation ‘new’ criterion, we test the options against To assess whether the option meets the analysis Eligibility Network OptionsAssessment2016/17 –January2017 More than £2000m than More £1000m to £2000m to£1000m £100m Cost band
0 1 4 Number of projects
idea of the value of projects. of value the of idea an to give intended are bands The bands. NOA year’s this in ‘proceed’ as recommended been have that Table 5.13 projects of number the shows because options work in combination. options where there are alternatives or multiple cover might case needs SWW An NW Coast Connection (Moorside). Hinkley to (HSNO). Seabank Shetland link. Western Isles link. Orkney link. (OENO). YorkshireCentral reinforcement reinforcement (TLNO). AC England East to North Torness (E2DC). Pit to Hawthorn Torness from Link HVDC subsea Eastern (E4DC). Pit to Hawthorn Peterhead from Link HVDC subsea Eastern in each of several cost cost several of each in
102 Network Options Assessment 2016/17 – January 2017 103 Chapter six
Interconnection analysis 104 Chapter six Interconnection analysis Interconnection analysis provides a view from the market market the from aview provides analysis interconnection The other.the by uninfluenced and independent remain analysis of sets two 5 – Investment recommendations). These Chapter in (presented investments to onshore This interconnection analysis is a parallel process of future interconnection. benefits potential the of industry the inform to undertaken is analysis This scenario. energy each under consumer GB to the benefit most the provides assessment This timing of additional future interconnection. and capacity markets, European the of view European interconnection by providing our assess we way the developed we year This before. than insightful and interconnection analysis to be more ambitious we have developed our methodology for industry, to the information to improve order In project of challenges or risk consider not does and analysis amarket-based is This transmission. system economical ofand electricity coordinated of efficient, an part as interconnector capacity to aims facilitatethis analysis the development of market modelling. output The from our pan-European from analysis our interconnection Chapter 6presents Introduction 6.1 Network OptionsAssessment2016/17 –January2017 Key statistics provides greater lifetimebenefitthanifit Interconnection delivered inearlieryears Gone Green. interconnection ismostbeneficialunder and Floorwindow1projects. However, to European marketsbeyondtheCap can benefitfrom more interconnection Under allscenarios,theGBconsumer
Options Assessment >Network Energy of >Future information) (more Information >Industry Sites > UK www2.nationalgrid.com which is available on the NOA methodology in the methodology document the of details full You find can analysis. our methodology employed and the results of the of asummary gives chapter This onshore investment considerations. to provide designed not is and perspective the onshore networks. on impacts system power nor delivery from increased interconnection. benefit economicallyandenvironmentally Under allscenarios,Europe andGBwould European consumers. greatest opportunityforbothGBand Irish andDanishmarketsprovide the were tobedelivered inlateryears.Icelandic, website. website.
104
Chapter six
105
to cheaper generation with more consumers. consumers. more with generation cheaper to The reduced revenue for generators in the higher priced market who are competing generation. overseas cheaper against the in consumers for price increased The access their share they as market cheaper In turn, SEW must also capture the detriments some that market participants The increase in SEW must alsobe balanced against the capital costs of the delivery of will face which is usually brought about brought usually is which face will means: following the through As capacity. interconnection increased the suitable two between increased is capacity markets and SEW is consequently gained, the prices between the two markets begin further interconnection, Upon converge. to the market prices continue converge to until further interconnection brings no benefit. capacity interconnection the consider then We as ‘optimised’ as the benefits derived from interconnection are at a maximum. GW
GW inGW
and 20.1 GW of interconnectionGW by 2025. Ofgem’s Cap 2025. by and No Progression No 2016, we see an increase 2016, between to suppliers have increased access increased have suppliers generation. renewable cheap to The increased revenue for generators in the lower priced market who now enjoy access to more customers. The created revenue for interconnector businesses who sell capacity across interconnectors. their Greater security of supply – the physical both allows borders across connection markets greater access generation to to needs. energy nation’s their secure Greater access renewable to energy – the increased access to generation delivers generation to access increased the increased allows it as benefit additional renewable intermittent of exploitation displace consequently will This generation. sources. non-renewable domestic increased the – competition Increased more and generation cheaper to access and competition increases consumers allows participants in both markets enjoy to are benefits financial These benefits. financial Welfare. Socio-Economic as measured consumers for price reduced The in the higher priced market as their Consumer Power Consumer Floor window 1 would take this total 11.3 to by 2022. deliver can interconnection in increase This benefitsto the industry and consumer in several ways: ‘Socio-Economic Welfare’ (SEW) is a term which captures the financial benefits and detriments seen market by participants as a Increased interconnection. increased of result SEW is primarily attained through the following: Electricity interconnectors are the physical physical the are interconnectors Electricity networks transmission between connections nations. across electricity of transfer the allowing Currently GB has ~4 our through however, markets European with FES GW 9.6 in 6.2 Interconnection theory 2017 – January 2016/17 Assessment Options Network Chapter six Interconnection analysis Interconnection Current interconnectioncapacitiesand2022basecase Table 6.1 interconnectors transmission-networks/electricity- https://www.ofgem.gov.uk/electricity/ Electricity Interconnectors > Electricity > Transmission Networks> www.Ofgem.gov.uk website. their visit then regime Floor and Cap Ofgem’s about more out to find want you If spread of connection points. adiverse through before, than countries more to connection see may we that suggests also FES The regime. Floor and Cap Ofgem’s of aresult as certainty regulatory to greater due FES with compared increased has FES from capacity interconnector total by FES identified As potential interconnection and Current 6.3 Network OptionsAssessment2016/17 –January2017 Case (GW) Case Base 2022 (GW) Capacity 2016
1 0 Belgium
2016 ETYS and 1 0 Denmark 5.4 2 France 2015. This is 2015. is This 2016, the the 2016, 0 0 Germany 2016 2016 2016 2016
0 0 Iceland in interconnection over the next six years. six next the over interconnection in on time, this will represent a substantial increase connect successfully do projects these all If window. Floor and Cap first Ofgem’s under regulatory approval including acceptance of degrees varying with projects mature includes but regime, Floor and Cap second interconnection going through Ofgem’s planned any include not does table The by 2022. connected to be assumed all this study’s base interconnection capacity, interconnection levels which have formed planned and current Table the 6.1 shows below 1.5 1 Ireland 1 1 Netherlands 1.4 0 Norway 0 0 Spain
11.3 4 Total
106 Chapter six 107 cases GW. An iterativeGW. process then 2. Simulate 3. Create test European markets European www2.nationalgrid.com/ WorkArea/DownloadAsset. aspx?id=8589936185 For each of the energy scenarios, we optimised market using levels interconnection GB the modelling electricity our market within studies softwareBID3. This produced four pictures The interconnection. of level optimal the of market study involved a step-by-step process base a with modelled was market the where current the including interconnection, of level projects mature and levels interconnection totalling 11.3 interconnection additional the where directed should be implemented. This is described in 6.1. Figure 1. Set1. base level website, where where website, additional
4. Simulate 4. with test cases test with interconnection 5. Identify optimal European markets markets European
Iterative process for Interconnection Optimisation Figure 6.1 www2.nationalgrid.com > UK Sites > Industry Information (more information) > Future of Energy > Network Assessment Options you can find further detail on the methodology taken. approach the behind rationale the and The interconnection analysis aims to identify to aims analysis interconnection The nine the across interconnection optimal the European markets for featured 6.1 in Table a selection of study years.The choice of markets and study years were defined during which methodology, the of development the NOA the on available remains 6.4 Methodology 2017 – January 2016/17 Assessment Options Network Chapter six Interconnection analysis Interconnection approximated to allow an estimation of the the of estimation an to allow approximated only. Possible physical landing points were differentials and offshore construction costs This study was driven by wholesale price ofEstimation costs construction 1 Network OptionsAssessment2016/17 –January2017 infrastructure.pdf http://www.acer.europa.eu/Official_documents/Acts_of_the_Agency/Publication/UIC%20Report%20%20-%20Electricity%20 and optimisationprocess completed. When thebasecaseshowedmore SEWthananytestcase,thebasewasconsidered optimal a particularyear. This then formedthebasecasefornextiteration. corresponded directly witha500 The testcasethatresulted inthelargestSEWincrease wasdeemedoptimal.Thetestcase as wastheestimatedcostofconstructionfor500 For eachtestcase,theSEWincrease compared tothebasecasewascalculated, 5. Identifyoptimaladditionalinterconnection simulated. TheSEWassociatedwiththistestwasmeasured. The testcaseswere eachimplementedinamodeloftheEuropean electricitymarkets,andthen 4. SimulateEuropean marketswithtestcases cases fortheninemarkets. in eachofthefourspotyears,creating fourtestcasespermarket,andatotalofthirty-six To testtheimpactofadditional capacityforeachmarket,500 3. Create testcases markets, andthensimulated.TheSEWassociatedwiththisbasewasmeasured. The baselevelofinterconnection wasimplementedinamodeloftheEuropean electricity 2. SimulateEuropean markets level wasdefinedasspecifiedinsection6.3 from 2022onwards. the levelsofinterconnection permarketwere describedoutto2036.Inthefirstiteration,base markets atthestartofiteration.Theyearconnectionwasalsotakenintoaccount,suchthat The baselevelofinterconnection wasthetotalcapacityGBhaswitheachofninestudied 1. Setbaselevel MW of additional capacity to a particular market in MW ofadditionalcapacitytoaparticularmarketin possible cable lengths. median of approximations and projects, European of arange on out carried surveys on a publicly available ACER document from derived were costs capital The CAPEX. MW of capacity introduced in the test case. MW ofcapacityintroduced inthetestcase. MW of interconnection was added MW ofinterconnection wasadded
1 , based , based 108
Chapter six
109
GB consumer benefit. benefit. consumer GB Benefits of overall increase Optimal Path for European SEW. Network and construction constraints have have constraints construction and Network an important and substantial impact on the attractiveness of projects, but these are out of scope for this study. The optimal path followed is the most efficient Other interconnection. optimise to way pathways could result in a higher total level of interconnection, generating similar levels levels similar generating interconnection, of of SEW.
