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Cross-Codes Forum 18 October 2013

Cross-Codes Forum 18 October 2013. Evacuation Muster Point. If there is an alarm, follow the instructions of the Fire Wardens The evacuation point is here…. Update on BSC Modifications. David Kemp. 18 October 2013. Active BSC Modifications. BSC Modifications – P272 (1 of 2). Issue:

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Cross-Codes Forum 18 October 2013

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  1. Cross-Codes Forum 18 October 2013

  2. Evacuation Muster Point If there is an alarm, follow the instructions of the Fire Wardens The evacuation point is here…

  3. Update on BSC Modifications David Kemp 18 October 2013

  4. Active BSC Modifications

  5. BSC Modifications – P272 (1 of 2) • Issue: • HH Settlement for PCs 5-8 not currently enforced • New meters in PCs 5-8 must be ‘advance/smart’ • All PC 5-8 meters to be ‘advanced/smart’ by 2014 • Proposed Solution: • All SVA Metering Systems for PCs 5-8 will be settled as HH from April 2014 • Alternative Solution: • As Proposed, but from April 2015

  6. BSC Modifications – P272 (2 of 2) • Panel’s Recommendation: Reject both Proposed and Alternative • Recommend implementation on 1 April 2014 (Pro) or 1 April 2015 (Alt) • Currently with Authority for decision

  7. BSC Modifications – P276 (1 of 1) • Issue: • Partial Shutdown would suspend entire Market • Disproportionate for small localised Partial Shutdowns • Approved Solution: • Introduce Market Suspension Threshold • If not met, Market continues as normal • Does not affect Total Shutdowns • Approved for implementation on 31 March 2014 • Authority: Better facilitates ABOs (b), (c) and (d)

  8. BSC Modifications – P283 (1 of 1) • Issue: • Hard to perform full commissioning of Metering Equipment • Some equipment not within control of Registrant or MOA when commissioning required • Approved Solution: • Relevant SO responsible for commissioning CTs/VTs & providing certificates/records • MOAs would assess performance; notify Registrant of potential uncontrolled risks • Registrant works with SO to minimise risks • Approved for implementation on 6 November 2014 • Authority: Better facilitates ABOs (b), (c) and (d)

  9. BSC Modifications – P286 (1 of 2) • Issue: • CMP201 proposes to remove BSUoS from generation BM Units • If approved, creates potentially anomalous situation where Parties liable for RCRC but not liable for BSUoS • Proposed Solution: • Exclude generation BM Units from RCRC • Generation BM Unit: BM Unit in a delivering Trading Unit

  10. BSC Modifications – P286 (2 of 2) • Panel’s Recommendation: Approve • Recommend implementation on 1 April 2015 • Currently with Authority for decision

  11. BSC Modifications – P291 (1 of 1) • Issue: • REMIT requires public reporting of inside information • Preference for use of central reporting platforms • Approved Solution: • Place an inside information reporting platform on BMRS • Messages submitted via Grid Code or ELEXON Portal • Approved for implementation on 31 December 2014 • Authority: Better facilitates ABOs (b), (c) and (d)

  12. BSC Modifications – P292 (1 of 1) • Issue: • New operating model – only Suppliers will be able to configure Smart Meters under the DCC • This has a direct impact on responsibilities for sending MTDs • Approved Solution: • Provide ‘hook’ in Code to enable implementation of detailed requirements (CP1388/CP1395) • Approved for implementation on 26 June 2014 • Authority: Better facilitates ABO (d)

  13. BSC Modifications – P294 (1 of 2) • Issue: • Offshore generator required to install metering at Boundary Point during development • This metering becomes defunct when Offshore Transmission Assets are transferred to the OFTO • Proposed Solution: • Amend definition of ‘Total System’ • Include ‘Offshore Transmission System’ and ‘OTSUA’ • Address confusion between BSC and Grid Code • Remove requirement to install metering at Boundary Point

