National Grid Plc · LSE:NG.
National Grid — Investor Presentation (April 2009)
106 slides from National Grid's investor presentation, Apr 9, 2009
Slide 1: User Seminars 7th & 9th April 2009
User Seminars 7th & 9th April 2009 - Macdonald Holyrood, Edinburgh - Thistle Westminster, London
Slide 2: Introduction & Welcome
Introduction & Welcome Chris Sambridge – Policy and Support Manager
Slide 3: Welcome
Welcome Health and Safety – fire alarm, fire exits, assembly point Mobile phones and Blackberrys Today’s format Q & A’s at end of each presentation Q & A’s published on web after both seminars 3
Slide 4: Agenda
Agenda 14:00 Introduction and Welcome GB Queue Management Update Constraint Management Update Locational BSUoS – Effects on Charging 16:00 Coffee Break Offshore Transmission Update Developing the Electricity Transmission System Summary and Close 17:30 approx. Networking opportunity over wine and can
Slide 5: National Grid hosts - Edinburgh
National Grid hosts - Edinburgh Duncan Burt – Customer Services Manager Les Jenkins – Customer Policy and Strategy Manager Chris Sambridge – Policy and Support Manager Mark Pearce – Electricity Customer Manager Nigel Fox – Charging & Revenue Manager John Greasley – GBSO Offshore Manager
Slide 6: National Grid hosts - London
National Grid hosts - London Duncan Burt – Customer Services Manager Les Jenkins – Customer Policy and Strategy Manager Chris Sambridge – Policy and Support Manager Mark Pearce – Electricity Customer Manager Nigel Fox – Charging & Revenue Manager John Greasley – GBSO Offshore Manager A
Slide 7: GB Queue Management
GB Queue Management Andrew Ford Customer Services Policy and Strategy
Slide 8: GB Queue Management
GB Queue Management GB Queue Management – Aims and Blockers. GB Queue Management Progress. TEC reduction review. CAP150. What does National Grid need from Users? 8
Slide 9: GB Queue Management – what are we doing?
GB Queue Management – what are we doing? Aims Replace sequential connection queue created at BETTA. Prevent Users retaining TEC they are unlikely to use. Connect ready, willing and able projects earlier. Utilisation of capacity – connect and manage via derogations. Interim initiatives to s
Slide 10: GB Queue Management – what are we doing?
GB Queue Management – what are we doing? Blockers Large influx of connection requests to a congested network. Planning Issues. Extending reinforcement works e.g. Beauly-Denny. Consents process. Uncertainty from developers in the queue. Finance Delays Regime does not allow for Strateg
Slide 11: December 2008 position
December 2008 position December 2008 Projects Invited to submit Modification Applications to 454 MW Advance Projects Unable to Advance 150 MW Requests Under review by Optimisation group 1600 MW Total—Projects that have requested advancement via 2200 MW the Quarterly report process 11
Slide 12: April 2009 position
April 2009 position April 2009 Projects with Offers issued during March and April 454 MW Further Projects identified for advancement 457 MW Projects Unable to Advance 1300 MW New requests under review by Optimisation group 200 MW Total—Projects that have requested advancement 2400 MW via the Quarter
Slide 13: Firm/Non Firm Offers
Firm/Non Firm Offers Scottish Hydro-Electric Scottish Power Transmission Transmission Limited Limited Total Agreement Type Firm Non Firm Firm Non Firm BCA 0 MW 390 MW 69 MW 0 MW 459 MW BELLA/BEGA 0 MW 366.5 MW 20 MW 0 MW 386.5 MW Small Embedded 0 MW 0 MW 65.5 MW 0 MW 65.MW Total 0 MW 756.5 MW 154.5
Slide 14: Free TEC Reduction review
Free TEC Reduction review Open letter to the Industry was published on National Grid website on 9th February 2009. National Grid initiated this process as an initiative to promote the release of capacity. Currently 10 enquiries and 1 formal request have been made, which National Grid are currently
Slide 15: CAP 150 - Update
CAP 150 - Update CAP150 was implemented on 16th May 2008, providing a framework for National Grid to monitor/reduce projects contracted capacity where the User is unable to make use of it by the contracted completion date. 13 projects were sent letters requesting clarification/evidence in March
Slide 16: What do we need from Users?