3. 2. interconnection. in The output is presented in three parts: 1. for Gone Green each to European market. capacities interconnection starting The arepresented based on 6.1 in projects Table aiming connect to These 2022. by have regulatory arrangements in place that represent a high level of maturity. This represents a connected, currently is than level higher much convergence price considerable causes which between GB and mainland Europe as seen in the modelling. As the SEW generated by price the on depends interconnection additional difference between GB and European markets, case base the form which interconnectors the SEW additional of level the diminish potentially 6.2 Figure bring. can further interconnection interconnection of level optimal the presents
GW
GW andGW 6 Projects markets to that are not in the optimal paths may well be beneficial, but simply not the most beneficial under the assumptions made in this study. There is more SEW be to captured an by the above interconnection of level increased base levels assumed (presented 6.2), in Table interconnection as reduces SEW the but increases between by 3.5 the future market conditions. market future the The optimal build up from the market perspective is not a forecast; many other factors will also influence the true picture the in emerges that interconnection for years. coming above the base levels. levels. base the above markets different cause scenarios Different beto more or less attractive. This means there is uncertainty as where to the best opportunities lie, driven uncertainty by in This section explores the optimal creation of of creation optimal the explores section This European SEW through the development of scenarios. the of each against interconnection The final result describes the marketsto connect and to, the years connect to in, SEW for each of the test and base cases where presents section This analysed. future interconnection was a benefitto the GB consumer, and Europe to as a whole. 6.5.1 European SEW for path Optimal in order maximise to SEW. The methodology for defining an optimal chosen path development interconnection defines how the results should be interpreted: The market studies undertaken generated generated undertaken studies market The 6.5 Outcome 2017 – January 2016/17 Assessment Options Network Chapter six Interconnection analysis Interconnection Most efficientpathtooptimalinterconnectionpermarket Table 6.2 Table in 6.2. shown is paths interconnection in each of the four optimal The capacity and timing of the additional Optimal levelofinterconnectionunderGoneGreen Figure 6.2 Network OptionsAssessment2016/17 –January2017 Power Consumer Progression No Progression Slow Gone Green Power Consumer Progression No Progression Slow Gone Green Power Consumer Progression No Progression Slow Gone Green i i e
Ireland Iceland Denmark Market e ar ra e 0 0 GW 0.5 + 1.5 GW + 0 1.5 GW + 2 GW + 0 2022/23 er a
0 0 0 1 GW + 0 1 GW + GW 0.5 + 0 2025/26 e a 0 0 0 0 2 GW + 0 0 0 2027/28 re a ether a 1 GW + 2 GW + 0 GW 0.5 + GW 0.5 + GW 0.5 + GW 0.5 + 3 GW + 2030/31 r a 1 GW + 2 GW + GW 0.5 + 3 GW + GW 2.5 + 3 GW + 3 GW + 3 GW + Total pa 110 Chapter six 111 , ,
. Conversely. under Green Gone to any of the nine studied European European studied nine the of any to markets provides savings to the GB consumer to costs wholesale reduced bring would consumer. GB the significant developments in domestic renewable to interconnection in result would generation other markets being substantially less beneficial theto GB consumer, but would instead benefit the connected market. Under Green Gone market Icelandic the to connection only contributions. This leads a fluctuating to Danish differences price market generate can that price and flows in either direction between Denmark and GB. This is a possibility for multiple markets Denmark–GB coupling however region; the in modelling. this under effective most proved generally as modelled is price Irish average The which mechanism second A GB. than higher Ireland’s of alleviation the is welfare generates an is there wherein constraint, synchronous imposed limit on how much demand Irish wind can meet. These effects result in Ireland exports British and curtailing wind, avoid to Britain to flowsto Irelandexploitto arbitrage; both sets of flows generate welfare. Markets not selected this by methodology still showed welfare benefits outweighing estimated costs, however they did not form part of the increased iterations as and path, optimal potential benefits were diminished as prices together closer moved region the throughout interconnection. of levels higher to due
GW and GW
No GW. as GB can import , the Danish market has drove the smallest the drove MW of interconnection GW baseGW level for 2022. , 500 optimising at 17.3 Gone Green Gone No Progression No Under Under energy. renewable cheap Progression The GB consumer stands gain to further from markets wholesale cheaper to interconnection beyond what is captured in the base case. interconnection the includes case base The currently operational and contracted mostly – under Ofgem’s Cap and Floor window 1. Benefitto the GB consumer is most prevalent under 6.5.2 GB benefit consumer interconnection optimising at 14.8 at optimising interconnection Green Gone The four scenarios all showed possible showed all scenarios four The Progression Slow welfare benefits from an increase in capacity above the 11.3 2017 – January 2016/17 Assessment Options Network The optimisation analysis has resulted in resulted has analysis optimisation The a clear indication that Iceland would be the most beneficial market for increased price wholesale effective The interconnection. of electricity is very low in Iceland, due to implies This generation. renewable plentiful exist will opportunities arbitrage price large and be stable in the future, which could such Any welfare. substantial generate increased an in result would interconnection cost for Icelandic consumers; this study has not made any assumptions on how welfare may be redistributed avoid to excessive burdens on any particular group of market participants. Under the lowest average price after the Icelandic future Denmark’s optimised. is interconnection substantial include will balance generation solar and wind large having renewables, Chapter six Interconnection analysis Interconnection generation is underused, due to low internal internal to low due underused, is generation cheap generation. The cheap very Icelandic for access market increased of because is This price. European average the down The additional interconnection drives prices wholesale on impact Overall 6.5.3.1 energy scenarios. four the of each under power renewable of both cheaper wholesale energy and exploitation of terms in consumers European and to GB benefit significant bring paths optimised The Benefits of in interconnection overall increase 6.5.3 Gone Green under decline sharply benefits These markets. European from importing large volumes of renewable power No Progression under prevalent most are consumers GB for benefits scenarios, the Through Average pricedifferencebetweenGBandEuropeanmarkets Figure 6.3 Network OptionsAssessment2016/17 –January2017
i i e ree
where GB would benefit by by benefit would GB where r re as GB’s domestic
r re renewable generation. intermittent more with states future in to arise likely more are prices Volatile opportunities to exploit price differences. more present they as value interconnector more drive often can prices volatile value; higher has term short the in difference price that Note network. European interconnected the forming markets other the and GB in generation to drive down average prices this generation can then displace expensive demand in Iceland. Upon connecting to GB, market. exporting an become it to allow to sufficient are supplies post-2030 as GB’s domestic renewable for interconnection in Gone Green renewable sources grow rapidly. Opportunities C er er C er rise again
112 Chapter six 113 output over over output 2 or eliminate the need for more expensive- which regions, other in technologies to-run increasingly are those which employ fossil fuels. Interconnection the for employed model The as argument; supports this analysis through increased are levels interconnection the iterative process, there is a reduction in Europe-wide need curtail to clean sources of withpower, a resultant drop in CO the study window. study the -£0.76 -£0.71 -£0.32 -£0.61 £19bn £18bn £15bn £18bn
Impact on European Welfare European on Impact Green Gone Average Price change across Europe Europe across change Price Average perMWh Green Gone Progression Slow Progression No Power Consumer Progression Slow Progression No Power Consumer These price changes, combined with the the with combined changes, price These different total demands behind each scenario, shown as welfare European overall large drive 6.4. in Table implications 6.5.3.2 Environmental Interconnectors can increase access to Interconnection power. of sources renewable allows surplus power be to exported, rather than curtailed. This exported power can reduce Table 6.4 Table Combined increases in welfare (including netting off Capex spend) for all years, all Europe welfare (including netting off Capex spend) for Combined increases in Table 6.3 Table in wholesale energy prices for the European consumer reduction Average 2017 – January 2016/17 Assessment Options Network Chapter six Interconnection analysis Interconnection Reduction inCO Figure 6.4 i i s s Network OptionsAssessment2016/17 –January2017
a e a e 2 outputunderoptimisedpath
pt e ssi
a e a e
pt e ssi
a e a e
pt e s
a e a e
pt e 114 Chapter six 115
The market study showed that there are economic and environmental benefits yet to be unlocked through interconnection. interconnection. through unlocked be to network physical the that challenges The presents, the uncertainty in the future state of interconnection’s and markets, power Europe’s other avenues for creating value mean these outcomes do not present the complete picture, worthwhile remains it that suggest does it but GB’s increase to opportunities investigate to portfolio. interconnection
Interconnection continues to present an present to continues Interconnection Europe for value creating opportunity for 6.6 Summary and GB as a whole, allowing by for the more efficient dispatch of Europe’s generation to lead to potential the has This portfolio. savings for consumers, extra profits for generators and a good business case increasing by However, developers. for closer prices market pulling and competition together, there can be a detriment current to engineering The participants. market complexity of subsea cables leads a to must which construction, of cost substantial be recoverable support to any such projects. and design identification, the Additionally to reinforcements onshore of construction facilitate interconnector flows adds another cost. and complexity of dimension 2017 – January 2016/17 Assessment Options Network Chapter six Network OptionsAssessment2016/17 –January2017 116 Chapter seven 117 118
Stakeholder engagement
seven Chapter Chapter 2017 – January 2016/17 Assessment Options Network Chapter seven know what you need. in our 2017 we so programme engagement stakeholder publication We’d like your this on NOA comments feedback and Introduction 7.1 Stakeholder engagement Network OptionsAssessment2016/17 –January2017
and your and help to improve take Please it. part
118 Chapter seven 119
in March 2016, publication. annual review process will help us NOA The cost–benefit process in our methodology have We chapter. now made these changes and would like hear to more about how we see how the publication fits into the wider we So, publications. SO of collection which you can find Youon 7–8.pagesalso wanted us explain to more about the can improve the NOA develop the publication. We’ll encourage all all encourage We’ll publication. the develop interested parties get to involved, which will help us improve the publication every year. After we published the first NOA we received some very helpful feedback. For example, you told us you wanted to developed a simple explain way to this,
publication continues continues publication . And because the two and the ETYS identifying and understanding ouridentifying understanding and opinions and views stakeholders’ constructive for opportunities providing process the throughout debate creating open and two-way communication discuss to stakeholders our with and outputs and drivers assumptions, been have views your how you telling considered and reporting on the process. engagement Your feedbackYour is an important part of the the developing and revising continue we way NOA 7. 2 Continuous development 2017 – January 2016/17 Assessment Options Network documents are closely related, make we’ll sure that the way we communicate and consult with you reflects this. make sureWe’ll the NOA to addto value by: Chapter seven ETYS/NOA stakeholderactivitiesprogramme Figure 7.1 as the publication and its contents. centre around the methodology as well to May early 2017. This consultation will now from you with conversations to having forward looking are we and process review NOA the that Now views: to your to listen happy always We are Stakeholder engagement 3 7. Stakeholder engagement Network OptionsAssessment2016/17 –January2017 published Jan through any means most convenient for you. for convenient most means any through at bilateral stakeholder meetings and nationalgrid.com through responses to transmission.etys@ at operational forums customer seminars our of part as events consultation at 2016/17 2016/17 Report Report NOA NOA (end January to early May) to early January (end
Feb Stakeholder comments is published we’ll start the the we’ll start published is Internal review Mar Apr May
published FES Jun 2017 2017 publication to meet your needs? NOA the improve we can Where Jul and form to Ofgem form and NOA Aug methodology Sep Oct ETYS published 2017 2017 Nov 120 Chapter eight 121 141 142 146 122
submissions may be made in the next to 24 12 months only.
Appendix C – List of options’ four-letter codes four-letter Appendix options’ C – List of Appendix D – Glossary Disclaimer151 team Appendix B – Meet NOA the This appendix contains summaries of SWW projects for which needs case Appendix A – SWW projects
eight Chapter Chapter 2017 – January 2016/17 Assessment Options Network Chapter eight given below. are considered options the of Details the options include: The factors taken into account in developing Islands. Shetland the on supply of security the to improve help also would reinforcement island generation. The Shetland Link the of connection the to facilitate order in between Shetland and the Scottish mainland considered to provide transmission capacity been have options reinforcement of A number 2. MITS. GB the into export facilitate to required be will mainland Scottish to the alink projects these of aconsequence As to 200 up of projects connection interests from developers of renewable energy further are There Voe Terminal. Sullom the from 15 and Station Power Lerwick 67 excludes This connected and contracted for connection. 488 of atotal is There (MITS). Main Interconnected Transmission System connection between Shetland and the GB no is there At present projects. wind onshore in to invest seeking developers by targeted been have which resources renewable attractive possesses Shetland 1. Link Shetland 8.1 projects SWW A Appendix Network OptionsAssessment2016/17 –January2017 Background Option development Option on the island). renewables in growth future for potential Capacity (MW rating including the Current (AC) technology). (HVDC) technology versus Alternating Technology (High Voltage Direct Current mainland). UK the on MITS the and Shetland Corridor (the geographical route between MW of diesel generation at at generation diesel of MW MW generation generation MW MW of export export of MW MW.