  14. BSC Modifications – P294 (2 of 2) • Panel’s initial Recommendation: Approve • Final Recommendation at November meeting • Recommend implementation 5WD after Approval

  15. BSC Modifications – P295 (1 of 2) • Issue: • Transparency regulation requires data to be published on EMFIP • TSOs provide this information to ENTSO-E • Proposed Solution: • BMRA act as data provider for National Grid’s data • Data also published on BMRS • Potential Alternative Solution: • As Proposed, but with Interconnector data also published on BMRS • Int. Administrators to submit info to BMRA in parallel with submitting to ENTSO-E

  16. BSC Modifications – P295 (2 of 2) • Undergoing assessment by Workgroup • Assessment Report to Panel in November • Proposing implementation on 31 December 2014 • Report Phase Consultation will be issued in November

  17. BSC Modifications – P296 (1 of 1) • Issue: • CGR2 introduces new ‘Fast Track’ Modifications • Required to be introduced into BSC • Approved Solution: • Introduce new ‘Fast Track’ process into BSC • Used to progress minor housekeeping changes quickly • Approved for implementation on 6 November 2013 • Authority: Better facilitates ABOs (a) and (d)

  18. BSC Modifications – P297 (1 of 2) • Issue: • Grid Code EBS Group has made changes to the Dynamic Data Set • Proposed Solution: • Amend BSC to ensure data on BMRS corresponds with data submitted to Transmission Company by Parties

  19. BSC Modifications – P297 (2 of 2) • Undergoing assessment by Workgroup • Assessment Report to Panel in November • Proposing implementation on 6 November 2014 • Currently out for Assessment Consultation • Responses due by 24 October • Report Phase Consultation will be issued in November

  20. Consultations • Current Consultations: • P297 Assessment Consultation – responses due by 24 October • Upcoming Consultations: • P295 Report Phase Consultation – November • P297 Report Phase Consultation – November This will be your final chance to comment on these Modifications

  21. Where can I find more information? www.elexon.co.uk/change/modifications/

  22. Any Questions?

  23. CUSC Changes Adam Hipgrave Cross Codes Forum 18 October 2013

  24. CUSC Modifications Process Change raised Urgent process Panel decision on progression Appeal to Competition Commission Panel Vote Workgroup assessment Industry consultation Ofgem decision to approve or reject Final report to Ofgem optional

  25. CUSC Modifications • CMP201 – Removal of BSUoS charges from Generators • Seeks to align GB arrangements with other EU Member States by removing BSUoS charges from GB Generators. • Panel voted on 26 April 2013 and Final Report sent to Ofgem on 9 May 2013. • Ofgem will be publishing their Impact Assessment shortly

  26. CUSC Modifications (2) CMP213 – Project TransmiT TNUoS Developments • Made up of 3 main elements – Network Capacity Sharing, Inclusion of HDVC in the charging calculation and inclusion of island links into the charging methodology. • Complex and extensive Workgroup process. • 26 Workgroup Alternative CUSC Modifications (WACM) • Panel voted in May that 8 of the 26 WACMs better facilitated the Objectives. • Final Report sent to Ofgem on 14 June 2014. • Impact Assessment closed on the 10th October 2013, awaiting Ofgem decision.

  27. CUSC Modifications (3) • CMP218 – Changes required for use of new banking product to hold Users’ cash securities • Seeks to facilitate the use of a new banking product by NGET. • Raised in March 2013 and is being progressed as Self-governance. • Code Administrator Consultation closed on 4 July 2013. • The Panel voted unanimously that CMP220 better facilitates the Applicable CUSC Objectives. • Implemented on 16th October 2013.

  28. CUSC Modifications (4) • CMP219 – CMP192 Post Implementation Clarifications • Seeks to address issues with the legal text for CMP192 (Arrangements for Enduring Generation User Commitment) identified following its implementation. • Raised in June 2013. • Code Administrator Consultation was published on the 2 October 2013 and closes on 30th October2013. • Being progressed as self-governance; Panel Determination Vote to be carried out in November.

