1. INTERNATIONAL DRAFT ESBI Workshop on OC October 9th-10th 2000 Presenters John Kennedy & Meadhbh Flynn

2. INTERNATIONAL DRAFT ESBI Workshop on OC October 2000 Agenda for the next two days Using the User Guide to Grid Code we will make presentations covering  General Conditions  Connection Conditions  Planning Conditions and Planning Code Appendix  Operating Codes 1-13  Special Dispatch Codes1-3 and Appendix  Glossary

3. INTERNATIONAL DRAFT ESBI Workshop on OC October 2000 The Format of the Presentations  Users Guide  Construct Flowchart of actions and events  “Breakout Groups” - to discuss issues and make changes  Use of flipcharts to capture unanswered questions and suggested changes  Role play of events to achieve better understanding  Plenty of time for Questions and Answers  A short post-workshop report will issue to tie-up outstanding issues

4. INTERNATIONAL DRAFT

5. DRAFT Purpose of Operating Code  Fundamentally a technical document containing the Rules governing the Operation, Maintenance, and development of the Transmission System  Gives Users an understanding of the Rules and provides for equitable treatment for all.  It refers to documents that are not part of the Operating Code e.g. transmission planning criteria, operating policies, interconnection  It does not address commercial issues - penalties -violations -failure of services  These are dealt with in other agreements

6. INTERNATIONAL DRAFT Hierarchy of documents

7. INTERNATIONAL DRAFT Precedence of Definitions  Importance of common understanding  Hence a Glossary is included  If a Term is Defined in the Operating Code it will take precedence over the definition in the Glossary

8. INTERNATIONAL DRAFT Governance  The Operating Code is a “living” document - it is subject to changes  Approved by RAE -brings it into being  Modifications, Updates, Derogation requests, will be approved by REA - keeping it alive

9. INTERNATIONAL DRAFT General Conditions  Makes provision for rules of a more general nature making a cohesive document allowing the operation of the transmission System for the benefit of all  Requirement of HTSO to establish and maintain the OCRP  Allows derogation rather than changes to design specifications  General Conditions requires users to comply with the”letter & spirit” of the code and provides HTSO with its rights  HTSO will act reasonably - “Prudent Utility Practice” It should be noted that if there a conflict between Operating Code and any other agreement the provisions of the Operating Code will prevail  If parts of the Operating Code unlawful/invalid the validity of all remaining provisions will not be affected

10. INTERNATIONAL DRAFT Connection Conditions  To protect plant certain minimum criteria are met - technical - design - operational  These are defined in Connection Conditions  This is to allow stable, secure operation of the transmission system  Compliance required from all users  Performance of the transmission system at the connection point to enable new users to design their equipment  For existing plant derogation will be through REA

11. INTERNATIONAL DRAFT CC Overall Structure

12. INTERNATIONAL DRAFT Planning Code  Planning code is necessary to allow development of the transmission system - demand growth - new connection - development of existing facilities  Planning code allows HTSO/User interaction covers - performance impacts on either side - information requirements of HTSO to allow it plan according to criteria and standards - Prepare Forecast statement

13. INTERNATIONAL DRAFT Planning Code- Outline of application procedure Complex Connection? User applies to HTSO for connection HTSO sends Connection Offer to User HTSO requests more data from User User sends Preliminary Project Planning Data to HTSO HTSO carries out further analyses HTSO sends revised Connection Offer to User User accepts offer? User sends Committed Project Planning Data to HTSO within 60 days HTSO and User signs Connection Agreement Yes HTSO publishes Forecast Statement and Use of System Tariffs Yes Connection Offer lapses if unaccepted by User before Connection Offer Expiry Date No

14. INTERNATIONAL DRAFT Operating Codes (OC)

15. INTERNATIONAL DRAFT OC1 Safety Co-Ordination  “Safety First” and so it is with the Operating Code OC1  Establishes the requirement of HMSO (or agents) as well as users ( or agents) to operate in accordance with approved Safety Rules. It is assumed that PPC’s will apply to everyone  Other rules allowable if complying with all national/international and legal requirements  Applies to interconnected systems