a600 and a 600 and a 132kV substation AC GIS includes the Blackhillock substation in Moray. The work connection between Shetland (at Kergord) and 600 a343km, Construct (c) 450 a and a 132kV substation AC GIS includes work The scheme. HVDC terminal a three to form Caithness) (in Head Noss at Station Switching 2018 HVDC in the via completed be to due link HVDC –Moray Caithness the and connection between Shetland (at Kergord) 450 a278km, Construct (b) a 600 Insulated Switchgear (GIS) substation and a132kV AC Gas includes work The scheme. HVDC terminal athree to form Caithness) (in Head Noss at Station Switching HVDC the 2018 in via completed to be due link HVDC Shetland (at Kergord) and the Caithness–Moray Converter (VSC) HVDC connection between 600 a278km, Construct (a) Options 2.1 EISD: 2021 EISD: 600 Shetland–Moray 2021 EISD: 450 Caithness–Shetland 2021 EISD: 600 Caithness–Shetland MW VSC HVDC converter at Kergord. at converter HVDC VSC MW MW VSC HVDC converter at Kergord Kergord at converter HVDC VSC MW Kergord. at converter HVDC VSC MW MW converter at Blackhillock. at converter MW MW HVDC Link, Link, HVDC MW MW VSC HVDC HVDC VSC MW MW Voltage Sourced Sourced Voltage MW MW VSC HVDC HVDC VSC MW
MW HVDC Link, MW HVDC Link,
122 Chapter eight 123
on the future subsidy 1 consenting activities. Preparation of Needs Case and Project Assessment submissions. engagement. stakeholder of Continuation Progression of key planning and planning key of Progression 2.3 Status On 9 November BEIS published 2016 an industry consultation regime for onshore wind projects located consultation The islands. Scottish the on Dependingcloses January on 31 2017. of the optioneering exercise may need to on the outcome of the consultation, the the consultation, the of outcome the on part as out carried assessment economic accordingly. revised be The key project milestones will be reviewed and of outcome the when accordingly amended current the meet To known. is consultation the Shetland Link target completion date of 2021, it is expected that the Contracts for Difference would eligibility process application and (CfD) be completed allow to approval mid-2017 by of the Needs Case and Project Assessment during Construction the third quarter of 2017. work would be expected start to at the end of first quarter Over the 2018. of next six months include: activities key the
MW HVDC MW HVDC Link MW HVDC Link HVDC MW
MW HVDC Link is identified as the least https://www.gov.uk/government/consultations/consultation-on-treatment-of-non-mainland-gb-onshore-wind-projects 1 worst regret option. The optioneering work will need be to revisited Government UK the of conclusion the when Industrial & Energy Business, for Department Strategy (BEIS) consultation is known. This may result in an alternative least worst regret option. reinforcement is more than recovered by high the under costs constraint in reductions the therefore and scenario penetration wind 600 Link option would leave too much generation generation much too leave would option Link large a is there when constrained being The islands. the on wind of penetration additional cost of the 600 2.2 option Lead was that exercise optioneering an Following undertaken identify to the mosteconomic, efficient and coordinated option, the Caithness–Shetland 600 option was identified as the lead option. This is because there are high wind load factors on Shetland and the 450 2017 – January 2016/17 Assessment Options Network Chapter eight given below. are considered options the of Details options include: factors taken into account in developing the The islands. the on supply power of security the to improve help also would reinforcement of the islands’ generation. The Orkney Link mainland in order to facilitate the connection Scottish the and Orkney between capacity considered to provide additional transmission been have options reinforcement of A number 2. MITS. GB the into export to facilitate required be will mainland Scottish to the link capacity ahigher projects these of aconsequence As is assessing. Hydro Electric Power Distribution (SHEPD) from embedded generators that Scottish 324 are there addition In capacity is contracted for connection. 460 of Atotal (MITS). System and the GB Main Interconnected Transmission Orkney between capacity 23MVA firm with connections cable subsea 2x33kV are there At present projects. wind onshore and marine particular in to invest, seeking developers by targeted been have which resources renewable attractive possesses Orkney 1. Link Orkney 8.2 projects SWW A Appendix Network OptionsAssessment2016/17 –January2017 Background Option development Option on the islands). renewables in growth future for potential Capacity (MW rating including the Current (AC) technology). (HVDC) technology versus Alternating Technology (High Voltage Direct Current mainland). UK the on MITS the and Orkney Corridor (the geographical route between MW of enquiries enquiries of MW MW generation generation MW
via new 132kV substations. interface with the local Orkney infrastructure will cables the Hoy and Skaill of At Bay Islands. Orkney the on Hoy of south the and Dounreay between 40km approximately cable a220 and Skaill of Bay and approximately 70km between Dounreay a200 Install (d) infrastructure via a new 132kV substation. Orkney local the with interface will cable the At Hoy Islands. Orkney the on Hoy of south the and Dounreay between 40km approximately a220 Install (c) infrastructure via a new 132kV substation. Orkney local the with interface will cable the on the Orkney Islands. At South Ronaldsay Bay 132kV substation and South Ronaldsay Gills planned the between 34km approximately a220 Install (b) 132kV substation. the local Orkney infrastructure via a new with interface will cable the Skaill of At Bay Islands. Orkney the on Skaill of Bay and approximately 70km between Dounreay a200 Install (a) Options 2.1 South Hoy subsea links: 2022 Dounreay to Bay of Skaill and Dounreay to to Dounreay and Skaill of to Bay Dounreay 2022 EISD: Dounreay to South Hoy Subsea Link, 2022 EISD: Gills Bay to South Ronaldsay Subsea Link, EISD: 2022 EISD: Link, Subsea Skaill of to Bay Dounreay MW AC subsea cable cable AC subsea MW cable AC subsea MW MW AC subsea cable cable AC subsea MW MW AC subsea cable cable AC subsea MW MW AC subsea AC subsea MW
124
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125 Conclusion of optioneering exercise. optioneering of Conclusion and planning key Commencement of consenting activities. engagement. stakeholder of Continuation In order meet to the current Orkney Link target completion date it of 2022, is expected that the CfD would eligibility process application and be completed allow to approval in 2017 of the Assessment during Project and Case Needs expected be would work Construction 2019. startto in Over 2020. the next six months the include: activities key
closes 2 https://www.gov.uk/government/consultations/consultation-on-treatment-of-non-mainland-gb-onshore-wind-projects 2 An optioneering exercise is underway to identify the mosteconomic, efficient and The option. development coordinated impact considers the exercise optioneering island the on points landing cable the of infrastructure. A cost–benefit analysis(CBA) will also be undertaken in line with the Western Isles and ShetlandCBAs carried out the by informSO to the preferred option. 2.2 Status On the 9 November the BEIS published 2016 subsidy future the on consultation industry an regime for onshore wind projects located on consultation The islands. Scottish the 2017 – January 2016/17 Assessment Options Network on 31 January 2017. Januaryon 31 2017. The CBA for the Orkney Link will take into government the of outcome the account auction. CfD 2017 April the and consultation The latter will inform the future volume of wave generation. tidal and Chapter eight given below. are considered options the of Details in developing the options include: account into taken factors The Isles. Western the on supply of security the to improve help also would reinforcement Link Isles Western connection of the island generation. The the to facilitate order in mainland Scottish the and Isles Western the between capacity developed to provide additional transmission been have options reinforcement of A number 2. Interconnected Transmission System (MITS). Main GB the into export to facilitate required be will mainland Scottish to the link capacity ahigher projects these of aconsequence As for connection. connected, under construction or contracted 380 of Scottish mainland with a restricted 132kV connection to the operates system Isles Western existing the At present projects. generation marine and developers to seeking invest in onshore wind by targeted been have which resources renewable attractive possess Isles Western The 1. Western Link Isles 8.3 projects SWW A Appendix 3 Network OptionsAssessment2016/17 –January2017 Single circuit connection from Fort Augustus which includes a 33kV section between Ardmore – Harris. Background Option development Option on the island). renewables in growth future for potential Capacity (MW rating including the Current (AC) technology). (HVDC) technology versus Alternating Technology (High Voltage Direct Current on the UK mainland). MITS the and Isles Western between Corridor (the geographical route MW is made up of generation either either generation of up made is MW 3 . A total generation capacity capacity generation . Atotal
Construct a 300 (a) Options 2.1 Lewis infrastructure via a132kV substation. via GIS infrastructure Lewis local the with interface will circuit the At Arnish substation. GIS a400kV via MITS GB the with interface will circuit the At Beauly Arnish. and Beauly at located be will stations converter 450 The cable. Arnish) and Dundonnell between (79km offshore and Dundonnell) and Beauly between (77km onshore of amix be will circuit The Scotland. of coast west the on Dundonnell via Lewis of Isle the of coast east the on Arnish and Inverness) of west north (located mainland Scottish the on Beauly Converter (VSC) HVDC connection between a450 Construct (b) a132kV substation. via GIS infrastructure Lewis local the with interface will circuit the At Arnish substation. GIS a400kV via MITS GB the with interface will circuit the At Beauly Arnish. and Beauly at located be will stations converter 300 The cable. Arnish) and Dundonnell between (79km offshore and Dundonnell) and Beauly between (77km onshore of amix be will circuit The Scotland. of coast west the on Dundonnell via Lewis of Isle the of coast east the on Arnish and Inverness) of west north (located mainland Scottish the on Beauly Converter (VSC) HVDC connection between Link, EISD: 2021 EISD: Link, 300 Beauly–Dundonnell–Arnish Link, EISD: 2021 EISD: Link, 450 Beauly–Dundonnell–Arnish
MW Voltage Sourced Sourced Voltage MW MW Voltage Sourced
MW HVDC HVDC MW MW HVDC MW MW MW MW
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127
closes January on 31 2017. 4 Conclusion of tender negotiations. tender of Conclusion and planning key of Progression consenting activities. Preparation of Needs Case and Project Assessment submissions. engagement. stakeholder of Continuation on the future subsidy regime for onshore wind projects located on the Scottish Islands. 2.3 Status On 9 November the UK Government 2016 Industrial & Energy Business, for Department industry published an consultation Strategy consultation The Depending on the outcome of the consultation, consultation, the of outcome the on Depending part as out carried assessment economic the of the optioneering exercise may need be to revised accordingly inform to the selection of the preferred option. The key project milestones will be reviewed and amended accordingly when the outcome outcome the when accordingly amended and of the consultation is known. In order to meet the current Western Isles Link target completion it is expected date of 2021, that the be CfD would eligibility process application and completed allow to approval mid-2017 by of the Assessment during Project and Case Needs Constructionthe third quarter work of 2017. would be expected start to in the first quarter Over the nextof 2018. six months the key include: activities
MW MW HVDC MW HVDC MW Voltage Sourced Link, EISD: 2021 Beauly–Dundonnell–Arnish 600 https://www.gov.uk/government/consultations/consultation-on-treatment-of-non-mainland-gb-onshore-wind-projects 4 an alternative least worst regret option. regret worst least alternative an Construct a 600 Converter (VSC) HVDC connection between between connection HVDC (VSC) Converter Beauly on the Scottish mainland (located north west of Inverness) and Arnish on the east coast of the Isle of Lewis via Dundonnell on the west coast of Scotland. The circuit will be a mix of onshore (77km between Beauly and Dundonnell) and offshore (79km between Dundonnell and Arnish) cable. The 600 Link. The is TO currently undertaking a retender exercise for provision of the HVDC Link. The optioneering work will need be to revisited when this is concluded. This may result in (c) converter stations will be located at Beauly and Arnish. Beauly At the circuit will interface with the GB MITS via a 400kV GIS substation. ArnishAt the circuit will interface with the local Lewis infrastructure GIS via substation. a 132kV 2.2 option Lead undertaken was exercise optioneering An identifyto the most economic, efficient and on Based option. development coordinated the latest analysis that is not yet completed, the current lead option is the 450 2017 – January 2016/17 Assessment Options Network Chapter eight (EISD) of 2024. of (EISD) date in-service earliest an to maintain year this process is to progress this reinforcement in 2016 the from NOA recommendation The (B6). NGET and (SPT) Transmission SP between and SHE Transmission and SP Transmission (B4) England. This includes key between boundaries of north the in area (NGET) Transmission Electricity Grid B7a and National the area in Electric Transmission (SHE Transmission) Hydro Scottish B1 the in boundaries between and England northern Transmission system Scottish the of capability transfer to south north the to E4DC of increase is objective The on either end. England, with associated AC onshore works East North in Pit Hawthorn and Scotland East 2 option (E4DC) involves the construction of a reinforcement Pit to Hawthorn Peterhead from Link HVDC subsea Eastern the of scope The 1. Pitto (E4DC) Hawthorn Link Peterhead subsea from HVDC Eastern 8.4 projects SWW A Appendix 6 5 Network OptionsAssessment2016/17 –January2017 The Required Transfer figures shown take into account interconnectors connecting to the GB Transmission system in the 2016 the in system GB the Transmission to connecting Future Energy Scenarios interconnectors account into take shown figures Transfer Required The Owners have licence obligations to develop their transmission systems in accordance with the NETS SQSS. The NETS SQSS is the National Electricity Transmission System Security and Quality of Supply Standard. GB Transmission GW HVDC link between Peterhead in North North in Peterhead between link GW HVDC Background .
