Market Rules Procedure on

Transcription

1 ver. 1.0 Page 1 from 27 Transmission System and Market Operator of Kosovo (KOSTT) February 2015

2 ver. 1.0 Page 2 from 27 Department: Market Operator This Market Rules procedure (including as subsequently amended) is made pursuant to paragraph (b) of the wholesale Market Rules prepared in accordance with Article 24, paragraph 6 of the Law on Electricity (Law No.03/L -201). 1 Objectives and Scope of Application 1.1 Objectives This procedure sets out the processes needed for all Trading Parties to ensure that Metering Data submitted for Settlement: (a) (b) (c) Are based on an accurate record of the volume of energy flowed through the Metering System between two points in time; or Are estimated using an approved methodology (as set out herein); or Are replaced by more accurate estimates determined in accordance with the methodologies set out in this Market Rules Procedure. 1.2 Scope This Market Rules Procedure sets out general principles applicable to collecting, validating, substituting and estimating Metering Data This Market Rules Procedure sets out processes and timetable for the relevant Network Operator to submit: (a) For each Generating Unit Metering System: (i) (ii) In accordance with Paragraph of the Market Rules, Actual Metering Data; In accordance with Paragraph of the Market Rules, Estimated Metering Data; (iii) In accordance with Paragraph 16.9 of the Market Rules, Metering Data to replace either Estimated Metering Data or Actual Meter Data; (b) For each Interconnector Trader Balancing Unit: 2

3 ver. 1.0 Page 3 from 27 (i) (ii) In accordance with Paragraph of the Market Rules, the confirmed Interconnector Nomination, which will be treated as Actual Metering Data; In accordance with Paragraph of the Market Rules, where the confirmed Interconnector Nomination is not available for any reason, an estimated Interconnector Nomination, which will be treated as Estimated Metering Data; (iii) In accordance with Paragraph 16.9 of the Market Rules, Metering Data to replace either Estimated Metering Data or Actual Meter Data; (c) For each Metering System at a TSO/DSO Commercial Boundary: (i) (ii) In accordance with Paragraph of the Market Rules, Actual Metering Data; In accordance with Paragraph of the Market Rules, Estimated Metering Data; (iii) In accordance with Paragraph 16.9 of the Market Rules, Metering Data to replace either Estimated Metering Data or Actual Meter Data. (d) For each Eligible Customer Interval Metering System (whether connected to the Transmission Network or the Distribution Network): (i) (ii) In accordance with Paragraph of the Market Rules, Actual Metering Data; In accordance with Paragraph of the Market Rules, Estimated Metering Data; (iii) In accordance with Paragraph 16.9 of the Market Rules, Metering Data to replace either Estimated Metering Data or Actual Meter Data; This Market Rules Procedure sets out the timetable for the MAA to make available valid Metering Data for Interval Meters to Settlement The timetable for making aggregated Customer Non-interval Meter Data available to Settlement is identified in the Metered Energy Allocation. 3

4 1.3 Terms used in this Market Rules Procedure ver. 1.0 Page 4 from The following terms will be used in this Market Rules Procedure: (a) (b) (c) (d) Actual Metering Data, which will be Metering Data for a Settlement Period derived from the deemed (in the case of an Interconnector or Eligible Customer supplied through a Non-interval Meter) or actual reading of physical Meters; Estimated Metering Data, which will be Metering Data for a Settlement Period derived from estimates of Metering Data for relevant Metering System; Period Advance is the calculated volume of energy that has passed through a Metering System in a Settlement Period. Metering Data Report is a report containing details of the Metering Data or Estimated Metering Data for one or more Metering Systems All other terms in bold will have the same meaning as terms used in the legislation in force or in the license as appropriate. 2 General principles 2.1 Overview For each Settlement Run, the MO is required to have a complete set of Metering Data with respect to each Metering System and therefore, the relevant Network Operators and the MAA must provide either Estimated Metering Data (where Actual Metering Data is unavailable) or Actual Metering Data in time for the Settlement Run The relevant Network Operator shall carry out the collection and initial validation of meter readings to assess their fitness for use in Settlement. Each Network Operator shall collect data in accordance with the requirements of this procedure for those Metering Systems for which their responsibility for meter reading is defined in section 7 of the Metering Code Where Metering Data fails initial validation, the Network Operator may carry out a number of remedial steps before repeating the validation process including, recollecting the Metering Data where this is an option Once the initial validation has been carried out, the Network Operator shall, where appropriate, replace the Actual Metering Data with Estimated Metering Data or substituted Actual Metering Data and shall forward it to the MAA who shall aggregate this data and make it available for Settlement. 4