  29. CUSC Modifications (5) • CMP221 – Interruption Compensation in the absence of Market Suspension during Partial Shutdown • Seeks to extend the existing CUSC compensation to cover Settlement Periods during a Partial Shutdown where market operations continue. • Raised in September 2013. • Code Administrator Consultation was published on the 1st October and closes on 29th October.

  30. CUSC Modifications (6) • CMP222 – User Commitment for Non-Generation Users • Generation user commitment for pre- and post-commissioning sites was introduced into the CUSC in April 2012 for April 2013 go-live. • Seeks to introduce enduring user commitment arrangements for interconnector and demand users by April 2015. • Raised September 2013. • First Workgroup meeting to be held on the 18th October.

  31. CUSC Modifications (7) • CMP223 – Arrangements for Relevant Distributed Generators under the Enduring Generation User Commitment. • Seeks to address issues associated with the way liability and security terms and conditions are set and calculated for distribution connected generators • Raised September 2013. • First Workgroup meeting to be held on the 18th October.

  32. CUSC Modifications (8) • CMP224 – Cap on the Total TNUoS Target Revenue to be recovered from Generation Users • Seeks to ensure that the average annual generation transmission charges remain within the current prescribed European Commission range until December 2014, and within the revised range (if modified after ACER’s review) that may come into force from 1st January 2015. • Raised September 2013. • First Workgroup meeting to be held on the 24th October.

  33. Contact Information • Email: • cusc.team@nationalgrid.com • Website: • http://www.nationalgrid.com/uk/Electricity/Codes/systemcode/

  34. Any questions? Adam Hipgrave National Grid Commercial Analyst - European Code Development Transmission Network Services | Markets & Balancing DevelopmentNational Grid House, Warwick Technology Park, Warwick, CV34 6DA T: 01926 656191 M: 07825193568E: adam.hipgrave@nationalgrid.com

  35. Grid Code Changes Adam Hipgrave Cross Codes Forum 18 October 2013

  36. GC0042 Information on Embedded Small Power Stations and Impact on Demand • The Workgroup determined that further information than what is currently provided under PC.A.4.3.2 is required to enable National Grid to efficiently plan and securely operate the transmission system. • A list of additional requirements was agreed upon for each Embedded Small Power Stations (ESPS) of 1 MW and above • The Distribution code will be be reviewed to enable the DNOs to capture any additional information that they are currently not entitled to receive • Implementation date for the above information to be submitted was agreed to be the Calendar Week 24 data submission beginning 2015. • Workgroup Report was presented at the September GCRP. • Industry Consultation anticipated early 2014 (in line with the DCode).

  37. GC0050 Demand Control and OC6 • The Workgroup was tasked with assessing the existing capabilities of the industry to implement Demand Control instructions and evaluate whether current requirements are still fit for purpose. • The Workgroup determined and assessed: • The need for, and requirements of, Demand Control Instructions • Existing capabilities of the DNOs to implement Demand Control Instructions • The costs, benefits and risks of any actions necessary to ensure that DNOs can implement the required Demand Control Instructions in the required timescales under future system requirements • Demand Reduction tests ongoing during October • GC0050 Workgroup Report to be presented to January GCRP.

  38. GC0063 Power Available • The Workgroup have defined and critically reviewed the deficiencies • A number of options have been considered, and the Workgroup are likely to recommend • the submission of Power Available as an operational metering signal which would be fed to the National Grid Control Centre via SCADA with the definition of MEL used to indicate electrically connected capacity. • There are still questions regarding the costs of implementation, and retrospective application that require further analysis • The Workgroup is expected to present the Workgroup Report at the November GCRP and carry out an Industry Consultation during December.