What do we need from Users? Users are requested to continue to submit Quarterly Reports with aspirational connection dates. National Grid values feedback and would request Users contact Chris Sambridge with any questions, suggestions or initiatives that may assist the GB Queue Management process
Slide 17: Constraint Management Update
Constraint Management Update Robert Smith Customer Services Electricity Codes
Slide 18: Agenda
Agenda Background Changes considered to manage constraints Ofgem consultation – addressing market power concerns Progress on options taken forward Category 5 System to Generator Operational Intertripping Scheme Progress on Locational BSUoS TO incentives Administered BM prices Feedb
Slide 19: Background
Background al! J nationalgrid The power of action:
Slide 20: Ofgem Open Letter to National Grid (Feb 09)
Ofgem Open Letter to National Grid (Feb 09) Requests National Grid to conduct an urgent review to consider whether changes are required to existing commercial and charging arrangements for access to the GB transmission system 20
Slide 21: Ofgem Letter
Ofgem Letter Review should seek to address: Options for reducing the level of constraint costs; and Whether the current use of system charging mechanisms are equitable and appropriate 21
Slide 22: Ofgem Letter - Timelines for the review
Ofgem Letter Timelines for the review Raise any proposals by the end of February 2009; or Publish a report explaining why we consider the current arrangements and forecast level of constraints costs are consistent with all of our relevant statutory and licence obligations A link to our respo
Slide 23: Trend in constraint costs
Trend in constraint costs 300 250 BETTA Implementation 200 £m illio n s 150 100 50 0 2001/2 2002/3 2003/4 2004/5 2005/6 2006/7 2007/8 2008/9* 2009/10* England & Wales Cheviot Scotland GB * Forecast information 23
Slide 24: Historical trend in constraint costs
Historical trend in constraint costs What is driving the recent increase? Outages associated with new investment/connections Outages associated with asset replacement Derogation of B6 or ‘Cheviot’ boundary from requirement to comply with Security and Quality of Supply Standards (SQSS) 24
Slide 25: Forecast of capacity shortfall
Forecast of capacity shortfall Cheviot boundary capacity vs GB SQSS Required Capability 6000 5000 Transmission Capacity (MW) 4000 3000 2000 Best View Required Capability* 1000 Contracted Background Required Capability** Actual Capability 0 2007/08 2008/09 2009/10 2010/11 2011/12 2012/13 2013/14 2014
Slide 26: Derogated boundaries
Derogated boundaries Why is non-compliance with SQSS a specific issue? Significant constraint management actions required during intact network conditions Including significant utilisation of intertrips (where economic) to maximise boundary capability Removes flexibility to schedule outages
Slide 27: Agenda
Agenda Background Changes considered to manage constraints Ofgem consultation – addressing market power concerns Progress on options taken forward Category 5 System to Generator Operational Intertripping Scheme Progress on Locational BSUoS TO incentives Administered BM prices Feedb
Slide 28: Managing Constraints Costs
Managing Constraints Costs Volume Clear issue on non-compliant boundary Price 28
Slide 29: Managing Constraints Costs - Volume
Managing Constraints Costs - Volume G=1000MW G=400MW What are the options available? D=400MW D=1000MW 1. Increase boundary limit • Build more capacity • SO-TO alignment of incentives Transfer = 600MW Boundary Limit = 400 MW Constraint = 200MW Constrained Zone Unconstrained Zone 29
Slide 30: Managing Constraints Costs - Volume
Managing Constraints Costs - Volume G=1000MW G=400MW What are the options available? D=400MW D=1000MW 1. Increase boundary limit • Build more capacity • SO-TO alignment of incentives Transfer = 600MW 2. Reduce flow Boundary Limit = 400 MW • TEC reduction • Auction to compliant levels Constraint = 20
Slide 31: Managing Constraints Costs - Price