5 ver. 1.0 Page 5 from 27 Department: Market Operator Once Metering Data have been submitted for Settlement, such data will be treated as final with respect to Settlement but may be updated subsequently if better estimates or actual information become available. 2.2 De-energized Meters Before De-energizing any Metering System where such De-energization will result in the NO being unable to capture data from any part of the Metering Installation, the NO shall collect the cumulative Metering Data and the Metering Data for each Settlement Period (if available) before and as close to the time of De-energizing the Metering Installation as is practicable The NO shall record a cumulative Meter reading immediately before the Metering Systems is De-energized together with the time of the reading. Where appropriate, the NO shall use these cumulative readings, to generate estimated consumption data for the Settlement Periods between the remote capture of data by the NO and the time of De-energization The NO shall record each occasion that the Metering Installation has been Deenergized or re-energized and the dates and times they were De-energized or re-energized The NO shall attempt to collect Metering Data from each Metering Installation which has been recorded as De-energized in accordance with the following timetable: For all Metering Installations where a communications link to the Metering Installation is operational every 5 Working Days. For all Metering Installations where no operational communications link exists and site visits are required every 20 Working Days If any attempt to collect Metering Data from a Metering Installation registered as De-energized provides data which indicates consumption has taken place or is taking place, the NO shall advise the registered Supplier within 2 Working Days. The NO shall investigate the circumstances and advise the Supplier, if appropriate, of the appropriate action to follow within 5 Working Days. 3 Data Collection from Interval Meters The NO shall collect, validate and record all Settlement Period data for Active Energy and cumulative consumption, including any associated alarms, as required for Settlement purposes. In addition, the NO shall collect, validate and record all Settlement Period data for Reactive Energy, cumulative consumption and 5

6 ver. 1.0 Page 6 from 27 Department: Market Operator maximum demand, including any associated alarms, as required for the purposes of calculating network access tariff Data from main and check Meters for all Metering Installations that are Interval Metering Installations shall be collected and validated by the NO. The NO shall pass all appropriate data to all relevant parties: by the time specified in section 7.2 to allow the MO Settlement liabilities of all Trading Parties, or to calculate the by on the third Working Day of the calendar month following the calendar month in which the day, which includes the Settlement Period, falls whichever is the earlier. 3.2 Data Capture from Automated Meter Reading Systems The NO shall establish a data collection routine where each Meter is polled at sufficient frequency to ensure: i. that all data is collected before any register can be overwritten, and ii. that all data is collected and processed within the required timescales detailed in section Where it is discovered that data cannot be downloaded remotely, the NO shall visit the Connection Point and electronically download all Metering Data within [3] Working Days of discovery of the problem and before any register is overwritten, making all necessary arrangements for access with the System User. 3.3 Manual Reading The NO shall establish a data collection routine where each meter is visited at sufficient frequency to ensure: a) that all data is collected before any register can be overwritten, and b) that all data is collected and processed by on the third working day of the calendar month following the calendar month in which the day, which includes the Settlement Period, falls The NO shall visit the Connection Point and electronically download all Metering Data before any register is overwritten making all necessary arrangements for access with the System User. Each visit to the premises of a 6

7 ver. 1.0 Page 7 from 27 Department: Market Operator System User or NO shall be undertaken in accordance with the the principles established in section Meter Reading at Change of Meter Before a Metering Installation is to be changed or reprogrammed, the NO shall collect the cumulative Metering Data and the Metering Data for each Settlement Period as close to the time of changing or reprogramming the (metering equipment) Metering Installation as is practicable. Meter replacement or reprogramming shall not be undertaken within 10 minutes of the end of a Settlement Period and only after the NO has confirmed collection of the Metering Data for that Settlement Period The NO shall record a cumulative Meter reading immediately before and immediately after the Metering Installation has been changed or reprogrammed together with the time of each reading. The NO shall use these cumulative readings, together with details of the nature of the work undertaken, to generate estimated consumption data for the Settlement Period during which the collected Metering Data will have been affected by the work undertaken. 3.5 Metering Installation Data Collection Checks A Metering Installation data collection check will be carried out whenever: i. a Metering Installation is first Energized, ii. iii. iv. a Meter or Primary Data Storage Device is replaced by another, a Meter or Primary Data Storage Device is reprogrammed, there has been a change to any CT or VT connections or ratios; and v. once every three months where the cumulative energy value is not available for remote reading. Where a Connection Point has been temporarily De-energized and any of the changes listed in (ii), (iii) or (iv) undertaken, it will be permissible to delay undertaking the Metering Installation data collection check until such time as the Metering Installation is re-energized Whenever it is necessary to undertake a Metering Installation data collection check, the NO shall record the Settlement Period consumption data while on site and shall then compare the actual data obtained on site request that Settlement Period consumption data that it has collected for the same period both as raw data and following processing to provide kwh energy consumption and kw demand and shall either confirm that the collected data is accurate or determine any necessary programming changes required to ensure that the NO will collect and process accurate data. 7