Figure 8.2 show the Required Transfers Required the show 8.2 Figure 8.1 Figure and Forth. of Firth the in and Firth offshore windfarms situated in the Moray SHE Transmission and SPT areas, including of predominantly renewable generation in the growth by the fundamentally driven is network The requirement to reinforce the transmission obligations in their transmission licences. pursuant to the Transmission Owners’ reinforcement. network further for arequirement shows Required Transfers and the network capability reinforcements. The difference between the approved for increases capability as well capabilities across the two boundaries as network current the show also figures The (FES) Scenarios 2016 Energy the in Future scenarios four the for B6 and B4 boundaries accordance with the NETS SQSS NETS the with accordance This reinforcement option is proposed in
5 and and 6 for for
. 128 Chapter eight 129 C er er C er er r re r re r re r re
e ree e e ree e ar Capa t a e Capa t
Figure 8.2 capability Boundary B6 (SPT/NGET) required transfer and Figure 8.1 SPT) required transfer and capability Boundary B4 (SHE Transmission/ 2017 – January 2016/17 Assessment Options Network Chapter eight across boundaries B1, B1a, B5. boundaries B2, and B4 across provides additional transmission capacity at Longannet. This reinforcement option and Longannet, and uprate the cable sections Westfield Tealing, between 275kV circuits the re-profile Blackhillock, at transformers shifting Kincardine for 400kV operation, install phase and Alyth Fetteresso, Kintore, Rothienorman, the 275kV circuits between Blackhillock, re-insulate Alyth, and Kintore Rothienorman, Establish new substations 400kV at (c) B1, B1a, boundaries B2, B4. across capacity option provides additional transmission transformers at Blackhillock. This reinforcement 400kV operation and install phase shifting for Kincardine and Alyth Fetteresso, Blackhillock, Rothienorman, Kintore, re-insulate the 275kV circuits between uprate substation Alyth for 400kV operation, Kintore, and Rothienorman at substations Following ECU2, establish new 400kV (b) B1, B1a, B5. boundaries B2, and B4 across provides additional transmission capacity and Longannet. This reinforcement option Westfield Tealing, Alyth, between 275kV circuits Kintore, and Kincardine and Alyth uprate the between circuits the 275kV re-profile Alyth, at compensation reactive shunt and Fiddes at Fiddes, including phase transformers shifting and Alyth at 275kV substations new Establish (a) Options 2.1 consider onshore and offshore solutions. B1 to B7a. options These boundaries across developed which improve capability boundary been have options reinforcement of A number 2. projects SWW A Appendix Network OptionsAssessment2016/17 –January2017 Option development Option (ECU4) (ECU4) East Coast onshore 400kV reinforcement reinforcement (ECUP) East Coast onshore 400kV incremental East Coast onshore 275kV upgrade (ECU2) route through the Scottish central belt. a to fourth north south double circuit Supergrid establish to sites associated reconfigure and to Newarthill Bonnybridge from line overhead Construct a new 400kV double circuit (f) B7a. and B7 transmission capacity across boundaries B6, This reinforcement option provides additional area. the in works reconfiguration circuits Hawthorn Pit–Norton circuit and associated the of uprating substation, GIS Pit Hawthorn 400kV anew include Pit Hawthorn at works ‘Branxton Converter Station’. The AC onshore to the connection to provide bays GIS 400kV by two substation’ 400kV ‘Branxton existing pre- the of extension include end Torness the of vicinity the in works AC onshore The Pit. Hawthorn and Torness at AC works associated Pit, including AC/DC converter stations and to Hawthorn area Torness from link subsea 2 offshore anew Construct (e) B1a, B7, B2, B6, B5, B4, B2a, B7a. and transmission capacity across boundaries B1, This reinforcement option provides additional area. the in works reconfiguration circuits Hawthorn Pit–Norton circuit and associated the of uprating substation, GIS Pit Hawthorn 400kV anew include Pit Hawthorn at works route to 400kV operation. The AC onshore the Blackhillock–Rothienorman–Peterhead the upgrade of the 275kV circuits along include end Peterhead the at works onshore AC The link. the of ends Pit Hawthorn and Peterhead the at works AC onshore AC/DC converter stations and associated to Hawthorn Pit (north of England), including Scotland) of east (north Peterhead from link 2 offshore anew Construct (d) Denny–Wishaw 400kV Reinforcement 400kV Denny–Wishaw (E2DC) HVDC Offshore Pit to Hawthorn Torness Link: to England Scotland Eastern (E4DC) Pit to Hawthorn Peterhead from Link HVDC subsea Eastern GW HVDC GW HVDC subsea GW HVDC 130
Chapter eight
131 though though scenario. scenario. that the that Eastern Scotland England to Link: Torness Hawthornto Pit Offshore HVDC (E2DC) Eastern Scotland England to Link: Torness Northto East England double circuit (TLNO) (b) critical a is TLNO that showed analysis The reinforcement Progression for Slow not the other scenarios. TLNO has a late EISD which prevents it from having a larger impact but front end costs are As a result low. the regrets are low for TLNO and it has a ‘proceed’ open. option the keeps which recommendation (c) The analysis showsthat E2DC is a critical reinforcement for Green the Gone As per the regret analysis, E2DC has a included not is It recommendation. ‘proceed’ in the other three scenarios as part of their optimal paths. E2DC provides capacity B6 to and allows B7a forto additional capacity be to realised from other reinforcements which as a group facilitates for positive economic benefit. Status survey and routeing cable Preliminary subsea further however out, carried been have be will surveys environmental and technical 400kV the for permission Planning required. substation at Peterhead has been granted and a preferred location for the convertor station at Peterhead has been identified. Design checks will be required for increasing the operating Peterhead between line overhead the of voltage Blackhillock. Further preliminary at and works the Hawthorn Pit end of the link will be required in requirements of details establish the to the area. It is expected in this NOA construction of the HVDC project will take place between 2022 and 2024.
where where scenario used. scenario No Progression No except scenario to Northto East England double circuit (TLNO) Eastern subsea HVDC Link from Peterhead Hawthornto Pit (E4DC) Eastern Scotland England to Link: Torness scenarios. It is a critical reinforcement in each FES Install a new double circuit overhead line from a new 400kV substation in the Torness area to system transmission the on point connection a in North East England. Construct a new 400kV overhead line from the Torness area the to SPT/ the of construction Continue border. NGET North in point connection suitable a into OHL substation additional providing England, East reinforcement This required. where equipment capacity thermal additional provides option across boundaries and B6, B7 B7a. 2.2 options Lead (a) In an optioneering exercise identify to the most economic, efficient and coordinated development option, is E4DC found be to an economic reinforcement in all of the four FES One side of the new overhead line will be operated at 400kV, the other at 275kV. establish Denny– will reinforcement This Wishaw– Bonnybridge–Wishaw, Bonnybridge, Strathaven No.2 and Wishaw–Torness 400kV Denny–Newarthill–Easterhouse a and circuits, option reinforcement This circuit. 275kV capacity transmission additional provides boundary B5. across (g) the optimal timing of the build is two years after its EISD. isE4DC a justified reinforcement as it provides capability across boundaries In B7a. to B1 order getto the full benefitE4DC of across all including reinforcements, other boundaries, ones for the B8 boundary, must be built. Note reinforcements of combination exact the that varies depending on the FES 2017 – January 2016/17 Assessment Options Network Chapter eight (EISD) of 2024. of (EISD) date in-service earliest an to maintain year coming the in reinforcement this to progress is 2016 the from NOA recommendation Electricity Transmission area. (NGET) The Grid B7a and National the area in (SPT) between boundaries B6 in the SP Transmission and England northern Transmission system Scottish the of capability transfer to south north the to increase is E2DC of objective The terminals. both at works reinforcement East England, with associated AC onshore North in Pit Hawthorn and Scotland East South in area Torness between circuit HVDC a2 of 200km approximately of Hawthorn Pit (E2DC) entails the construction to Torness from Link HVDC Offshore England to Scotland Eastern the of scope The 1. (E2DC) HVDC Pitto Offshore Hawthorn Scotland to Link: Torness England Eastern 8.5 projects SWW A Appendix 8 7 Network OptionsAssessment2016/17 –January2017 The Required Transfer figures shown take into account interconnectors connecting to the GB Transmission system in the 2016 the in system GB the Transmission to connecting Future Energy Scenarios interconnectors account into take shown figures Transfer Required The Owners have licence obligations to develop their transmission systems in accordance with the NETS SQSS. The NETS SQSS is the National Electricity Transmission System Security and Quality of Supply Standard. GB Transmission Background . GW VSC GW VSC process process depicts the Required Transfers 8.3 Figure areas. SPT and Transmission SHE of predominantly renewable generation in the growth by the fundamentally driven is network The requirement to reinforce the transmission obligations in their transmission licences. pursuant to the Transmission Owners’ further networkfurther reinforcement. for arequirement shows capability network the and Transfers Required the between for approved reinforcements. The difference increase capability as well as B6 boundary the across capability network current the (FES) Scenarios Energy 2016 the in Future scenarios four the for B6 accordance with the NETS SQSS NETS the with accordance This reinforcement option is proposed in . The figure also shows shows also figure . The
8 on boundary on boundary 7 and and
132 Chapter eight
133 GW HVDCGW C er er Eastern Scotland England to Link: Torness Hawthornto Pit Offshore HVDC (E2DC) r re of the Hawthorn Pit–Norton circuits from associated and operation, 400kV to 275kV circuits reconfiguration works in the area. This reinforcement option addresses the with associated limitations voltage and thermal B2a, B4, B5, B6, B2, boundaries B7, B1a, B1, and B7a. (b) Construct a new offshore 2 subsea link from Torness area Hawthorn to and stations converter AC/DC including Pit, associated works AC at Torness and Hawthorn Pit. The onshore AC works in the vicinity of the Torness end include establishment of a onshore AC The Station. Converter 400kV works at Hawthorn Pit include a new 400kV Hawthorn Pit GIS substation, uprating of one of the Hawthorn Pit–Norton circuits from associated and operation 400kV to 275kV circuits reconfiguration works in the area. additional provides option reinforcement This B6, boundaries across capacity transmission B7 and B7a. GW HVDCGW subsea r re