Managing Constraints Costs - Price G=1000MW G=400MW What are the options available? D=400MW D=1000MW 1. Administered prices • Bids and Offers • Intertrips Transfer = 600MW • TEC buyback product Boundary Limit = 400 MW Constraint = 200MW Constrained Zone Unconstrained Zone 31
Slide 32: Evaluation of options
Evaluation of options Interaction with Transmission Access Reform Ease of implementation Efficiency of proposal Likely BSUoS cost savings Better meet licence objectives 32
Slide 33: The options we proposed to take forward
The options we proposed to take forward On derogated boundaries Locational BSUoS Administered prices for intertrips SO-TO aligned incentives For further consideration Administered Balancing Mechanism prices during constraints 33
Slide 34: Ofgem consultation – addressing market power concerns
Ofgem consultation – addressing market power concerns Launched 30 March 2009 Responses by 8 May 2009 Considers three broad approaches to tackling issue of undue exploitation of market power Licence condition; Price capping; or Divestment Preferred mechanism - licence condition 34
Slide 35: Agenda
Agenda Background Changes considered to manage constraints Ofgem consultation – addressing market power concerns Progress on options taken forward Category 5 System to Generator Operational Intertripping Scheme Progress on Locational BSUoS TO incentives Administered BM prices Feedb
Slide 36: Category 5 System to Generator Operational Intertripping Scheme
Category 5 System to Generator Operational Intertripping Scheme
Slide 37: Background
Background National Grid proposing to introduce a new category of System to Generator Operational Intertripping Scheme Requires amendment to CUSC, Grid Code and Procurement Guidelines CUSC Amendment Proposal 170 Urgent status http://www.nationalgrid.com/uk/Electricity/Codes/gridcode/consul
Slide 38: Issue being addressed
Issue being addressed At non-compliant transmission boundaries The need to take action to manage constraints is more onerous than at a compliant transmission boundary As such the use of intertrips (where economic) is a necessity rather than an occasional tool to maximise the flows across the bou
Slide 39: Next steps
Next steps CUSC & Grid Code Amendment Reports submitted to authority 25th March Procurement Guidelines consultation closes 9th April Note Ofgem have stated they intend to do a Regulatory Impact Assessment 39
Slide 40: Locational Balancing Services Use of System (BSUoS)
Locational Balancing Services Use of System (BSUoS) Charging Methodology Proposal
Slide 41: Initial Thinking – B6 Transmission Capacity Shortfall
Initial Thinking – B6 Transmission Capacity Shortfall Cheviot boundary capacity vs GB SQSS Required Capability 6000 5000 Transmission Capacity (MW) 4000 3000 2000 Best View Required Capability* 1000 Contracted Background Required Capability** Actual Capability 0 2007/08 2008/09 2009/10 2010/11 2011/
Slide 42: Initial Thinking
Initial Thinking TNUoS : Proxy for the long run cost of Transmission Access Assumes SQSS compliance (assets have been built) BSUoS : Constraint costs Should reflect the efficient level of build on a Compliant Network Proxy for short run costs of transmission access for non compliant capaci
Slide 43: Initial Thinking
Initial Thinking TNUoS : Proxy for the long run cost of Transmission Access Assumes SQSS compliance (assets have been built) BSUoS : Constraint costs Should reflect the efficient level of build on a Compliant Network Proxy for short run costs of transmission access for non compliant capaci
Slide 44: Locational BSUoS: Proposal
Locational BSUoS: Proposal BSUoS charges: two component parts; Locational element reflecting the costs of constraints incurred through derogated boundary non compliance; and A residual element incorporating the remaining costs. 44
Slide 45: Locational BSUoS: Proposal
Locational BSUoS: Proposal BSUoS charges: two component parts; Locational element reflecting the costs of constraints incurred through derogated boundary non compliance; and A residual element incorporating the remaining costs. Locational element is allocated to all BMUs located behind the