8 ver. 1.0 Page 8 from Where it is necessary for a NO to remotely make programming changes to ensure that accurate data can be collected and processed, a Metering Installation data collection check shall be carried out within three Working Days of these programming changes being made. 4 Data Collection from Non-interval Meters 4.1 Automated Meter Reading Systems Electronic Data Capture (a) (b) The NO shall establish a data collection routine where each Meter is polled at sufficient frequency to ensure: i. that all data is collected before any register can be overwritten, and ii. that all data is collected and processed within the required timescales. Where it is discovered that data cannot be downloaded, the NO shall visit the Connection Point and electronically download all Metering Data before any register is overwritten, making all necessary arrangements for access with the System User Monthly consumption and maximum demand data for all Non-interval Metering Systems that are normally read using an automated Meter reading system shall be collected and validated by the NO and the resulting data passed to all relevant Parties by on the seventh Working Day of the following calendar month. 4.2 Metering Installation Data Collection Checks A Metering Installation data collection check will be carried out whenever: i. a Metering Installation is first Energized, ii. a Meter or Primary Data Sstorage Device is replaced by another, iii. a Meter or Primary Data Sstorage Device is reprogrammed, iv. there has been a change to any CT or VT connections or ratios. Where a Connection Point has been temporarily De-energized and any of the changes listed in (ii), (iii) or (iv) undertaken, it will be permissible to delay undertaking the Metering Installation data collection check until such time as the Metering Installation is re-energized Whenever it is necessary to undertake a Metering System data collection check, the NO shall interrogate the Primary Data Storage Device on two occasions 8

9 ver. 1.0 Page 9 from 27 Department: Market Operator that a representative of the NO is on site to record the consumption data. The NO shall then compare the actual data obtained on site with the Settlement Period consumption data that it has collected for the same period both as raw data and following processing to provide kwh energy consumption and kw demand and shall either confirm that the collected data is accurate or determine the programming changes required to ensure that the NO will collect and process accurate data Where it is necessary for a NO to make programming changes to ensure that accurate data can be collected and processed, a further Metering System data collection check will be carried out within three Working Days of these programming changes being made. 4.3 Meter Reading at Change of Meter Before a Metering System is to be changed or reprogrammed, the NO shall collect the cumulative Metering Data as close to the time of changing or reprogramming the Metering System as is practicable The NO shall record a cumulative Meter reading immediately before and immediately after the Metering System has been changed or reprogrammed together with the time of each reading. The NO shall use these cumulative readings, together with information regarding the nature of the work undertaken, to generate actual or estimated consumption data for the Metering System. 5 Manual Reading of Non-Interval Meters 5.1 Routine Reading by NO The NO shall establish a Meter reading schedule designed to ensure that a visit will be made to every Connection Point where Non-Interval Meters are installed and reading is not normally undertaken using an automated Meter reading system: in the case of Meters fitted with a maximum demand register or indicator, once each month on the fifth Working Days. in the case of Meters which have not been fitted with a maximum demand register or indicator, at least once in every [six] months The NO shall advise the Supplier of the visit schedule Each visit to the premises of a Customer will be undertaken in accordance with the provisions of section 11. The NO shall validate and process the collected data in accordance with the requirements of sections 7. 9

10 ver. 1.0 Page 10 from Where the NO has been unable to gain access during routine visits, the NO shall make arrangements with the Customer for a special visit to gain access to the Connection Point at least once each year in the case of CT operated metering or at least once in every two years in all other cases. 5.2 Meter Reading at Change of Meter The NO shall record a cumulative Meter reading immediately before and immediately after the Metering System has been changed or reprogrammed together with the time of each reading. The NO shall use these cumulative readings, together with information regarding the nature of the work undertaken, to generate actual or estimated consumption data for the Metering System. 5.3 Customer Readings When so requested by the NO or their Supplier, the Customer shall take a reading for every register of the Metering System through which their supply is provided within the first 5 days of each month. The Customer shall record the date, meter type and serial number together with all register readings identified with the number or description of the register. The Customer shall forward the recorded details to the NO or their Supplier, as appropriate by the fifteenth day of the month using the mechanism specified by the NO or Supplier If Metering Data is provided to the Supplier in any circumstances, the Supplier shall forward the information to the NO for validation and processing for Settlement and Network Access Tariff purposes. 5.4 Date and Time of Reading Whenever a reading is taken by manual means, the date on which the reading is taken shall be recorded and it will be deemed that the reading occurred at /24.00 on the date on which the reading was taken. 5.5 Allocation of Energy to Settlement Period Where a Non-interval Meter is used in accordance with the requirements of these metering rules and all other relevant regulations, the energy deemed to have been consumed in each Settlement Period will be calculated by allocating energy according to the same profile as the system residual once all interval metered energy has been allocated. 6 Validation of Meter Readings The following steps are covered in this section: 10