e ree e ar Capa t
Eastern subsea HVDC Link from Peterhead Hawthornto Pit (E4DC) Option Option development link from Peterhead (north east of Scotland) including England), of (north Pit Hawthorn to associated and stations converter AC/DC onshoreAC works at the Peterhead and Hawthorn Pit ends of the link. The AC onshore works at the Peterhead end include along circuits 275kV the of upgrade the Blackhillock–Rothienorman–Peterhead the onshore AC The operation. 400kV to route works at Hawthorn Pit include a new 400kV Hawthorn Pit GIS substation, uprating of one 2. A number of reinforcement options have been boundary capability improve which developed across boundaries Due the to broad B6 B7a. to nature of the reinforcement requirement, a full options potential all of assessment and review for providing capacity these to boundaries will be required for which the following identified onshore and offshore options will be included. 2.1 Options (a) Construct a new offshore 2 Figure 8.3 required transfer and capability Boundary B6 (SPT/NGET) 2017 – January 2016/17 Assessment Options Network Chapter eight reinforcement for the Gone the Green for reinforcement a critical is E2DC that shows analysis The (c) recommendation which keeps the option open. a‘proceed’ has it and TLNO for low are regrets the low. aresult As are costs end front but impact alarger having from it prevents which EISD alate has TLNO scenarios. other the not Slow for Progression reinforcement The analysis showed that TLNO is a critical (b) varies depending on the FES the on depending varies that the exact combination of reinforcements Note built. be must boundary, B8 the for ones boundaries, other reinforcements, including all across of E4DC benefit full the to get order B1 to B7a. In boundaries across capability provides it as reinforcement ajustified E4DC is EISD. its after years two is build the of timing optimal the FES each in reinforcement acritical is It scenarios. FES four the of all in reinforcement economic an to be found E4DC is option, development coordinated and efficient economic, most the to identify exercise optioneering an In (a) Lead options 2.2 B7a. B7 B6, and boundaries across option provides additional thermal capacity equipment where required. This reinforcement East England, providing additional substation OHL into a suitable connection point in North NGET border. Continue construction of the SPT/ to the area Torness the from line overhead 400kV anew Construct England. East North in a connection point on the Transmission system to area Torness the in substation 400kV a new from line overhead circuit double anew Install (c) projects SWW A Appendix Network OptionsAssessment2016/17 –January2017 to Hawthorn Pit Offshore HVDC (E2DC) HVDC Offshore Pit to Hawthorn Torness Link: to England Scotland Eastern (TLNO) circuit double England East to North Torness Link: to England Scotland Eastern to Hawthorn Pit (E4DC) Pit to Hawthorn Peterhead from Link HVDC subsea Eastern EastNorth England double circuit (TLNO) to Torness Link: to England Scotland Eastern scenario except No Progression scenario used. scenario. though where
more would be practicable. or one that determined was it and investigated were corridors route broad of Anumber future. the in England and Scotland between capacity credible design option for providing additional a as considered be should reinforcement assessment concluded that an onshore This England. East to North Scotland East for potential onshore routes from South A feasibility assessment has taken place 2024. and 2022 between place take will project HVDC NOA2 in expected is It area. the in requirements of details the to establish required be will link the of end Pit Hawthorn the at works preliminary Further the potential impacts. a subseaidentify route cable which minimises studies and mitigation solutions are required to route corridor options. Further environmental to the proximity in area the including Torness constraints in the coastal area surrounding environmental significant of anumber are There identified. to yet be cable apreferred with stage, optioneering route to the progressed been have cable subsea to the relating Studies more detail. in considered to be require will sites These the development of all required infrastructure. for identified been have points landing cable potential five with together sites potential Six area. Torness the within infrastructure onshore sites to accommodate transmission consider the potential for the development of Assessment has been carried out to StrategicA preliminary Environmental Status benefit. economic positive for facilitates group a as which reinforcements other from realised to be capacity additional to for B7a allows and to B6 capacity provides E2DC paths. optimal their of part as scenarios three other the in ‘proceed’ recommendation. It is not included a has E2DC analysis, regret the per As that the construction of the 134 Chapter eight
. 9 135
In June 2015, NationalIn June 2015, Grid concluded option connection preferred the that would be made up of an onshore double double onshore an north and circuit circuit south with a tunnel crossing underneath Morecambe These Bay. options will require the removal of an operated line overhead 132kV existing Electricityby North West Limited. This option is also supported the by cost– benefit analysis studies that have been that demonstrate which undertaken, the Scenarios Energy Future the across (outlined option connection preferred above) is theleast worst regret option. through robust remained has option This has which analysis sensitivity of range a uncertainties various at looking involved timing. generation wider as such At theAt early stages of the project National Grid identified several possible strategic connection a deliver could that options to consideration gave and Moorside, to To technologies. connection feasible the Grid National options strategic the assess studies offshore and onshore undertook identifyto potential route corridors for assessed These were circuits. new the against a number of factors in accordance with National Grid’s licence obligations, obligations, licence Grid’s National with assessment the on further information and in found be can conclusions and Corridor Route Proposed of Statement circuits are required to ensure a NETS a ensure to required are circuits connection. compliant SQSS National Electricity Transmission System System Transmission Electricity National Security and Quality of Supply Standard for connection compliant SQSS) (NETS that determined analysis This Moorside. a minimum of four new transmission Project Project Development 2.3.2 2.3.2 2.3 2.3.1
.
.
MW MW
MW units to . NOA The potential need for this project is 3,387 proposed NuGen’s by driven This project is being developed under the current Strategic RIIO-T1 Wider Works (SWW) framework, which means that information is published as part of the Ofgem between process assessment information Further Grid. National and about this project and other SWW can be found on Ofgem’s website here https:// www.ofgem.gov.uk/electricity/ transmission-networks/critical- investments/strategic-wider-works power station at Moorside near Sellafield station power proposed The Cumbria. in would consist ofthree 1,129 be connected sequentially2025, in 2024, and 2026. Ofgem is already consulting on the is due close to after the publication of this Initial Needs Case and the consultation consultation the and Case Needs Initial The proposed project has been subject to information so consultation public extensive http://www. through available is northwestcoastconnections.com/ National Grid carried out power system system power out carried Grid National analysis identify to the minimum level of a provide to required reinforcement There is no existing transmission proposed the of vicinity the in infrastructure are There location. station power Moorside existing distribution network assets in this area but these do not have the capacity to Moorside’s of connection a accommodate size. It was therefore concluded that new required. be would circuits transmission Options Options assessment Background Statement of Proposed Route Corridor (June 2015) http://www.northwestcoastconnections.com/docs/SPRC.pdf 2015) (June Corridor Route Proposed of Statement 9 1. 1.1 1.2 8.6 North Coast connections project West 2017 – January 2016/17 Assessment Options Network 1.3 2.2 2. 2.1 Chapter eight North West Coastconnectionstimeline Figure 8.4 3.1 3. 2.4.2 2.4.1 2.4 2.3.3 projects SWW A Appendix Network OptionsAssessment2016/17 –January2017 NGET DCO Strategic Wider Works Wider Strategic
planning/delivery May in submitted was Case Needs Initial an process, Works Wider Strategic the 2015. to meet order In November in project Works Wider aStrategic for NWCC project meets the eligibility criteria the that confirmed formally Ofgem Proposed Option Connection Q1 through the Lake District National Park. National District Lake the through the 23.4km of undergrounding 400kV of identification the including proposals, provided information on the connection 24 2017. February This consultation 2016 28 October to from project the on National Grid ran its statutory consultation corridor of the preferred option. alignment of the connection within the proposed the to define undertaken been now has work development Further of undergrounding or landscaping. require mitigation through the use may that areas any and connection to identify the route alignment for the specialists, has completed the process archaeologists and socio-economic landscape architects, ecologists, external consultants including by supported Grid, 2015 National June in corridor route preferred the Following the announcement of Q2 2016
consultation S42 Q3 Q4 Q1 submission DCO Q2 2017 Q3 Q4 Q1
Q2
2018
Q3
decision DCO Q4 Q1 4.1 4. 3.2 Q2 Projecttimeline 2019 project construction to commence in 2019. in to commence construction project applications in 2017 to allow the 400kV DCO their to submit intending are NuGen and Grid National Both aligned. closely are generator, NuGen, to ensure the timelines the with closely working is Grid National Case. Needs Final the to support undertaken be will analysis cost–benefit further project the of development the of connection obligation at this stage. As part the to satisfy to Middleton Bay Morecambe from Moorside including a tunnel under double overhead line to Harker and south a for was recommendation the and undertaken was analysis Cost–benefit consultation_2016.pdf uk/system/files/docs/2016/12/nwcc_ for tendering: https://www.ofgem.gov. the Initial Needs Case and the suitability a consultation currently on undertaking is Ofgem consumers. of interest best the in is and obligations statutory Grid’s option and how this option meets National for selecting the preferred connection process the demonstrates information The them. discounting for reasons with considered options strategic the presents and analysis benefit cost project, the information on the technical need for 2016. The Initial Needs Case includes Q3 Q4 Transmission construction M1 2020 M2 M1 2021 M2 M1 2022 M2 M1 2023 M2 M1 2024
136 M2 Chapter eight 137
. Extensive Extensive .