Slide 46: TNUoS Implications
TNUoS Implications TNUoS: proxy for the Long Run cost of transmission access Locational Element of BSUoS: proxy for the Short Run cost of transmission access If Parties exposed to both BSUoS and TNUoS for all capacity effectively charged twice for non compliant proportion of access. TNUoS ch
Slide 47: Comments requested
Comments requested A few key areas we specifically would welcome views on What impact do you feel Locational BSUoS will make on constraint costs? What do you see as to the benefits and/or consequences of this proposed change (e.g. in respect of new generation connecting)? Do you agree with N
Slide 48: Timeline
Timeline Responses to the consultation requested by no later than close of play on 20 April 2009 (date extended following explanatory note) Offering to meet bilaterally to discuss further http://www.nationalgrid.com/uk/Electricity/Charges/modifications/uscmc/ 48
Slide 49: TO Incentives
TO Incentives al! J nationalgrid The power of action:
Slide 50: SO-TO aligned incentives
SO-TO aligned incentives Efficient alignment of TO and SO financial drivers should help to reduce constraint costs over the medium and long term (1-7 years) by encouraging efficient and timely investment. In addition, such alignment should also lead to: Improvements in the way the TOs plan outages
Slide 51: SO-TO aligned incentives – greater focus
SO-TO aligned incentives – greater focus Long Term (5-7 years) and Medium term (1-5 years): Outage alignment Outage duration and timing Outage innovation Outage stability Capacity increases (short-term and enduring) Short term (within year): Re-optimisation 51
Slide 52: National Grid – Proposed Way Forward
National Grid – Proposed Way Forward Further work required To select all key boundaries and circuits To devise financial incentive Expect to complete this in next few weeks In discussions with TOs and Ofgem on best way forward TO licence amendment SO-TO Code amendment Ofgem also requ
Slide 53: Latest thoughts on administered BM prices
Latest thoughts on administered BM prices
Slide 54: Ofgem consultation
Ofgem consultation Ofgem consultation on ‘Market Power Concerns’ looks wider than just administering BM prices Considers alternatives to pay-as-bid mechanism such as marginal cleared price Considers ex-ante regulation mechanism (e.g. due to constrained regions) Mechanism to cap prices Comp
Slide 55: Agenda
Agenda Background Changes considered to manage constraints Ofgem consultation – addressing market power concerns Progress on options taken forward Category 5 System to Generator Operational Intertripping Scheme Progress on Locational BSUoS TO incentives Administered BM prices Feedb
Slide 56: Feedback on our review
Feedback on our review Concerns have been highlighted by some industry parties on the: Lack of transparency in relation to constraint services required and costs Not seeking new and more innovative ways of managing these constraint costs In relation to transparency we agree there are issues
Slide 57: Agenda
Agenda Background Changes considered to manage constraints Ofgem consultation – addressing market power concerns Progress on options taken forward Category 5 System to Generator Operational Intertripping Scheme Progress on Locational BSUoS TO incentives Administered BM prices Feedb
Slide 58: Summary
Summary Increasing trend in constraint costs Volume issue on derogated boundaries Ofgem consulting on market power concerns Not minded to progress administered BM prices at this stage Administered prices for CAT 5 intertrips raised and with Ofgem Locational BSUoS consultation closes on 2
Slide 59: Locational BSUoS – Effects on Charging
Locational BSUoS – Effects on Charging Nigel Fox Charging & Revenue Manager
Slide 60: Agenda
Agenda TNUoS Charging BSUoS Charging Examples 60
Slide 61: TNUoS
TNUoS zal J nationalgrid The power of action:
Slide 62: Proposed changes to TNUoS tariffs