11 ver. 1.0 Page 11 from 27 (a) MO provides Network Operators and MAA with the profile of consumption of electrical energy over the latest 720/744 Settlement Periods for which it has complete data for flows across Connections for which they are responsible for the provision of Metering Data. Consumption will be determined as the difference between all flows onto the Transmission System (adjusted for the prevailing Transmission Losses) and the sum of all exports across the Interconnections; (b) Network Operator receive Actual Metering Data for the relevant Settlement Period and carry out an initial validation exercise in accordance with Section 7: (i) (ii) Where the Actual Metering Data passes the initial validation test then the Actual Metering Data is Provisionally Valid Metering Data; Where the Actual Metering Data fails the relevant validation test then the Actual Metering Data is Provisionally Error Metering Data; (iii) Where the Network Operator has any reason to believe that the Actual Metering Data is false then the Actual Metering Data is Provisionally Error Metering Data; (c) (d) Following initial validation by the Network Operator the Metering Data shall be transferred to the MAA. The MAA receives Actual Metering Data for the relevant Settlement Period and may carry out a secondary validation exercise in accordance with Section 7: (i) (ii) Where the Actual Metering Data passes the secondary validation test then the Actual Metering Data is Provisionally Valid Metering Data; Where the Actual Metering Data fails the relevant validation test then the Actual Metering Data is Provisionally Error Metering Data; (iii) Where the Network Operator or the MAA have any reason to believe that the Actual Metering Data is false then the Actual Metering Data is Provisionally Error Metering Data; 11

12 ver. 1.0 Page 12 from 27 (e) (f) (g) Where the Actual Metering Data is Provisionally Error Metering Data, the MAA will return such data to the relevant Network Operator to determine Estimated Metering Data in accordance with Section 7. The MAA submits the Estimated Metering Data and the Actual Metering Data to the Registrant (including the assessment of validity) in a Metering Data Report. The Registrant may respond to the proposed estimate with a revised estimate and the MAA will instruct the NO to agree an estimate. Failure to respond to the Metering Data Report issued in step (c) will result in the data contained in the original report being used in Settlement Meter Reading Status Codes will be one of the following: (a) (b) (c) (d) (e) A0 Valid Actual Metering Data A1 Valid Actual Metering Data replacing a false actual or a previous Estimate used in Settlement E0 Estimate generated by the relevant Network Operator E1 Estimate agreed with Registrant E3 Estimate used to replace either a false actual or a previous estimate that had already been used in Settlement. 7 Validation of Actual Meter Readings 7.1 Confirmation of Data Completeness The NO shall, prior to undertaking validation checks on actual Meter readings, confirm that complete data for the particular Metering System has been collected The NO shall, prior to undertaking validation checks on actual meter readings, confirm that no unexplained zeros exist in the data that has been collected for any particular Metering System. Where unexplained zeros exist, the NO shall, as far as is practicable, validate the remaining data. Should the remaining data pass the validation checks, it should be considered provisionally valid Metering Data and estimated values created to replace the unexplained zeros in accordance with the provisions of section 9. 12

13 ver. 1.0 Page 13 from Validation of Metering Data for Generating Units, TSO/DSO interface and Supply Points Within 1 WD following Day D, the NO shall complete the download of Metering Data from the Metering System and provide a Metering Data Report to the Registrant Metering Systems covered by this section shall include those at Generating Units and Supply Points connected to the Transmission or Distribution Systems and Connections between the Transmission and Distribution Systems The Metering Data will be initially validated using the following checks. Metering Data will be Provisionally Error Metering Data where: (a) The outstation or Meter identifier is different from that registered in the data collection system. (b) Main/check errors associated with corresponding Meter registers exceed the limits in the following table: Connection Type Connections between Transmission System and other systems and Generating units 100 MW Connections between distribution systems, generating units < 100 MW and supply points of eligible Customers and supply points where the Regulator determines that interval metering is required 10MW Supply points of eligible Customers and supply points where the Regulator determines that interval metering is required 1MW Active Energy Register Reactive Energy Registers At >5% of At >2% At 2% of Max Value and 5% Max Value At >10% At 10% for of Max for of Max of Max Channel Value for Channel Value for Value for Channel Channel Channel ± 0.30% ± 0.50% ± 1.00% ± 3.00% ± 6.00% ± 0.75% ± 1.00% ± 2.25% ± 3.00% ± 6.00% ± 1.50% ± 2.00% ± 2.50% ± 4.50% ± 9.00% 13