point-c-connection/ information on this consented project can be found on our website at http://www. hinkleyconnection.co.uk/ The process of options assessment options of process The carried out is summarised below, and is explained furtherin theProject Need and Environmental the of chapter Alternatives Statement submitted in support of the Point Hinkley the for application DCO be can which project, Connection C found here: https://infrastructure. planninginspectorate.gov.uk/ wp-content/ipc/uploads/projects/ EN020001/EN020001-000770-5.2.1%20 ES%20Project%20Need%20and%20 Alternatives.pdf This document also signposts the various documents referred below. to Having identified the needto reinforce system, transmission voltage high the extensive an considered Grid National range of options resolve to the need case, as reported in a Strategic Options Report (SOR) published in 2009. alternative 23 of considered, originally were options were discountedwhich 11 as they would Transmission Electricity National meet not System Security and Quality of Supply Standard (NETS SQSS). Eight options were discounted on the basis of excessive costs, and two were ‘parked’ (i.e. they arise issues should reconsidered be would with the options taken forward for further and solutions cost lower as investigation) coordination better providing options – available were works transmission of between connections were options these Nursling and Melksham and Point Hinkley Options Options assessment 2. 2.1 2.2 options strategic Consideration of 2.3 GW . 11 GW. The proposedGW. , to be, to connected 10 respectively in 2022 and 2023. Contracts for the power station were signed EDF by and its development partners and the UK which at 2016, September in government electricity first “the that confirmed EDF point is due be to produced in 2025” National Grid undertook a full option Hinkley that concluded that appraisal Point Seabank to overhead line would best economic technical, Grid’s National meet was and obligations, environmental and identified as the preferred strategic option. National Grid then refined this option and stakeholders, with consultation in should proposals the that concluded Mendip the cables in underground include Hills AONB, removal of existing distribution The design. pylon new a and infrastructure proposed project was subject extensive to October between consultation public 2009 and and March was granted 2014 development consent the by Secretary of State (SoS) for Energy and Climate Change in January 2016. Information on the project, including the development consent order (DCO) made by including documents project and SoS, the environmental Report and Consultation the information can be found here: https:// infrastructure.planninginspectorate. gov.uk/projects/south-west/hinkley- units, currently contracted, according according contracted, currently units, theto TEC Register power station would consist of two 1.67 The potential need for this project is driven generation of levels increased the by requested customers, by most notably Company Generation NNB proposed the (HPC) Limited (referred as to EDF) new Point, Hinkley at station power nuclear Entry Transmission a with Somerset Capacity (TEC) of 3.34 Background http://www2.nationalgrid.com/UK/Services/Electricity-connections/Industry-products/TEC-Register/ https://www.edfenergy.com/energy/nuclear-new-build-projects/hinkley-point-c/news-views/contracts-signed 1.2 1.3 10 11 1. 1.1 8.7 C connection project Point Hinkley 2017 – January 2016/17 Assessment Options Network Chapter eight Corridors andoptionsforHinkleyPointCconnectionproject Table 8.1 2.5 2.4 projects SWW A Appendix Network OptionsAssessment2016/17 –January2017 Corridor 2 Corridor 1, option B Corridor 1, option A Option PC5: Hinkley Point – Seabank (subsea). (onshore). –Seabank PC4: Bridgwater PC3: Bridgwater – Nursling. –Melksham. PC2: Bridgwater (subsea). –Aberthaw PC1: Hinkley take forward for further investigation, taking taking investigation, further for forward take to option preferred the remain should and economic and environmental obligations would best meet National Grid’s technical, line between Bridgwater and Seabank of constructing an overhead transmission option the that 2011The concluded SOR potential connections listed below: five 2011. in assessed report published This SOR afurther in documented is information alternative connection options. This on information updated and a review options appraisal, National Grid undertook connection options and the scope of its concerning its consideration of alternative made to representations response In option. preferred the between Hinkley Point and Seabank was line overhead 400kV anew that concluded substations respectively. The 2009 SOR
be removed. be not would line 132kV overhead WPD existing The areas. urban and in certain locations possible due be to not the presence would of this environmental constraints although lines, overhead distribution and transmission existing of paralleling the toavoid 2sought Corridor removed. be not would line 132kV overhead WPD existing the option this For line. overhead existing the of west or east tothe either line, 132kV overhead existing to the parallel line overhead 400kV operated by WPD. and Option owned B considered line the construction of a 132kV overhead new existing an on based corridor Route place. its in line overhead 400kV a new and Seabank, via Portishead in North Bridgwater Somerset and the construction between of direction north-to-south abroadly in travels which line 132kV overhead WPD existing the of removal the involved A Option plc. West) (South Distribution Power Western by operated and owned line 132kV overhead existing an on based corridor Route 2.6 Route corridor study table below. the in summarised are identified options and corridors The identified. were options, corridors, one of which contained two minimise effects. Two broad route and those on which should corridors that route should corridors seek to avoid undergrounding policy to areas identify its and Rules Holford the 9 Statement, into account National Grid’s Schedule corridors between these locations, taking route potential to identify undertaken was Study Corridor aRoute Seabank, and 400kV overhead line between Bridgwater connection should be based on a new preferred the that identified Having project. the of stage next the in investigated be would measures mitigation other and these that and connection may be placed underground thatrecognised sections of the proposed was It account. into standards licence its National Grid’s statutory obligations and Option description
138
Chapter eight 139 .
EDF confirm to its timescales for and C Point Hinkley the developing will then revise the programme. A DCO for the project as described above was made the by SoS in January 2016. with working currently is Grid National 29 October, 2013. Statutory29 October, 2013. and Statutory consultation on National Grid’s Grid’s National on consultation Statutory eight-week an over place took proposals and September 3 between period members and consultees non-statutory of the public were included within the representationsconsultation. 1,635 were of some consultation, the during received design the to changes requested which of the development.A structured change to implemented was process request address all requests for such changes. As a result, some local refinementsto the alignment were proposed a new (e.g. area). Mark/Southwick the in alignment which settlement, RIIO-T1 Grid’s National and consultation the during reached was development stage of the preferred option, identified the majority of the proposed as works Connection C Point Hinkley eligible for the Strategic Wider Works (SWW) framework. Further information about this project and other SWW can be found on Ofgem’s website here https:// www.ofgem.gov.uk/electricity/ transmission-networks/critical- investments/strategic-wider-works National Grid proposes submit to a Final Needs Case Ofgem to for this project, currently anticipated be to in Spring 2017. Strategic Wider Works Project timeline Project Statutory consultation process 2.9 3. 3.1 3.2 4. 4.1.1 During 2012 and 2013, the preferredDuring and 2013, 2012 route corridor was separated into a range a which within sections of number of overhead line routes were developed. also was route cable underground An sections, the of each within developed Policy National with accordance in and Statement EN-5 a comparison was made determineto whether the benefits from would alternative line non-overhead the economic, additional any outweigh clearly the and impacts environmental and social surmountable. were difficulties technical the in documented is process This and Report (2012), Options Connection determined the final route alignment of the overhead line. It also concluded that the benefits from the use of underground cables as an alternative an to overhead line in the Mendip Hills AONB (Section C) economic, extra the outweigh clearly would the and impacts environmental and social could undergrounding of costs additional therefore be justified. The Route Corridor Study concluded that that concluded Study Corridor Route The Corridor 1 Option A was clearly the least it as corridor constrained environmentally would use the route of an existing 132kV overhead line and would not result in any landscape. the in lines overhead additional effects minimise also corridorThis would on the Mendip Hills Area of Outstanding Special designated and Beauty, National for Areas Special Areas, Protection National sites, Ramsar Conservation, Monuments Scheduled Reserves, Nature and settlements. 2.7 and selection route Detailed undergrounding of consideration 2.8 2017 – January 2016/17 Assessment Options Network Chapter eight work possible include: and informationsupport that makes our provide who Parties people. many from the the Strategic network planning and producing parties Supporting following key activities: the performing includes This NETS. the for responsible for developing a holistic strategy NOA the to publishing addition In Development Network Electricity time. real of ahead aday just access to network through landscape energy achanging in stage options investment the electricity network operability by studying from addresses the of challenges engineering The Network Capability (Electricity) team [email protected] Head of Network Capability (Electricity) Smith Richard Meet the NOA team B Appendix Network OptionsAssessment2016/17 –January2017 Asset Management National Grid Electricity Transmission and evolution industry background. long term against the network development operable GB transmission network in the Developing strategies to enable a secure and demand connections. for all transmission generation and Providing the customer point of contact securely and economically. both operated be can system the ensuring development or maintenance activities while NETS for access system Facilitating to all connections. Managing the technical activities relating ETYS the in publish and requirements NETS to identify potential transmission FES Testing the NOA requires support and information information and support requires against models of the GB GB the of models against we are are we
.
[email protected] NOA on views your with us email also can you forget Don’t energy scenarios show might happen. future that requirements possible the to meet capabilities and working out the best options transmission system by present understanding and operable GB and offshore electricity efficient an of development the to ensure is The Electricity Network Development team [email protected] Head of Electricity Network Development Julian Leslie [email protected] Manager Capability System GB Nicholas Harvey Year Statement Electricity Ten and requirements Network [email protected] Economics Team Manager Marc Vincent Options Assessment Network and analysis Cost–benefit about: to discuss us You contact can SHE Transmission SP Transmission our customers. at: at:
140 Chapter eight 141 SPT-RI-003 SHET-RI-019 SHET-RI-019 21850-1 33432 21847, 20834-1, 20834-4, 20834-3, 20834-5, 20834-6, 20834-2, 20834-2C, 20834_2A, 20834-2Q 33458 33698, 33699 33452 SHET-RI-026 SHET-RI-026 32018L1 SHET-RI-7a SHET-RI-7a SHET-RI-69, SHET- SHET-RI-69, RI-66 TORI or scheme number The TORI number is the Transmission Owner Transmission the is number TORI The applies and number Instruction Reinforcement Scotland. in