  39. GC0035 Frequency Changes during Large Disturbances and their effect on the total system • The joint DCRP and GCRP Workgroup is examining how the maximum rate of change of frequency (RoCoF) seen by the electricity networks in GB is likely to increase, and how this impacts on the effectiveness of RoCoF based Loss of Mains (LOM) protection. • Phase 1 (5-50MW Total Registered Capacity) • Workgroup report presented in July • Recommended changing RoCoF to 1Hzs-1 measured over 500ms • Industry Consultation closed on 27 September • Workgroup are reviewing the responses before presenting their recommendation to Ofgem • Phase 2 • Incorporates sub 5MW machines, inverter technology and multi-machine islands • Requests for proposals for two independent studies will be published soon • Workgroup will develop RoCoF withstand requirements

  40. Other areas of note • GC0033 (Offshore Wind Farms not connected to an Offshore Transmission System) • The Authority decision is expected on 22 October • GC0037 (BMU Configurations Offshore) • National Grid are reviewing the Industry Consultation response • GC0071, 72 and 73 (Code Governance Phase 2 Modifications) • The Authority decision is expected on 18 October

  41. Contact Information • Email: • grid.code@nationalgrid.com • Website: • http://www.nationalgrid.com/uk/Electricity/Codes/gridcode/

  42. Any questions? Adam Hipgrave National Grid Commercial Analyst - European Code Development Transmission Network Services | Markets & Balancing DevelopmentNational Grid House, Warwick Technology Park, Warwick, CV34 6DA T: 01926 656191 M: 07825193568E: adam.hipgrave@nationalgrid.com

  43. DCUSA Change Proposals Update Michael Walls Governance Services Senior Analyst – ElectraLink Ltd. Email: michael.walls@electralink.co.uk Tel: 020 7432 3014

  44. What is the DCUSA? • The Distribution Connection and Use of System Agreement is a multi-party contract between the licensed electricity distributors, suppliers and generators of Great Britain • The DCUSA defines the rules for connecting and using the UK’s electricity network distribution systems • It is essentially a legal contract which commenced on 6 October 2006 • Parties to the DCUSA include: DNOs, Suppliers, IDNOs, DG, Gas Suppliers and OTSO

  45. Current DCUSA Activities DCUSA website review Smart Metering 31 Change Proposals in progress 21 of those are Charging Related Theft of Electricity (CoP) Induction training sessions Code Administration Code of Practice Next DCUSA Release 7 November 2013

  46. DCUSA Change Process - Overview Pre-Change Process (Charging methodology changes) CP raised Modelling Resource Initial Assessment Working Group Assessment Industry Consultation Change Report Implementation Party Voting Change Declaration Authority Consent

  47. Overview of the DCMF MIG Pre-Change Process DCMF MIG DCMF DCUSA Originator Issue submitted Issue defined Recommendation Decision CP Raised From Pre-Change Process to formal DCUSA Change Process Modelling Resource Industry Consultation Working Group Change Report Outcome Voting Implemented

  48. Overview of Common Distribution Charging Methodologies in DCUSA Open Governance - CDCM and EDCM • The governance and change management processes for the Common Distribution Charging Methodology (CDCM) were implemented into the DCUSA on 01 January 2010. • The governance and change management processes for the EHV Distribution Charging Methodology (EDCM) (import) were implemented into the DCUSA on 01 April 2012. • The governance and change management processes for the Common Connection Charging Methodology (CCCM) were implemented on 30 October 2012. • The governance and change management processes for the EDCM (export) were implemented on 01 April 2013. • As the methodologies will be common among all DNOs, this brings about many improvements, such as: • More transparency, and as the complexities of the methodologies have been agreed, dialogue among all Parties have to be taken into account for any change; and • When there is a change brought about by any Party, all DNOs must implement it and model the changes.

  49. The National Terms of Connection • Unless otherwise agreed, the NTC is the connection agreement between the end user and the distributor • When you enter into your electricity supply contract with your supplier, you are also entering into a connection agreement with your electricity network operator on these terms

  50. Charging Methodology CP Summary

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