14 ver. 1.0 Page 14 from 27 Connection Type Supply points of eligible Customers and supply points where the Regulator determines that interval metering is required < 1MW Active Energy Register Reactive Energy Registers At >5% of At >2% At 2% of Max Value and 5% Max Value At >10% At 10% for of Max for of Max of Max Channel Value for Channel Value for Value for Channel Channel Channel ± 3.00% ± 4.00% ± 5.00% ± 4.50% ± 9.00% 1. Where it has been confirmed in accordance with section 10 that a value which has failed this check is valid Actual Metering Data, the Network Operator shall continue to perform this check on all subsequent data which will not fail validation in the following [six] months provided:this is the only check which indicates that data may be invalid; 2. The limit of the main error in each current range does not change; and 3. At no time does the main/check error exceed 1.5 times the accuracy limit for those parts of the Metering System which are not shared by the main and check Meters. (c) (d) There are Primary/Secondary errors associated with corresponding channels. Any instances where the values of compared channels differ by an amount that exceeds the tolerances prescribed in the Metering Code due to allowable time-shift shall be reported. This validation can only be performed where both Primary and Secondary Data Concentrators are installed and the associated data collected. This includes situations where, in some Meter configurations, there is a Secondary Check Meter available. Time errors are outside: (i) (ii) ± 20 seconds in the case of Connections to the Transmission System, generator Connections to a Distribution Network or Connections between Distribution Networks; or ± 15 minutes in the case of Supply connections. Provided that time errors are not outside these limits, the outstation time should be corrected by the data collection system on each occasion that the outstation is interrogated.. 14

15 ver. 1.0 Page 15 from 27 (e) (f) (g) (h) (i) (j) Period Metering Data is outside the expected parameters set for the location. Meters have not been able to be remotely interrogated. These failed interrogations must be reported where there is a suspected fault on the Metering System. Cumulative comparison errors are outside ±0.2% where the cumulative comparison check is undertaken monthly, ±0.7% where the check is undertaken weekly and ±5.0% when undertaken daily. The cumulative comparison is the discrepancy of the cumulative register advance [the snapshot] and the summation of the period Metering Data [the Load Profile data] for the same time period. There has been a Meter alarm or event log relating to parameter changes, clock changes during a Settlement Period, phase voltage failure RAM/ROM checksum error, power supply failure. Where the alarm or event log report relates to specific Settlement Periods, only the data for these periods shall be considered Provisionally Error Metering Data. Any Metering Data is missing (including a check that Metering Data is from the expected number of channels). Where the NO has any other reason to believe that the Actual Metering Data is false Within 2 WD following Day D, the Actual Metering Data will be forwarded to the MAA and, where Actual Metering Data has failed validation, Estimated Metering Data will be determined for all Provisionally Error Metering Data and forwarded to the MAA Within 3 WD following Day D, Actual Metering Data and Estimated Metering Data will be provided on the Metering Data Report to the Registrant with an Code indicating the estimation method used. A list of Codes is given in Appendix A together with the method used to determine the estimate The Network Operator shall maintain a record of any communication with the Registrant during the determination of Estimated Metering Data Within 5 WD following Day D, the MAA shall ensure that validated Actual Metering Data or Estimated Metering Data is available to Settlement The Metering Data available to Settlement shall be the Period Advance determined from the Primary Main Meter or an estimate of the Period Advance determined from the Estimated Metering Data. 15

16 ver. 1.0 Page 16 from All Metering Data collected by the Network Operator and the MAA shall be recorded and stored in accordance with the relevant Metering Code. 7.3 Validation of Interconnector Metering Data By 12am on the first WD after Day D, the TSO shall complete the download of Metering Data from the Metering Systems registered for each Interconnection By 1pm on the first WD after Day D, the TSO agrees Metering Data relating to individual InterConnections with neighbouring TSO in accordance with ENTSO- E agreed procedures By 2pm on the first WD after Day D, the TSO agrees Accounting Data across individual InterConnections with neighbouring TSO in accordance with ENTSO- E agreed procedures and submits Metering Data to the next level in the ENTSO-E Pyramid By 3pm on the first WD after Day D, the TSO submits Metering Data to the MAA for each Interconnection The Metering Data to be submitted to the MAA is the confirmed Nominations for each Trading Party across each Interconnection and the Unintentional Deviation calculated in in accordance with ENTSO-E agreed procedures provided on a Settlement Period basis. Such Metering Data shall be deemed to be Actual Metering Data for Settlement purposes Where the TSO is unable to reach agreement with neighbouring TSOs relating to Interconnection Metering Data and the Unintentional Deviation, it shall use its best endeavours to provide Metering Data based on its own Metering Data marking the Metering Data as estimated with the Meter Reading Status Code E Once agreement has been reached with neighbouring TSOs on the relevant data, the TSO shall provide updated Metering Data to the MAA marking this as Valid with the Meter Reading Status Code A Within 2 WD following Day D, the MAA shall ensure that validated Actual Metering Data or Estimated Metering Data is available to Settlement. 7.4 Validation of DSO Non-interval Metering Data This section addresses the validation of Non-Interval Metering Data used to calculate Annual Quantities for Eligible Customers without Interval Meters 16