Proposed changes to TNUoS tariffs If the cost of non-compliance (higher constraints) is reflected in a new locational BSUoS charge, TNUoS charges should be adjusted so that they only reflect the cost of compliant system Generation behind non-compliant boundaries scaled to compliant level Wider z
Slide 63: Step 1: Calculate locational tariffs for non-compliant zones
Step 1: Calculate locational tariffs for non-compliant zones All generation behind non-compliant boundary is uniformly scaled to a compliant level and the transport model is re-run A capacity scaling factor of ~79% is required 63
Slide 64: Step 2: Combine locational tariffs for all zones in GB
Step 2: Combine locational tariffs for all zones in GB The revised locational tariff is a combination of two generation backgrounds A TNUoS rebate of ~£22m 64
Slide 65: Step 3: Recalculate residual tariff component
Step 3: 3 Recalculate residual tariff component The revised residual is slightly larger to recover the drop in revenue that results from lower locational tariffs in non-compliant boundaries 65
Slide 66: Resulting changes to wider generation TNUoS tariffs
Resulting changes to wider generation TNUoS tariffs Non-Compliant Zones Compliant Zones 0.50 0.00 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 -0.50 -1.00 -1.50 -2.00 -2.50 -3.00 -3.50 B6 Boundary 66
Slide 67: Mid-year implementation
Mid-year implementation Changes to tariffs and charges will be made mid-year No change to: a generator’s chargeable capacity local generation charges demand TNUoS tariffs Annual TNUoS liability is calculated on a prorated based for the tariffs that apply within the year Revised monthly c
Slide 68: A simple example
A simple example Initial liability Initial monthly charge calculated as calculated as normal normal i.e. i.e. the annual liability TEC x TNUoS1 charged in 12 equal Revised annual Implementation liability is changes tariffs in August of modification monthly instalments given by: Annual Liability Annu
Slide 69: BSUoS
BSUoS zal J nationalgrid The power of action:
Slide 70: Allocation of Costs to Individual Parties
Allocation of Costs to Individual Parties Locational BSUoS Element Allocated to all exporting BMU behind a derogated boundary Costs allocated based on BMU proportion of Total Metered Adjusted output behind boundary (QMadjij) QMadjij = The intended Metered Output of the BMU prior to interventio
Slide 71: BSUoS Billing Changes
BSUoS Billing Changes 300MWh PN Capping 50MWh 250MWh BMU Specific Constraint Action Final BMU Meter Adjusted PGBTs Volume 300MWh used in 50MWh Volumes 150MWh calculation of proportion of 200MWh Total Constraint Costs (if applicable) BOAs 50MWh 150MWh Final BMU Metered Volume 150MWh used in calculati
Slide 72: Hypothetical examples
GB SYS FIGURE A.1.3 GB GENERATION USE OF SYSTEM TARIFF ZONES 2007/08 400kV Substations Hypothetical examples 275kV Substations Dounreay 132kV Substations Thurso 400kV Circuits 1 Mybster 275kV Circuits 132kV Circuits Stornoway Cassley Dunbeath Major Generating Sites Lairg Including Pumped Storage THE
Slide 73: Example in Scotland, TNUoS
Example in Scotland, TNUoS Dexter power station has a TEC of 300MW and is located in Zone 5 (Argyll) at Nant 132kV substation TNUoS tariff = Wider Zonal tariff + Locational Substation tariff + Local cct tariff Under the current regime the following TNUoS charge will apply: £13.99/kW + £0.14/kW +
Slide 74: Example in England & Wales, TNUoS
Example in England & Wales, TNUoS Simmental power station has a TEC of 300MW and is located in Zone 14 (Midlands) at Leiston 132kV TNUoS tariff = Wider Zonal tariff + Locational Substation tariff + Local cct tariff Under the current regime the following TNUoS charge will apply: £2.11/kW + £0.30/
Slide 75: Example for BSUoS - Assumptions
Example for BSUoS - Assumptions Both power stations have an output of 1TWH under the current regime Under the proposal, Dexter ps has a final metered position of 0.8TWH with 0.2TWH of BMU specific constraint actions ly on B6 boundary constraints are £75m on a background of £975m total balancin