Denny to Wishaw 400kV reinforcement Dounreay to Orkney, Bay of Skaill and Dounreay to Orkney, South Hoy subsea link South Hoy to Orkney, Bay of Skaill and Dounreay to Orkney, Dounreay cable section and replace – reconductor 1 circuit Drax to Eggborough South Hoy subsea link to Orkney, Dounreay to allow Thornton to run two-way split replacement breaker Generator circuit Bay of Skaill subsea link to Orkney, Dounreay Reconductor remainder of Coryton South to TilburyReconductor remainder circuit Quad booster installation at Cilfynydd A new 400kV double circuit between Bramford and Twinstead between Bramford A new 400kV double circuit Uprate non-conductor components of Bramford to Pelham double circuit to Pelham double circuit Uprate non-conductor components of Bramford new double circuit) to Twinstead (following Bramford to Rayleigh route to Braintree of Bramford Reconductor remainder Bolney and Ninfield additional reactive compensation reactive Bolney and Ninfield additional Beauly to Shin to Loch Buidhe 132kV double circuit reconductoring Beauly to Shin to Loch Buidhe 132kV double circuit and generation OHL reconductoring Beauly to Loch Buidhe 275kV double circuit connection reconfiguration Main MSCs at Burwell 225 MVAr Beauly to Loch Buidhe and Loch Buidhe to Dounreay 275kV double Beauly to Loch Buidhe and Loch Buidhe to Dounreay reconductoring circuit thermal uprating Bramley to Fleet circuits 400kV double circuit New Beauly to Kintore New Beauly to Loch Buidhe 275kV double circuit circuits New 275kV phase shifting transformers at Blackhillock on the Knocknagael from Reconductor the Connah's Quay legs of the Pentir to Bodelwyddan to Connah’s to Connah’s Reconductor the Connah's Quay legs of the Pentir to Bodelwyddan Quay 1 and 2 circuits New Beauly to Blackhillock 400kV double circuit Alverdiscott to Taunton double circuit thermal uprating double circuit to Taunton Alverdiscott Transformers and Melgarve and inter-bus Reactive compensation at Tummel at Fort Augustus Description publication together with their their with together publication DWNO D2NO DERE DHNO DREU DSNO CTRE CIQB BTNO BPEU BRRE BNRC BLR1 BLR2 BMMS BDRE BFHW BKNO BLN2 BLQB BCRE BBNO ATHW B1RC Four-letter Four-letter code The list below is of the options assessed List of options’ four-letter codes four-letter List options’ of in this NOA appear codes four-letter The codes. four-letter through the report in tables and charts. order alphabetical the in is below list The of the code. included We’ve the scheme options Some available. is it where number do not have scheme numbers, for instance if the option isvery Other new. options have where number scheme one than more option. an for combined been have schemes Appendix C 2017 – January 2016/17 Assessment Options Network Chapter eight code Four-letter of options’List four-letter codes C Appendix E4DC E2DC ECU2 ECU4 ECUP FLRE FBRE HCC1 HAEU GSNO GKRE HSNO HPNO KLRE KCRE LDQB LNRE LNHW LTR1 LTR2 NBRE MRUP NEEU NOR1 NOHW NOR2 OTHW OENO NR02 NR01 NPNO NOR3 Network OptionsAssessment2016/17 –January2017 Description Eastern subseaHVDCLinkfrom Pit Eastern PeterheadtoHawthorn subseaHVDCLinkfromEastern Torness Pit toHawthorn East Coastonshore 275kVupgrade East Coastonshore 400kVreinforcement East Coastonshore 400kVincremental reinforcement Fleet toLovedeanreconductoring connection reconfiguration Beauly toFyrish275kVdoublecircuit reconductoring andgeneration Cowley toMinetyandWalham cables(Hinkseycables)upgrade Harker SuperGridTransformer 6replacement Gills BaytoOrkney, SouthRonaldsaysubsealink to KillingholmeCircuit Reconductor GarforthTee toKeadbylegoftheCreyke BecktoKeadby Hinkley PointtoSeabanknewdoublecircuit New east–westcircuit betweenthenortheastandLancashire Kemsley toLittlebrook circuits uprating Reconductor theKeadbytoCottam400kVcircuits Lister Drivequadbooster Reconductor LackenbytoNortonsingle400kVcircuit Lovedean toNinfieldthermaluprate overhead linesections doublecircuitLackenby toThornton –upratecableandthermal reconductor sections doublecircuitLackenby toThornton –upratecablesectionand Reconductor Bramford toNorwichdoublecircuit Uprate thePenworthamtoWashway FarmtoKirkby275kVdoublecircuit to400kV North east400kVand275kVnetworkreinforcement Reconductor 13.75kmofNortontoOsbaldwick 400kVdoublecircuit Thermal uprate55kmoftheNortontoOsbaldwick 400kVdoublecircuit Reconductor 13.75kmofNortontoOsbaldwick number1400kVcircuit Osbaldwick to Thornton 1circuitOsbaldwick toThornton thermalupgrade Central Yorkshire reinforcement B4/B5 NotionalReinforcement 2 B4/B5 NotionalReinforcement 1 New east–westcircuit betweenthenortheastandLancashire Norton toOsbaldwick400kVdoublecircuit –reconductor therest ofthecircuits number TORI orscheme RI-025c, SHET-RI-025d SHET-RI-025b, SHET- SPT-RI-004 SPT-RI-200 SHET-RI-026, SPT-RI-200 SHET-RI-026, 31671-2 20903L, 33700 20899C 20897L4, 20897Q, 21132S, 20899, 20897L2B, 21132L, 20897L2, 20897L2A, 20897L1A, 20897L1B, 20898, 30010, 20846-4 21590 20669 31380 33454C &33454L 11630, 11630I,11630F SHET-RI-025d 20640 33705 142 Chapter eight 143 30915 21898-1 20314SI 33519 33417, 20774CA SHET-RI-69 SHET-RI-69 SHET-RI-69 SHET-RI-69 33506 33457 33702 32897 31338, 31339, 21497-5 31832-2, 31832-3 21850-1 SHET-RI-105 SHET-RI-105 33432 33712 30311, 30311-1L, 30311-1S, 30311-2, 30311-3C, 30311-6 33708 33711 32018L2 TORI or scheme number Windyhill turn in to Denny North to Lambhill to Longannet 275kV circuit 275kV substation circuit Boldon to Offerton device on West Deploy FACTS HVDC Link to South Wales North Wales Turn-in of West Boldon to Hartlepool cct at Hawthorn Pit of West Turn-in West Burton to High Marnham circuit – complete gantry works to match Burton to High Marnham circuit West rating circuit Western HVDC Link fast de-load scheme Install quad booster in West Boldon to Offerton circuit to Offerton Boldon Install quad booster in West Willesden to Wimbledon 275kV cable Ealing diversion Reactive compensation at Tummel Install series reactors at Thornton Install series reactors to Legacy thermal upgrade Tee Treuddyn to North East England AC reinforcement Torness and Melgarve Reactive compensation at Tummel Reconductor Drax to Thornton double circuit double circuit Reconductor Hinkley Point to Taunton at Thornton Install series reactors South east to East Anglia HVDC link Quay reconductoring to Connah’s Tee Treuddyn Reactive compensation protective switching scheme Reactive compensation protective Severn Tunnel 400kV cable circuit uprate 400kV cable circuit Severn Tunnel South East coast reactive compensation South East coast reactive New 400kV transmission route between South London and the south coast New 400kV transmission route alternative options) (three Uprate non-conductor components of newly formed Bramford to Braintree to to Braintree Uprate non-conductor components of newly formed Bramford new double circuit) to Twinstead (following Bramford Rayleigh Main double circuit at Rayleigh Main of Rayleigh to TilburyReconductor remainder circuit Reconductor newly formed second Bramford to Braintree to Rayleigh Main circuit to Rayleigh Main circuit to Braintree Bramford Reconductor newly formed second new double circuit) to Twinstead (following Bramford of the 275kV Rothienorman Rothienorman substation with reconductoring circuit to Kintore Pembroke to Walham circuit turn-inSwansea North to circuit to Walham Pembroke Pentir to Trawsfynydd circuits – reconductor the remaining overhead line sections the remaining – reconductor circuits Pentir to Trawsfynydd Pentir to Trawsfynydd second circuit Pentir to Trawsfynydd Pentir to Trawsfynydd 1 and 2 cables – second core per phase and reconductor per phase and reconductor 1 and 2 cables – second core Pentir to Trawsfynydd circuit the existing Pentir to Trawsfynydd of an overhead line section on Reconductor newly formed second Bramford to Pelham circuit (following Bramford (following Bramford to Pelham circuit Bramford Reconductor newly formed second circuit) new double to Twinstead per phase core – single 1 cable replacement Pentir to Trawsfynydd Reconductor Pentir legs of the Pentir to Bodelwyddan to Connah’s Quay 1 and Quay Pentir to Bodelwyddan to Connah’s Reconductor Pentir legs of the 2 circuits Description WLTI WOSR WPDC WHTI WHRE WEOS WBQB WEC1 TURC THS2 TLH1 TLNO TMRC TDRE THRE THS1 SGDC TCRE SEEU SEC1 SCRC SCN1/SCN2/ SCN3 RMEU RTRE RBRE RKEU PWTI PTRE PTNO PTC2 PRRE PTC1 PBRE Four-letter Four-letter code 2017 – January 2016/17 Assessment Options Network Chapter eight code Four-letter of options’List four-letter codes C Appendix WPNO WYQB WYTI Network OptionsAssessment2016/17 –January2017 Description Wylfa toPentirseconddoublecircuit route Wymondley quadboosters Wymondley turn-in number TORI orscheme 30346S 30310, 30310-3, 32581S 32586S 144 Chapter eight 145
produced produced 2 can be applied to large emission 2 ) Capture and Storage (CCS) is a process by which the CO and Storage (CCS) is a process ) Capture 2 is then compressed and transported for long-term storage in geological is then compressed 2 Description operator to balance demand and supply and to by a system Services procured the transmission system. supply across the security and quality of electricity ensure GB these In and voltage control. control frequency These services include reserve, parameters that service has different known as balancing services and each are must meet. a provider combination of weather elements cold spell is defined as a particular Average peak demand which has a 50% chance of which gives rise to a level of winter definitions different are of weather variation alone. There being exceeded as a result purposes. of ACS peak demand for different A UK government & Industrial department. The Department of Business, Energy energy clean, affordable the UK has secure, sure Strategy (BEIS) works to make international change. These activities action to mitigate climate supplies and promote of the Department of Energy and Climate Change formerly the responsibility were (DECC) which closed in July 2016. optimisation model supplied by Pöyry Management BID3 is an economic dispatch power markets simultaneously including the Consulting. It can simulate all European between markets. BID3 has been specifically developed impact of interconnection GB allowing the for National Grid to model the impact of electricity networks in to balance the system, System Operator to calculate constraint costs it would incur post-gate closure. arising out of the An allowance in MW to be added in whole or in part to transfers account of year-round NETS SQSS economy planned transfer condition to take some is calculated by an variations in levels of generation and demand. This allowance quality of supply empirical method described in Appendix F of the security and (SQSS). standards the region power that the transmission system can carry from The maximum pre-fault on the other side of the boundary while on one side of a boundary to the region will exist following ensuring acceptable transmission system operating conditions faults. one of a range of different costs. in comparison to the A method of assessing the benefits of a given project to be considered. a comparative base for all projects This tool can help to provide Carbon (CO formations or for use in industrial processes. The 2020 UK sources. renewable from of energy use sourced for share Targets Parliament and of the of the European 2009/28/EC defined in the Directive targets are Union, see http://eur-lex.europa.eu/legal-content/EN/TXT/ Council of the European HTML/?uri=CELEX:32009L0028&from=EN#ntc1-L_2009140EN.01004601-E0001 to drive a gas turbine Gas turbine that uses the combustion of natural gas or diesel is used to this process heat from The residual generator to generate electricity. boiler which, in turn, drives a steam turbine steam in a heat recovery produce electricity. generator to generate more generated simultaneously as part of both heat and electricity are A system whereby Covers a range of technologies that achieve this. one process. into a contract to connect any generator who has entered A term used to reference System (NETS) on a given date while having with the National Electricity Transmission of said contract. requirement as a a transmission entry capacity (TEC) figure wealth, fast-paced Energy Scenario. Consumer Power is a world of relative A Future and development and spending. Innovation is focused on meeting the needs research their quality of life. of consumers, who focus on improving in the combustion of fossil fuels is captured, transported to a storage location and transported to a storage location in the combustion of fossil fuels is captured, of CO Capture the atmosphere. isolated from sources like power plants used for electricity generation and industrial processes. processes. like power plants used for electricity generation and industrial sources The CO Ancillary services cold spell Average Department of Business, Energy & Industrial Strategy Boundary allowance Boundary transfer capacity Cost–benefit analysis Carbon Capture and Storage Word Climate change targets Combined cycle gas turbine Combined heat and power Contracted generation Consumer Power ACS BEIS BID3 CBA CCS Acronym Glossary Appendix D 2017 – January 2016/17 Assessment Options Network CCGT CHP CP Chapter eight HVDC HVAC GB GWh GW GTYS GG GSP GEP FES EU ENTSO-E EISD DNO DSR Acronym Glossary D Appendix Network OptionsAssessment2016/17 –January2017 Embedded generation overhead line Double circuit current High voltagedirect current High voltagealternating Great Britain Gigawatt hour Gigawatt Gas Ten Year Statement Gone Green Grid supplypoint Grid entrypoint Scenarios Future Energy European Union Operators –Electricity Transmission System European Networkof Earliest InServiceDate Operator Distribution Network Demand sideresponse Word voltage level andconvertitto/from AC. requires theuseofcostlypower electronic convertersateachendtochangethe subsea connections.HVDC offers variousadvantagesoverHVAC transmission,but current.alternating HVDCiscommonlyusedforpointto long-distanceand/or The transmissionofpower usingcontinuousvoltageandcurrent asopposedto to beraisedorlowered usingatransformer. common formofelectricitytransmissionanddistribution, sinceitallowsthevoltagelevel in acurrent flowthatperiodically reverses direction. HVAC ispresently themost Electric powertransmissioninwhichthevoltage variesinasinusoidalfashion,resulting Scotland andWales. A geographical,socialandeconomicgrouping ofcountriesthatcontainsEngland, 1,000,000,000 watthours,aunitofenergy 1,000,000,000 watts,ameasure ofpower annual basis. Transmission System(NTS)overatenyear periodandispublishedonan The GTYSillustratesthepotentialfuture developmentofthe(gas)National by society, enablingallcarbonandrenewable targetstobemetontime. restrained byfinanciallimitations.Newtechnologiesare introduced andembraced A Future EnergyScenario.GoneGreen isaworldwhere green ambitionisnot connected tothetransmissionsystem. transmission-connected load.Typically onlylargeindustrialloadsare directly A pointofsupplyfrom theGBtransmissionsystemtoadistribution networkor as thelowvoltagebusbaronplatformsubstation. transmission licensees for new types of substation. When offshore, the GEP is defined insulated substation,orequivalentpointasmaybedeterminedbytherelevant in thecaseofanairinsulatedsubstation,gaszoneseparatora transmission system.Thedefaultpointofconnectionistakentobethebusbarclamp A pointatwhichageneratingunitdirectly connectstothenationalelectricity to identifyfuture operabilitychallengesandpotentialsolutions. starting pointforalltransmissionnetworkandinvestmentplanning,are used to 2050,andare usedtoframediscussionsandperformstress tests.Theyformthe with theenergyindustry. Theyare asetofscenarioscoveringtheperiodfrom now The FESisarangeofcredible futures whichhasbeendevelopedinconjunction in Europe. A politicalandeconomicunionof28memberstatesthatare locatedprimarily Energy Marketin2009,whichaimsatfurtherliberalisingelectricitymarketstheEU. and givenlegalmandatesbytheEU’s Third LegislativePackagefortheInternal ENTSO-E isanassociationofEuropean electricityTSOs.ENTSO-Ewasestablished demand ontheNationalElectricityTransmission System. National ElectricityTransmission SystemOperator(NETSO).Theyreduce electricity Power generatingstations/unitsthatdon’t haveacontractualagreement withthe if investmentintheproject wasstartedimmediately. The earliestdatewhentheproject couldbedelivered andputintoservice, Distribution networkoperatorsownandoperateelectricitydistributionnetworks. electricity orgasconsumption,brought aboutbyasignalfrom anotherparty. A deliberatechangetoanindustrialandcommercial user’s ofmetered naturalpattern at leastonespan. is atransmissionlinewhichconsistsoftwocircuits sharingthesametowersfor in SPTransmission system.Inthecaseofanoffshore transmissionsystem,this Transmission's systemorNGET’s transmissionsystemorforatleasttwomiles consists oftwocircuits sharingthesametowersforatleastonespaninSHE In thecaseofonshore transmissionsystem,thisisalinewhich Description 146 Chapter eight 147