17 ver. 1.0 Page 17 from Once the DSO has uploaded Metering Data from Non-interval Meters for validation it will provide a Metering Data Report to the Registrant within 1 WD following Meter reading Metering Systems covered by this section are Supply Points fitted with Noninterval Meter connected to the Distribution System The Metering Data will be validated using the following tests. Metering Data will be Provisionally Error Metering Data where: (a) (b) (c) (d) Metering System ID does not match the expected Metering System ID Meter read date is before last valid Meter read date. Calculated advance i.e. the difference between the current read and the last valid read, is zero Calculated advance is negative. A subsidiary check should be made to ensure that a Meter rollover has been correctly identified. If a Meter rollover is suspected, repeat the validation and mark the read as valid. Where the last valid read was an estimated read and the calculated advance is negative, the calculated advance from the last valid actual read should be determined. If this is positive, then the latest read should be marked as valid and any intervening estimated reads withdrawn. (e) (f) (g) (h) (i) Calculated advance is more than twice the expected advance. Period Metering Data is outside the reading range defined for that type of Meter in the Metering Code. The Meter read date for the registers of a multi-register Meter are different. Error flags have been recorded on the Meter. Where the DSO has any other reason to believe that the Actual Metering Data is false A Metering Data Report will be provided to the Registrant covering Metering Data recorded by the DSO. Metering Data will be indicated as either valid or, where Metering Data has failed validation, invalid with an Error Code indicating the reason why the Metering Data failed validation. A list of Error Codes is given in Appendix B. 17

18 8 Substitution of Metering Data ver. 1.0 Page 18 from Where Metering Data from the Main Meter cannot be used to determine the Period Advance, data from the Check Meter, Secondary Main (where fitted) or Secondary Check (where fitted) (listed in order of preference) may be used and indicated by the Data Substitution Codes in Appendix A Where Metering Data from the Main Meter cannot be used to determine the Period Advance, and appropriate data is not available from the Check Meter, Secondary Main (where fitted) or Secondary Check (where fitted) but equivalent data is available from the TSO s SCADA system, this value may be used and indicated by the Data Substitution Code in Appendix A 9 of Meter Readings Except as provided in section 9.2, the overriding objective of the estimation process is to establish the most accurate value that may be used in the Settlement process to achieve a fair and reasonable result for all parties. 9.2 Special Cases Where incomplete data or data that fails the applicable validation checks established in this procedure, and the NO is prevented from investigating the cause, repairing an identified defect, manually downloading data or undertaking any required test, on [three] occasions at reasonable times, then the NO shall identify the Metering System to the MO, MAA and ERO as a special estimation case. Following identification as a special case, estimation shall be performed as outlined in section or as appropriate Special Procedure for Generation Infeeds Until the Metering System is no longer a special estimation case, the relevant NO shall estimate all outflows as zero. Special Procedure for Demand Outflows (including flow to network of a DSO) The NO shall follow the estimation procedure outlined in this procedure and shall double the resulting value before submitting it to the MAA and any other relevant party Where the arrangements outlined in section or are applied, the ERO shall be advised. 18

19 9.3 Calculation of Metering Data ver. 1.0 Page 19 from Where actual Metering Data is available for all other infeeds and outflows in a section of the network for a particular Settlement Period, the appropriate estimated Metering Data for that Settlement Period for the remaining connection shall be established by calculating the difference in metered values Where a System User can identify loadflows on its network such that it is possible to identify the corresponding loadflows across the commercial boundary, such data may be used by the NO to calculate the estimated Meter advance. Subject to review by the MAA if requested, it shall be the responsibility of the NO to calculate and apply appropriate network loss factors Where a cumulative advance and all except one Settlement Period advance are available, the NO shall calculate the estimated period advance using the available date. 9.4 of Less than 9 Adjacent Interval Values Where there are fewer than 9 adjacent interval values missing, the NO shall use linear interpolation to estimate the required values based on the adjacent, valid interval values and, where available, the cumulative advance. 9.5 of More than 8 Adjacent Interval Values Where there are more than 8 adjacent values missing, the NO shall construct an estimated profile of interval data based on: (a) (b) (c) (d) Where available, the cumulative advance; Known system operational data; The profile for the location at the same time on the same day of the previous week and/or; The system residual profile Where the day for which estimation is required is a public holiday, unless it is a normal working day for the location for which estimation is required, the profile for the previous Sunday should be used in place of the profile for the same day of the previous week Where the day for which estimation is required is not a public holiday but the same day of the previous week was a public holiday, an average profile should be created: 19