Slide 76: Example in England & Wales, BSUoS
Example in England & Wales, BSUoS Current Regime Simmental pays BSUoS based on £1.50/MWH and a chargeable volume of 1TWH Charge = £1.5m Under Proposal Charge = 1TWH @ Residual Charge of £1.38 = £1.380m BSUoS difference £120k reduction in charge Overall Position £96k extra TNUoS charge offs
Slide 77: Example in England & Wales, Scotland
Example in England & Wales, Scotland Current Regime Dexter pays BSUoS based on £1.50/MWH and a chargeable volume of 1TWH Charge = £1.5m ! e Under Proposal tiv Residual Charge = 0.8TWH @ residual tariff of £1.38 = £1.104m a tr Targeted Charge = 1TWH @ targeted tariff of £1.88 = £1.880m us T
Slide 78: Summary
Summary BSUoS TNUoS charges charges Constraint Adjusted based on Charge a compliant level + of TEC Cheviot Non-locational costs Boundary Residual adjusted to ensure Non-locational correct costs only revenue recovery 78
Slide 79: Contacts
Contacts 01926 654633 charging.enquiries@uk.ngrid.com 79
Slide 80: Coffee Break
Coffee Break 80 Back at 16:20 nationalgrid The power of action: yy,
Slide 81: Offshore Transmission Update
Offshore Transmission Update John Greasley GBSO Offshore Manager
Slide 82: Offshore Transmission Update
Offshore Transmission Update Competitive appointment of Offshore Transmission Owners Timescales: Go-active in June 2009 Transitional activities Appointment of OFTOs for transitional sites (developers build) Migration of current contractual relationships Go-live in June 2010 Offshore chargi
Slide 83: Developing the Electricity Transmission System
Developing the Electricity Transmission System John Greasley GBSO Offshore Manager
Slide 84: Climate Change concerns drive targets
Climate Change concerns drive targets 2050 GHG Target 2020 Scottish Renewables Target By 2020 50% of gross electricity consumption in Scotland derived from renewable sources. Interim Reduce CO2 emissions to 80% below 1990 levels by target of 31% by 2011. 2050. ic Our share of the 2020 m est Renewabl
Slide 85: What are the implications of this?
What are the implications of this? How do we source renewable energy? How do we source low carbon energy? For electricity: What generation mix is required? What transmission network is required to connect it all up? What market arrangements are required? How will the system be operated? How
Slide 86: A roadmap to 2050
A roadmap to 2050 Electricity Heat Transport Simple efficiency measures across all sectors Appliance Insulate Efficient engines & Efficiency/Smart Homes integrated transport Decarbonised Heat electricity fuels Pump zero-emission vehicles Decarbonised .heats new .& decarbonise Electricity… homes only
Slide 87: Our different programmes of work
Our different programmes of work Removing network constraints Meeting the operational challenge Scenario development Market requirements 87
Slide 88: Initiatives in each area
Initiatives in each area ENSG TAR Dealing with increased GBSQSS intermittency GB Queue Management Gone Green Will the market provide? 88
Slide 89: Gone Green 2020
Gone Green 2020 Plant closures B LE 5.5, 6% 12GW Coal & oil LCPD U SI 3.3, 3% P LA UT LY 34.1, 34% 7.5GW nuclear B ME G E GIN 29.1, 30% Some gas & additional coal T R EX LLEN Significant new renewable C HA 6.9, 7% 19.8, 20% 32 GW wind (21GW offshore & 11GW onshore) Gas Coal Nuclear Wind Othe
Slide 90: Gone Green 2030
Gone Green -2030 2030 Remaining coal and nuclear stations to be replaced 6.9, 6% 6.9, 6% 16GW of remaining coal 31.5, 30% 2.5GW nuclear (last two AGRs) 40.0, 38% 8GW of gas closures 10.9, 10% 10.6, 10% New low carbon generation required to meet CO2 Gas Coal Nuclear Wind Other Renew able Other
Slide 91: Removing Network Constraints
Removing Network Constraints Issues to solve… Our proposals… 1a. “Strategic Investment” in 1. Build more transmission transmission – Technical Studies capacity faster 1b. Regulatory Reform for Strategic Investment 2a. Transmission Access Reform 2. Allocate available transmission capacity more sensib
Slide 92: ENSG Report
