Source: https://www.scribd.com/document/60442455/Metering-Code-v01
Timestamp: 2016-10-28 14:53:07
Document Index: 432733942

Matched Legal Cases: ['ART 1', 'ART 2', 'ART 3', 'ART 1', 'ART 2', 'ART 3', 'ART 1', 'art 3', 'art 2', 'art 1', 'ART 2', 'art 1', 'art 2', 'art 3', 'ART 3', 'art 1', 'art 3', 'art 2']

Metering Code v01
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Metering Code – Version 01
Page INTRODUCTION METERING CODE PART 1: GENERAL CONDITIONS PART 2: GRID METERING CODE PART 3: DISTRIBUTION METERING CODE METERING CODE – APPENDIXES 3 4 8 20 39 53
The current report – “Metering Code Report. Ver.2” – corresponds to the Work Stream C – “Technical” deliverable (partial) established in the “Implementation of the Corporate Restructuring of the Power Holding Company of Nigeria PLC (PHCN)” project. The Consultant has developed a second draft of the Metering Code, taking into account the comments received from the NERC to the first version. Following chapters present the amended complete version of the code “Metering Code Version 2.1” Changes from the previous version (Metering Code – Version 2.0) are highlighted using track changes.
.1.................... 3.............1.....3......................................... 25 Characteristics of the Metering System .......... 32 Proper Order ......................................2............. 8 The Metering Code ...........3.....................................................................1...................................................
SECTION: REVIEW PROCESS AND DISPUTES ...4.............................................
SECTION: CERTIFICATION......................... 20 Scope ......................................... 23 Location of Main and Checking Metering systems .......................................................................... Type of Connection Points....... Objective .3......................................................................2.3... 3................... 20
2...........................5............................................................................................................................................................................... 10
3.......................................................................... 10 2...........4.......................... 2..................1..........1.....
SECTION: INTERPRETATION AND DEFINITIONS.................................................................................. 20 1.. Ownership ......................................................................................................... 19 Illegality and Partial Invality ...................................... 33
4..................... 3 4 8
SECTION: BACKGROUND .........
SECTION: OWNERSHIP AND ASSOCIATED OBLIGATIONS ................................... 26 Accuracy of Metering .............................................................. 17 3.................................................................... Certification ................................................... 1.............
SECTION: METERING REQUIREMENTS................................ Title ...................................3..... 23 Applicable Standards ....1...................3.................................................. 20 Derogations....................... 34 Initial Calibration .................................................... 8 1.......... 8
2.............. 3...............2........................................................... 1..... 35
...................... CALIBRATION AND TESTING OF METERING SYSTEM ...................................................................................................................... 3............ 33 Metering Information Register ....................2....... 32 3.............. 34 4...... 17 Metering Commitee ....................................... 17 Unforeseen Circumstances ...... 3.................. 1.................. 23 2............................Metering Code – Version 01
INTRODUCTION METERING CODE PART 1: GENERAL CONDITIONS 1.................................... 17 Any dispute in relation to the following matters: ............................................................................................................................................................................... 2.......................................................................................... 28
3...2...........................2................................1................................ 3......................... Interpretation ........................... 4......... 19 20
PART 2: GRID METERING CODE 1.................... 4............................................... 2..............................2.. 2.................................................................. 1......................... Disputes .............................
OBJECTIVES AND SCOPE ........................................................................................ 35 Commissioning Tests .............1................................................................................................ 8 New Arrangements for the Nigerian Electricity Sector ............................................................
................................5....................................................... 50 Security of Metering Systems ...............................................1.................................................................3....... 5.................................................................................................................................................
SECTION: INTRODUCTION ................................................................................................................................... 51 5................................................................................................. 48 Inspection and Periodic Tests............................................................................ 2......2................................................................................1.............................................................................................................................. 37 Access to Metering Data. 60 2.............. 3...........
SECTION: METER READING AND DATA MANAGEMENT ............. 2................................. 4..................................................... Meter Reading .........................................................Metering Code – Version 01
4................... 43 Alternatives to Standard Metering Systems ................................ 1.1. 42 2.....................................2... 37 5...................................................... General ...... 39 1....................................... 1.........
SECTION: ACCESS AND SECURIY................... 47 Re-certification .....................................
APPENDIX A – CERTIFICATION TESTS ..... 36 Test Failure .....................3..................................................3...............
Periodic Tests ........... 5............1............ 3.................................................................................... 52 53
METERING CODE – APPENDIXES 1................. 5.. 3. Certification of New Metering Installations .................................................... 38 39
PART 3: DISTRIBUTION METERING CODE 1.......................2......4................................................ .. access to Metering Systems ...2....................... 54 1........................................................................... 39 Derogations...... 42 2................................. 52 Data Validation and Loss Adjustment Factors............................................ 2......................................................................... 5...........................................