20 ver. 1.0 Page 20 from 27 (c) (a) (b) For a Monday, from the three previous working Mondays; For a Friday, from the three previous working Fridays; For a Tuesday, Wednesday or Thursday, from the three previous working Tuesday, Wednesday and Thursday. 9.6 Generator Metering Data Where it is necessary to estimate Metering Data relating to a generator Connection, except where evidence exists of an alternative operating regime, attention shall be paid to nominations provided to the TSO and instructions issued by the TSO when identifying the values to be applied to each Settlement Period. 9.7 of Reactive Energy Where it is necessary to estimate Reactive Energy, the approaches described in this section 9 shall be used except that no estimate shall be made for any location where Reactive Energy registers are not recorded in the Meter Technical Details for the Connection. 9.8 Non-interval Meter Eligible Customer Metering Data On a monthly basis, the MAA shall calculate the annual fraction, AF D, for each day D in the next month as: AF D DC D DC D where DC = Average consumption on Day D for last [5] years and the summation is over all days D in the previous year The MAA will provide the set of Annual Fractions for the coming year to the DSO by the 10 th day of the last month preceding the six month period The DSO shall determine an expected advance, EA, for site as: EA AF D AQ where the summation is performed over the period of the advance 20

21 ver. 1.0 Page 21 from 27 Department: Market Operator and AQ is the Annual Quantity determined under Section 16.4 of the Market Rules. 10 Investigation of Validation Failure Causes Where Meter Data fails validation undertaken in accordance with the requirements of section 7, the cause shall be investigated on site, if appropriate with the attendance of Trading Parties and/or System Users directly affected. Unless a clear cause is identified, repaired and tested as required by the provisions of the Metering Code, Metering Systems shall be tested as identified in section 11.5 of the Metering Code or section 4.9 of the DSO Metering Code as appropriate. 11 Site Visits The System User, or other person controlling the site of any Metering System shall, at all reasonable times, permit access to that Metering System by a representative of any of: the NO to whose network the Metering System is connected; the NO or any agent of the NO responsible for the provision of metering services at the Connection Point; the Market Operator; and the Supplier responsible for supplying energy through the Metering System in the case of a System User who is a Customer, and the Supplier shall ensure that the Customer has a contractual obligation to provide access by representatives of the organisations listed above. to inspect, maintain or collect data from the Metering System Whenever visiting a site, the representative of TSO shall comply with its Code of Practice for Access to Land and Premises and the representative of the DSO, Market Operator or Supplier shall: wherever possible, wear clothes and use vehicles which identify the company for which they work; show an identity card issued by the company for which they work. This card will show the company name; the name and signature of the representative; the employee number of the representative; a colour photograph of the representative at least the size required for an international passport; an expiry date for the card which is not more than two years from the date of issue; and an easy to read 21

22 ver. 1.0 Page 22 from 27 Department: Market Operator contact telephone number which can be used to confirm the representative and the reason for the visit is genuine; undertake all work in compliance with the safety requirements of the [electricity installation safety rules]; and comply with all relevant safety instructions applicable at the Metering System and for the specific site During site visits, the following checks will be undertaken by the representative of NO, Market Operator or Supplier at Connection Points where Interval Metering is installed: Whether the Metering System is/should be Energized or De-energized. Confirm any time registers/timeswitches are set to the correct time. Any evidence to suggest the existence of a Metering System fault including phase or fuse failure. Any evidence of damage to the Metering System or Network Connections. Any evidence of tampering especially Meter seals and terminal Connections/connector blocks. Any evidence of Meters not registering an advance where the premises are occupied. Any evidence of a supply being taken while Meters are De-energized During site visits, the following checks will be undertaken by a representative of the NO, Market Operator or Supplier at Connection Points where Noninterval Meters are installed: Whether the Metering System is/should be Energized or De-energized. Where appropriate, the number of maximum demand register resets. Whether a maximum demand register is on full scale. Confirm any time registers/timeswitches are set to the correct time. Any evidence to suggest the existence of a Metering System fault including phase or fuse failure. Any evidence of damage to the Metering System or Network Connections. Any evidence of tampering especially Meter seals and terminal Connections. 22