16. INTERNATIONAL DRAFT OC2 Information Exchange  This Code deals with - notification of event and event reporting - operational communication an data retention  Pre-connection communication is covered under Connection Conditions

17. INTERNATIONAL DRAFT OC2- Overall structure All Users Generators DSO Grid Connected Customer HTSO

18. INTERNATIONAL DRAFT OC3 Metering Code  For settlement purposes imported and exported MWh and MVArh are measured at defined points  OC3 specifies the minimum technical, design and operational criteria for metering and data collection  The Settlement System provides for payments due  Metering is provided by HTSO and DSO and will be registered in an appropriate system

19. INTERNATIONAL DRAFT OC 4 Demand Forecasting  Demand forecasting will be required over different time scales - Operational Planning - Programming - Control - Post Control  Exact HTSO responsibilities yet to be determined  Anyway will require typical profiles from DSO for defined categories of day type. HTSO will define these day types  Unnecessary duplication can be avoided by using information delivered under SD1 for centrally dispatched and embedded generation  Pumped storage generation treated as negative generation  Possible agreements required with external TSOs

20. INTERNATIONAL DRAFT OC4 Summary of information needed

21. INTERNATIONAL DRAFT OC4 Information for Demand Forecast Operational Planning Phase User Information Post Control Phase User Information HTSO conducts demand forecasting Historic Data User information Transmission losses System Events Other information Programming Phase User Information Control Phase User Information

22. INTERNATIONAL DRAFT OC5 Demand Control  Operator must feel comfortable with methods employed in Demand Control - Empowered to act  The operator should have extensive knowledge of control methods and act quickly in emergencies and if necessary break the rules if needed  Mainly DSO will act on behalf TSO - contact between suppliers and customers will need to reflect the necessity of demand control  There may be tariff arrangement that allow for a higher risk of disconnection  Exemptions - need arrangements in place

23. INTERNATIONAL DRAFT OC5 Overall structure

24. INTERNATIONAL DRAFT OC5 Demand Control Provision will be made for - Customer Demand reduction instructed by HTSO - Automatic low frequency demand disconnection - Automatic low voltage demand reduction - Automatic Demand Restoration

25. INTERNATIONAL DRAFT OC6 System Services  System services for network control and operation now more formalised (payments and measurements)  HTSO will manage these services and will specify what services will be provided and by whom  Generator licences must have a requirement to provide certain services on reasonable terms  Services include - Frequency control Voltage control Network control Operating Margin and Power System Restoration

26. INTERNATIONAL DRAFT OC7 Interconector Management  Interconnector management is part of prudent system control  OC 7 facilitates secure trading with neighbouring utilities  Trading planned over three day time frame requiring posting of Available Transmission Capacity (ATC) and then allowing Independent and Franchise sectors access  Reserve sharing and restoration services should be covered by bilateral agreements

27. INTERNATIONAL DRAFT OC7 Summary of procedure

28. INTERNATIONAL DRAFT OC8 Generator Maintenance Scheduling  The role of HTSO not clear yet in the new environment - will still have to produce a Transmission outage Programme - maintain capacity adequacy - ensure system security - Areas of special constraints - produce timely information to market participants

29. INTERNATIONAL DRAFT OC8 Generator Maintenance Scheduling  Schedule time frames 1- 5 years - Indicative Outage Programme (4 -5 years) - Provisional Outage Programme (2 - 3 years) - Committed Outage Programme (year 1)  HTSO approves outages from a security point of view  Obligation on Generators to move outages  Need to develop mechanisms for dispute resolution

30. INTERNATIONAL DRAFT OC8 Summary

31. INTERNATIONAL DRAFT OC8- Procedure when HTSO requests change to COP HTSO requests Generator to change COP Amend COPCOP not amended Generator agrees Generator has reasonable case for declining request HTSO accepts conditions HTSO does not accept conditions Generator agrees subject to conditions

32. INTERNATIONAL DRAFT OC8- Procedure when Generator requests change to COP Amend COP Capacity adequacy OK No amendment to Generator's proposal HTSO evaluates effect on Capacity Adequacy Capacity adequacy not OK Generator prepares new proposal for change to COP Generator requests change to COP Generator takes forced outage for unit HTSO and Generator discuss modification to Generators proposal HTSO informs Generator COP not amended Generator makes change to Declaration of Availability