ENSG Report Develop electricity generation and demand scenarios consistent with the EU Target for 15% of the UK’s energy to be produced from renewable sources by 2020 Identify and evaluate a range of potential electricity transmission network solutions that would be required to accommodate these sce
Slide 93: ENSG approach
ENSG approach Joint study with Scottish TOs Gone Green 2020 generation mix used Three scenarios for volume of Scottish renewables: 6.6GW (minimum to meet Scottish Gov’t target) 8GW 11.4GW Offshore generation (E&W) 21 – 25GW Constant UK renewable electricity in each case 93
Slide 94: UK Strategic Investment – areas of focus
UK Strategic Investment – areas of focus TRANSMISSION SYSTEM REINFORCEMENTS Dounreay Thurso Focus on Scotland Mybster REINFORCED NETWORK Stornoway Cassley Lairg Dunbeath THE SHETLAND ISLANDS 400kV Substations 275kV Substations Driven by onshore renewables Brora 400kV CIRCUITS Shin 275kV CIRCUITS Gru
Slide 95: Reinforcements to Accommodate Increased Transfers from Scotland – 2020
Reinforcements to Accommodate Increased Transfers from Scotland – 2020 HVDC circuit Re-conductor or re-insulate existing double circuit overhead line route Full re-build or new build double circuit overhead line route Series compensation (equipment located at terminal substations) The incremental re
Slide 96: Range of Transfers Across B6 Boundary at Peak Demand
Range of Transfers Across B6 Boundary at Peak Demand Based on Central Scenario of 11.4GW of Wind Generation in Scotland 96
Slide 97: Proposed reinforcements
Proposed reinforcements 97 nationalgrid The power of action: )
Slide 98: Summary of proposed reinforcements
Summary of proposed reinforcements 2008/09 TR A N SM IS SIO N S YSTEM A S AT 31st D E C EM BER 2007 400kV Sub stations 275kV S ubstations 132kV S ubstations 400kV C ircuits 275kV C ircuits 132kV C ircuits M ajor G enerating S ites Including P um ped Storage C onne cted at 400kV TH E S H ET LA N D IS
Slide 99: Summary of proposed works
Summary of proposed works 99 Cost Capacity of generation which can be accommodated (GW) Wind Nuclear Total North of Scotand Upgrade Scotland - Stage 1, 2015 Incremental Scottish Upgrade | 625 8 0 8 NA 1565 Western HVDC Link 760 Scotland - North of Scotand Upgrade 450 Stage 2,2018 | Eastern HVDC Link
Slide 100: ENSG work – next steps
ENSG work – next steps • Report agreed and published • Integration with National Policy Statements/National Planning Framework • 2030 addendum being produced • Funding for pre-construction engineering work for 2009/2010 • Enduring regulatory arrangements for strategic investment being developed 100
Slide 101: The operational challenge
The operational challenge High Level Overview SO Workstream established How we will operate the system From now out to 2030 How will security of supply be maintained? Requirements for balancing services Costs/volumes Tools and technology development Smart and storage are sub-elements of this work Sc
Slide 102: Market Requirements
Market Requirements High level overview of study assess the market implications of the ‘Gone Green’ world. working with other industry members facilitated by Poyry holistic ‘market overview’ Provides necessary actions to meet energy policy objectives Examples of the questions posed are; Will the mar
Slide 103: Summary
Summary Scenarios developed Vision for 2020 network developed Work progressing to deliver it Additional capacity will become available 103
Slide 104: The Energy Policy Triangle - Summary
The Energy Policy Triangle - Summary Sustainable The renewables roadmap to 2020 The CO2 roadmap to 2050 Sustainable Removing Affordable Network Constraints Concentrate on simple efficiency measures and Scenario innovative ‘smart’ solutions as opposed to always Market Development Meeting the Op
Slide 105: Summary and Close
Summary and Close Duncan Burt Customer Services Manager
Slide 106: Feedback - Thank you
Feedback We would be grateful if you could complete the feedback forms provided Thank you See you next time 106