23 ver. 1.0 Page 23 from 27 Department: Market Operator Any evidence of Meters not registering an advance where the premises are occupied. Any evidence of a supply being taken while Meters are De-energized Discovery of Meter Tampering or other Electricity Theft Where it is identified that Meter tampering or other electricity theft has taken place, the System User or Supplier shall advise the NO who shall: Advise that all readings provided since the last valid reading should be replaced, Calculate and provide estimated values to all relevant Parties for: a. Consumption during each Settlement Period in the case of Interval Meters, b. Meter advances, register readings and, consumption allocated to each Settlement Period, based on the revised Meter advances, in the case of Non-interval Meters In the case of Meters which are read remotely using an automated system, the date of the last valid Meter reading will be deemed to be the later of: the date of the last communications test or confirmation reading, and the date of the first estimated Meter reading after the date which is [one] calendar year prior to the date on which the fault is discovered In the case of Meters which are read on site by manual or electronic means, the date of the last valid Meter reading will be deemed to be the later of: the date of the last reading on site by the NO, and the date of the first estimated Meter reading or Meter reading provided by either the System User or the Supplier after the date which is [one] calendar year prior to the date on which the fault is discovered When calculating estimated consumption values for all days after the date of the last valid Meter reading until the end of the incidence of Meter tampering or other electricity theft, the NO shall: use any of the consumption models permitted by the Market Rules, these metering rules or the energy supply agreement or Connection Agreement. 23

24 ver. 1.0 Page 24 from Where a NO provides a revised calculation of the consumption during each Settlement Period or of the Meter advance, the NO shall be responsible for the accuracy of the calculation in accordance with the requirements of this section 11.2 and of section 9. Responsibility for securing all evidence which may later be required by a court of law will rest with the person who identifies the incidence of Meter tampering or other theft. 12 Transitional Clauses Validation of TSO Metering Data in accordance with this procedure shall commence on the later of the date by which the ERO approves implementation of this procedure and the date of coming into force of Version 2.0 of the Market Rules Validation of DSO Metering Data in accordance with this procedure shall commence on the later of the date by which the ERO approves implementation of this procedure; the implementation of the MAA; the commencement of supply competition at the Distribution Level and the date of coming into force of Version 2.0 of the Market Rules Until supply competition commences, validation of distribution metering for the purposes of Settlement will not be necessary as it is assumed that the Public Supplier will supply all consumers below the Tx/Dx boundary. 13 Emergencies and Disputes Where there has been a significant failure in the delivery of Metering Data to the MO then the MO, in consultation with the ERO and the Stakeholder Review Panel: (i) (ii) assess the impact of delaying Settlement pending the delivery of the missing Metered Data; assess the impact of running Settlement with substitute Metering Data such as the previous month s data or the data from a similar month in a preceding year; or (iii) an alternative solution Following the process referred to in the MO will carry out Settlement in accordance with the outcome of the consultation Disputes arising from the operation of this Market Rules Procedure will be handled in accordance with the Dispute Procedure set out at Section 21 of the Market Rules. 24

25 ver. 1.0 Page 25 from At the conclusion of any Dispute, the Metering Data will be updated, where relevant, in accordance with this Market Rules Procedure and any resulting Settlement impact dealt with under the Meter Adjustments. 25

26 ver. 1.0 Page 26 from Appendix A Substitution Codes for Interval Meters Method Code A B C D Reason for Substitution Main Metering Data missing or incorrect, Check Metering Data available Main and check Meter Data missing or incorrect in Primary Data Concentrator, Secondary Data Concentrator Meter Data available Main and check Meter Data missing or incorrect in Primary Data Concentrator, Secondary Data Concentrator Meter Data available Main and check Meter Data missing or incorrect in Primary Data Concentrator, Secondary Data Concentrator Meter Data not available, but SCADA data exists Method Used Copied from Check Copied from Secondary Main Copied from Secondary Check Copied from SCADA Data Note: Options A C cannot be used if the substitution data fails any of the validation rules from section 6 that can be applied. Codes for Interval Meters Method Reason for /Substitution Method Used Code E Special - Generation: Manual Estimate to zero F Special - Demand: Special Mark to be followed by estimation method code G H No data from location, but data available from all surrounding points in close vicinity at same voltage level No data from location, but data available from surrounding points Calculated based on Network Flows no correction factor Calculated based on Network Flows correction factor required 1 Period advance calculated J Cumulative advance and all except 1 period advance available K Less than 9 Period Advances Profile using linear interpolation L More than 8 Period Advances Profile using appropriate trend U Parties own readings used Manual Estimate X Other estimation method used Manual Estimate 26

27 ver. 1.0 Page 27 from 27 Error Codes for Non-interval Meters Method Code Reason for Invalid Read A Unexpected Metering System ID B Meter read date before last valid Meter read date C Zero advance D Negative advance 1 E Advance more twice expected advance E Calculated advance exceeds capability of the Meter F Meter read data for multi-register meters are different G Error flags recorded on Meter X Other reason 2 1 Expected advance to be provided in Metered Data Report. 2 Other reason to be indicated in Metered Data Report. 27