33. INTERNATIONAL DRAFT OC9 Transmission Maintenance Scheduling  Maintenance year runs from July 1st- June 30th  Schedule time frames 1- 5 years - Indicative Transmission Outage Schedule (3 -5 years) - Provisional Transmission Outage Schedule (year 2) - Committed Transmission Outage Schedule (year 1)

34. INTERNATIONAL DRAFT OC9 Transmission Maintenance Scheduling  First Business Day of July, TO gives HTSO: –the CMPR for Maintenance Year 1 (MY+1) –the PMPR for Year MY+2 –the IMPR for MY+3 to MY+5. –the start date and time and the duration of each Outage.  TO should avoid a situation arising in which the TO is obliged to schedule an Outage at short notice  In rolling over the Transmission Outage Programme Requirements from one year to the next TO shall not be constrained in making any submission by any previous IMPR.  1 July - 31 August of MY, HTSO does security analysis of MY+1 to MY+5 in light of proposed Outages and other relevant matters including Outages of Generation Units, Interconnection and load growth.  HTSO will highlight any concerns with the Transmission Outage Programme Requirements to TO by the end August in MY.  31 Aug - 30 Sept: HTSO and TO discuss any concerns

35. INTERNATIONAL DRAFT OC9 Transmission Maintenance Scheduling  The HTSO shall issue to TO a Transmission Outage Schedule for Maintenance Year MY+1 to Maintenance Year MY+5 by the fifth (5th) Business Day of November in Maintenance Year MY, comprising –the Committed Transmission Outage Schedule (CTOS) for Maintenance Year MY+1 –the Provisional Outage Schedule (POS) for Maintenance Year MY+2 –the Indicative Outage Schedules (IOS) for Maintenance Years MY+3 to MY+5.

36. INTERNATIONAL DRAFT OC9 Overview

37. INTERNATIONAL DRAFT OC9 Outline procedure

38. INTERNATIONAL DRAFT OC9 Outline procedure

39. INTERNATIONAL DRAFT OC10 Monitoring Testing and Investigating  For HTSO to discharge its duties for safe secure and economic operation there is a need to carry out monitoring testing and Investigation of User’s Plant  HTSO is to ensure compliance with Operating Code and needs to establish agreed procedures separate from the Operating Code  OC10 does not apply to Operational testing but check that users are within their design, operating and connection requirements  Methods to deal with disputes are required

40. INTERNATIONAL DRAFT OC11 Operational Testing  Covers responsibilities and procedures to arrange and carry out Operational Tests - these test can affect HTSO and Users  Central co-ordination required since there will be implications foe security quality continuity and economic operation  Tests required by HTSO or Users - Requesting - Evaluation - Approval - Scheduling - Dispatching - Reporting - Disputes

41. INTERNATIONAL DRAFT OC11 Summary part 1 of 2

42. INTERNATIONAL DRAFT OC11 Summary Part 2 of 2

43. INTERNATIONAL DRAFT OC12 Emergency Control and Power System Restoration  OC12 is to ensure that after a partial or total system collapse normal supply is restored to all customers quickly and safely  Generator licences include a provision to offer black start capability to HTSO ( this can be tested under OC10)  Various proposed System Alerts are presented  An up to date Power System Restoration Plan is Required

44. INTERNATIONAL DRAFT OC12 Emergency Control and Power System Restoration

45. INTERNATIONAL DRAFT OC13 Small Scale Generator Conditions  Small scale generation is defined by HTSO as less than 5MW for a single site  Some sections of Operating Code do not apply  Some important codes still apply like OC8 Operational Planning. Here the HTSO needs information like seasonal load factors and running patterns.  OC13 deals with –Outage Scheduling - Changes to the Committed programme - information to be notified –Network control

46. INTERNATIONAL DRAFT Scheduling and Dispatch Codes SDC Codes

47. INTERNATIONAL DRAFT SDC1 Generation Scheduling  HTSO obligation to to schedule and dispatch generation  HTSO requires accurate and timely information relating to generation and supply  SDC1 specifies procedures for issuing a generation schedule for a trading day and Demand forecast  Thus generator receive an indicative dispatch for the following day and thus be available for operation  HTSO maintains an operating margin desired flows on interconnections