Description which commits directive Union is a European The Industrial Emissions Directive on the the impact of industrial emissions and reduce member states to control (LCPD) expires. Combustion Plant Directive post-2015 when the Large environment examined (ITPR) project Planning and Regulation Integrated Transmission Ofgem’s and cross-border offshore and delivering the onshore, the arrangements for planning Ofgem published the final conclusions in electricity transmission networks. 2015. March market to transmission assets that connect the GB are Electricity interconnectors between markets. and allow suppliers to trade electricity Europe which introduced Union Directive is a European The Large Combustion Plant Directive and dust of sulphur dioxide, oxides of nitrogen the emissions to control measures large combustion plant. from by the peak power output over a period of time. The average power output divided (see http://www. wave technologies Tidal tidal lagoons and energy from streams, emec.org.uk/) of power. a measure 1,000,000 Watts, 1 hour. of power usage or consumption in a measure hours, 1,000,000 Watt list of generators, sorted by the marginal cost of generation. An ordered transmission This comprises all the 400kV and 275kV elements of the onshore transmission system system and, in Scotland, the132kV elements of the onshore transmission offshore operated in parallel with the supergrid, and any elements of an generation circuits, system operated in parallel with the supergrid, but excludes between transformer connections to lower voltage systems, external interconnections transmission system and external systems, and any offshore the onshore via transmission system transmission systems radially connected to the onshore single interface points. and offshore System comprises the onshore The National Electricity Transmission and Scotland. It transmits high-voltage transmission systems of England, Wales the country. it is needed throughout to where it is produced where electricity from that extend across The system is made up of high voltage electricity wires and maintained by regional waters. It is owned Britain and nearby offshore by a single transmission companies, while the system as a whole is operated system operator (SO). the Britain while owning National Grid acts as the NETSO for the whole of Great In Scotland, transmission assets are transmission assets in England and Wales. in the Ltd (SHE Transmission) Electricty Transmission owned by Scottish Hydro South. in the SP Transmission North of the country and Scottish Power Transmission used in the planning and operation of the national electricity A set of standards For the avoidance of doubt the national Britain. transmission system of Great transmission system electricity transmission system is made up of both the onshore transmission systems. and the offshore office is plc (No. 2366977) whose registered National Grid Electricity Transmission 1–3 Strand, London, WC2N 5EH stations, gas transportation system consisting of compressor A high-pressure terminals NTS pipelines transport gas from pipelines, multijunction sites and offtakes. of 94 barg. designed to operate up to pressures and are to NTS offtakes Maintenance and system access is typically undertaken during the spring, summer and autumn seasons when the system is less heavily loaded and access is favourable. With and equipment unavailable the integrity of the system is circuits system to ensure controlled The planning of the system access is carefully reduced. security is maintained. Industrial Emissions Directive Integrated Transmission Planning and Regulation Interconnector Large Combustion Plant Directive Load factor Marine technologies Megawatt Megawatt hour Merit order Main Interconnected System Transmission National Electricity System Transmission National Electricity System Transmission Operator National Electricity System Transmission Security and Quality of Supply Standards National Grid Electricity plc Transmission National Transmission System Network access Word IED ITPR LCPD MW MWh MITS NETS NETSO NETS SQSS NGET NTS Acronym 2017 – January 2016/17 Assessment Options Network Chapter eight SP PV pa OCGT Ofgem NP NOA Acronym Glossary D Appendix Network OptionsAssessment2016/17 –January2017 SHE Transmission Seasonal circuit ratings Real power Reactive power Ranking order generation background) background (aka Power supply Planned transfer Peak demand circuit Onshore transmission Onshore circuit Offshore transmission Offshore Slow Progression Photovoltaic Per annum Open cyclegasturbine Electricity Markets Office ofGasand No Progression Assessment Network Options Word target dates. low costlong-termsolutions toachievedecarbonisation,albeititlater thanthe growth restricts marketconditions. Moneythatisavailablespentfocusing on A Future EnergyScenario.SlowProgression isaworldwhere slowereconomic situated atInveralmondHS,200DunkeldRoad, Perth,Perthshire PH13AQ. Scottish Hydro-Electric Transmission (No.SC213461)whose registered officeis 400kV overheadlinemaybe20%lessinthesummer thaninwinter. seasons asthecircuit’s capabilitytodissipateheatisreduced. Theratingofatypical The current carrying capabilityofcircuits. Typically, thisreduces duringthe warmer factor otherthan1. load. InanACsystem,real powerisaccompaniedbyreactive powerforany This term(sometimesreferred toas‘ActivePower’)provides theusefulenergytoa are saidtogeneratereactive power. are saidtoabsorbreactive power;thosewhichstore energy byvirtueofelectricfields Devices whichstore energybyvirtueofamagneticfieldproduced byaflowofcurrent and magneticfields.Thesefieldsstore energywhichchangesthrough eachACcycle. currentmovement inanalternating (AC)systemarisingfrom theproduction ofelectric Reactive powerisaconceptusedbyengineerstodescribethebackground energy used bytheNETSSQSS. A listofgeneratorssortedinorder oflikelihoodoperationattimewinterpeakand The sources ofgenerationacross Great Britaintomeetthepower demand. analysing boundarycapability. A termtodescribeapointatwhichdemandissettheNationalPeakwhen conducting materials. A methodofconvertingsolarenergyintodirect current electricityusingsemi- Per year. of peakdemandare usedfordifferent purposes. around 5:30pmonaweek-daybetweenDecemberandFebruary. Different definitions The maximumpowerdemandinanyonefiscalyear:Peaktypicallyoccursat inthecombustor.injected andburned Gas turbinesinwhichairisfirstcompressed inthecompressor elementbefore fuelis busbars, generationcircuits andoffshore transmissioncircuits. includes, forexample,transformers,reactors, cablesandoverheadlinesbutexcludes Part oftheonshore transmissionsystembetweentwoormore circuit-breakers which This termrefers toassetsthatare whollyonland. converters butexcludesbusbarsandonshore transmissioncircuits. which includes,forexample,transformers,reactors, cables,overheadlinesandDC Part ofanoffshore transmissionsystembetweentwoormore circuit breakers This termmeanswhollyorpartlyinoffshore waters. electricity andgasconsumers. department. Theirprincipalobjectiveistoprotect theinterests ofexistingandfuture The UK’s independentNationalRegulatoryAuthority, anon-ministerialgovernment of gasandelectricitydominate,withlittleinnovationaffecting howweuseenergy. loweconomicgrowth, traditionalsourcesof supplyatthelowestpossiblecost.With A Future EnergyScenario.NoProgression isaworldfocusedonachievingsecurity finds from itsanalysisoftheFutureEnergyScenarios(FES). Transmission System(NETS)tomeettherequirements thatthesytemoperator(SO) The NOAistheprocess forassessingoptionsreinforcing theNationalElectricity Description 148 Chapter eight
149
Description office is situated registered plc (No. SC189126) whose Scottish Power Transmission 8SP. Glasgow G2 Robertson Street, at 1 Atlantic Quay, one fiscal year: the transmission network in any off The minimum power demand between May 06:00am on a Sunday at around Minimum demand typically occurs and September. transmission system operated at a nominal voltage That part of the national electricity of 275kV and above. on the NETS that operate in the A term used to describe transformers 275–400kV range. of a substation that can be used to carry The term used to describe components include, but is not limited to, isolators/disconnectors out switching activities. This can breakers. and circuit largely by the changes. This is provided of the system that resists The property mass, diameter inertia that is a function of the rotor generator synchronous rotating the risk of rapid system changes. Low system inertia increases and speed of rotation. and operational The ability to maintain system stability and all of the asset ratings economically and sustainably. limits safely, parameters within pre-defined operation The SOF identifies the challenges and opportunities which exist in the operability. the future to ensure electricity networks and identifies measures of future gas or power An entity entrusted with transporting energy in the form of natural Unlike a TSO, the SO may or national level, using fixed infrastructure. on a regional not necessarily own the assets concerned. For example, National Grid operates by Scottish Hydro the electricity transmission system in Scotland, which is owned Scottish Power. and Electricity Transmission With voltages during the power demand and a tendency for higher system reduced do run could be at summer months fewer generators will operate and those that the dynamic power factor output. This condition has a tendency to reduce reduced analysis is usually performed for network stability stability of the NETS. Therefore the limiting period. summer minimum demand conditions as this represents that allows TOs This is a funding mechanism as part of the RIIO-T1 price control that have not been funded in the price large investment projects to bring forward settlement. control transmission circuit. or an offshore circuit transmission This is either an onshore station at its grid entry The maximum amount of active power deliverable by a power This will be the maximum power or offshore). point (which can be either onshore minus any auxiliary deliverable by all of the generating units within the power station, loads. of the transmission system. caused by the electrical resistance Power losses that are transmission asset owners within A collective term used to describe the three Scottish Hydro-Electric Britain, namely National Grid Electricity Transmission, Great Limited. Limited and SP Transmission Transmission gas or power An entity entrusted with transporting energy in the form of natural or national level, using fixed infrastructure. on a regional SP Transmission SP Transmission Summer minimum Supergrid Supergrid transformer Switchgear System inertia System operability System Operabiltiy Framework System Operator System stability Strategic Wider Works circuit Transmission entry Transmission capacity losses Transmission Owners Transmission System Transmission Operators Word SGT SOF SO SWW TEC TO TSO Acronym 2017 – January 2016/17 Assessment Options Network Chapter eight Disclaimer or misstatement or opinion on which the recipient of of recipient the which on opinion or misstatement or error any for liability any under be shall company) such any of employees the or directors the (nor group Grid NGET nor the other companies within the National information contained within the Document. Neither the of completeness and accuracy to the as made is or be can C27, of warranty no requirements the with accordance in published and prepared Whilst the information within the Document has been licence. transmission NGET the of accordance with Standard Condition C27 (“C27”) in and charge without (“NGET”) plc Transmission Document”) is published by National Grid Electricity Options Assessment Report The information contained within this Network Network OptionsAssessment2016/17 –January2017 document (“the
Designs and Patents Act 1988. Act Patents and Designs accordance with the provisions of the Copyright, in except Grid National of permission written the whether or not transiently or incidentally) without and means electronic or medium any in restoring any material form (including photocopying and in reproduced be may Document this of part No Copyright National Grid 2017, all rights reserved. incurred. losses or damages any for law) by information or Document or (to the extent permitted the of made is which use any for responsibility any accept not does and misrepresentation) than fraudulent misstatement or fraudulent (other to rely seeks or relies Document the
150 Continuing the conversation
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