48. INTERNATIONAL DRAFT SDC1 Generation Scheduling  General Requirements - Demand Forecast - Declarations by Generators - Daily Nominations - Communication of Declarations - Communication of Daily Nominations - ATC for interconnections - Production of Generation Schedule (GS) - Procedure in absence of a daily nomination

49. INTERNATIONAL DRAFT SDC1 Generation Scheduling SDC1.4 The HTSO publishes demand forecast for next dispatch day by 11.00 SDC1.5-1.6 Generators send Declarations and Daily Offers for next Dispatch Day by 12.00 SDC1.8 Exporting Purchasers send Nominations for next Dispatch Day by 12.00. SDC1.10 The HTSO produces schedule between 13.00 and 16.00 for next dispatch day SDC1.10 The HTSO issues provisional running orders and publishes forecast system marginal price for each dispatch hour of next dispatch day

50. INTERNATIONAL DRAFT SDC2 Generation Dispatching  HTSO licence obligation to dispatch generation to meet demand  A structured process is required  SDC2 details the process to be used by HTSO decides the generation dispatch using the generation scheduled provided  HTSO procedure for communicating dispatch instructions - some details will depend on Market protocols

51. INTERNATIONAL DRAFT SDC2 Summary The HTSO forecasts Demand, sets reserve level and agrees ATC on interconnectors with External System Operators. HTSO issues dispatch instructions up to real time The HTSO issues dispatch instructions up to real time Accepted by Gen? Inform HTSO-must be for safety or emergency reasons Yes No Synchronising, desynchronising times Active Power Dispatch System Alerts Instruction in line with operating characteristics? Inform HTSO No Revise instruction Reactive Power Dispatch System Emergency Conditions Operating Mode Dispatch

52. INTERNATIONAL DRAFT SDC2 Dispatch Instructions: Synchronise/ desynchronise Yes Synchronising, desynchronising times Can synchronise within 10 mins. instructed time? Synchronise Effective redeclaration Can synchronise between 10 mins. & 4 hrs. instructed time? Issue redeclaration Yes No

53. INTERNATIONAL DRAFT SDC2 Dispatch Instructions: Active power, reactive power and operating mode dispatch Active Power Dispatch Achieve dispatch level within allowable tolerance consistent with Declarations Inform HTSO without delay if problem arises Reactive Power DispatchOperating Mode Dispatch Change operating mode consistent with Declarations

54. INTERNATIONAL DRAFT SDC2 Dispatch Instructions: Emergency Emergency Instruction Instruction may be outside Declared characteristics. Generator must comply except for safety reasons Inform HTSO without delay if problem arises

55. INTERNATIONAL DRAFT SDC3 Special Scheduling Provisions  SDC3 is to describe procedures to be adhered to by Users in defined special cases. –Congestion relief –Irrigation constraints –Minimum demand provisions –Renewable generation –Indigenous generation units –Hydro dispatch groups  Process for issuing instructions pursuant to SDC3 shall be in accordance with the provisions of SDC1 and SDC2.  Provisions of SDC3 do not supersede the provisions in SDC1 and SDC2.

56. INTERNATIONAL DRAFT SDC3 Irrigation Constraints Unconditional must-run output for each dispatch hour Availability for each dispatch hour Generator gives notice of constraints by 10.00 day ahead of dispatch day and specify:: IRRIGATION CONSTRAINTS Maximum and minimum available energy for dispatch day Schedule and dispatch - SDC1 & SDC2

57. INTERNATIONAL DRAFT SDC3 Hydro Dispatch Groups Unconditional must-run output for each dispatch hour Availability for each dispatch hour Generator gives notice of constraints by 10.00 day ahead of dispatch day and specify:: HYDRO DISPATCH GROUP CONSTRAINTS Maximum and minimum available energy for dispatch day Schedule and dispatch - SDC1 & SDC2 Generator must meet certain constraints to qualify as Hydro Dispatch Group

58. INTERNATIONAL DRAFT THE END Thank you from Meadhbh & John