APPENDIX B – COMMISSIONING TESTS .......................................5...............1............................... 51 Remote Metering Equipment ................. 44
SECTION: CERTIFICATION AND TESTS ...... 4..... 5.. 3....................................... Purpose and Scope .................................... Sealing: ...........................................................1........................... 4.................................................................................................................................................................2..................... General ............................. 1................ 49
4........................................................... 60
.......6.............................. 5.................1........... 55
2.............................................4................................................................................. 51 Data Management .....................................................5..........3............ 35 Other Periodic Tests ..................... 42 Standard Metering Sytems ......................... 44 Technical requirements and accuracy of Meters .... 50 4..............................................................................................................................1.................................................................................................. Installation and Replacement of Metering Equipment ....................... 46 3..................2.......................2....................... 48 Faulty Metering Equipment .......4........................ 36
SECTION: SECURITY AND DATA ACCESS ........................................ 3......................................................................................................................................... 54 Measurement transformers.................4.............................. 54 meters ..... 40
SECTION: OBLIGATIONS ........................ 51 Data Registration ... 50
5..................................................... 46 Certification of existing installations .............................................................................................
............................ 3......................5...... 64
......4.................................... recalibration......... 63 3......................................................................... inspecting... Seals Specifications ................ 63 Sealing Procedure at Point of Installation.......................... 2......
Measurement Transformers ............................................ site testing of meters etc .....................................................3....................................................Metering Code – Version 01
2.......... 64 Sealing Points ................................................................................................3......................................................................................... 2............ Sealing Procedure at point of Maintenance....................................................2.......................2........................................................... 3.... 63 3.. 3.............. 63
3.............4................................. Sealing Procedure at the Laboratory ...............1........................................................ 61
APPENDIX C – SEALING PROCEDURES ........... 60 Metering ..... 60 Measurement transformers leads and burdens ..............
METERING CODE (VERSION 01)
PART 1: GENERAL CONDITIONS 1. SECTION: BACKGROUND
1.1.1. This code shall be called the metering code (otherwise known as “MC”) for the Nigeria electricity supply industry.
1.2. NEW ARRANGEMENTS FOR THE NIGERIAN ELECTRICITY SECTOR
1.2.1. The Electric Power Sector Reform Act, 2005 (henceforth referred to as the act) gave legal backing to the unbundling of the Nigeria Power Sector. The act stipulates the functional unbundling of the generation, transmission and distribution sectors. To ensure financial viability of the electricity industry after the unbundling stated in 1.2.1, modern accurate meters systems with reliable communication facilities shall be deployed across the industry production and supply chain to measure and record energy production and utilization.
1.3. THE METERING CODE
1.3.1. This metering code (MC) is divided in three different parts: (a) The first Part, defines the General Conditions, which applies to the whole Code. (b) The second Part, Grid Metering Code (GMC) sets out or refers to the requirements for the metering of the Participant’s Connection Points on the Transmission or Distribution Network. It caters for the Commercial Metering System. The Grid Metering Code is required to cover the interchange of Energy and Power (i) (ii) entering or exiting from the Transmission Network entering or exiting from the Distribution Network, at any Participant’s Connection Point,
(c) The third Part, the Distribution Metering Code (DMC) specifies the technical and operational criteria, including the procedures to be complied with by the Distributor, in carrying out its obligation to provide metering services, for the metering of Customers of the Distribution System. The Distribution Metering Code is required to cover the interchange of Energy and Power entering or exiting the Distribution Network at any Customer’s Connection Point, provided that such Customer is not a Participant.
This Metering Code shall be read in conjunction with the Market Rules, the Grid Code, the Distribution Code and the Metering Market Procedures
SECTION: INTERPRETATION AND DEFINITIONS
2.1.1. In this metering code (including the appendixes), unless the context otherwise specifies or requires: (a) references to "the Metering Code" or "this Metering Code" or "this Code" are a reference to the whole of the Metering Code, including any Appendixes or other documents attached to any part of this Metering Code; (b) the Appendixes shall be deemed to be part of this Metering Code; (c) capitalised words used shall have the meanings assigned to them in the Definition Condition of the General Conditions Section; (d) words corresponding to persons or parties shall include any individual, firm, joint venture and corporation, and all references to persons shall include their legal successors and permitted assignees; (e) words in singular only also include the plural and vice versa where the context requires; (f) words in the masculine shall include the feminine and vice versa; (g) any reference to a day, month or year shall be construed as reference to a calendar day, month or year, as the case may be, and all references to specific dates shall be to the day commencing on such date at 00:00 hours; (h) the headings are for ease of reference only and shall not be deemed part of and shall neither affect nor be used in the interpretation or construction of this Metering Code; (i) the word “include” or “including” shall be construed without limitation; (j) the word “shall” refers to a rule, procedure, requirement or any provision of this Metering Code that requires mandatory compliance; (k) all references to a numbered Appendix, Section or Condition is respectively a reference to the Appendix, Section or Condition bearing that number in this Metering Code as well as the case for a numbered table or section in a Condition or Appendix (l) references to the consent or approval of the NERC shall be references to the approval or consent of the NERC in writing, which may be given subject to such conditions as may be determined by the NERC, as that consent or approval may be amended, modified, supplemented or replaced from time to time and to any proper order, instruction or requirement or decision of the NERC given, made or issued under it; and (m) reference to any law, by-law, code, regulation made under any law, directive or other document issued by the NERC shall be construed to refer to such law, by-law, code, regulation made under any law, directive or other document issued by the NERC as amended, modified or replaced from time to time. In particular, any reference to a licence shall be to that licence as amended, modified or replaced from time to time and to any rule, document, decision or arrangement promulgated or established under that licence.
including its appendixes. Any capitalized word or expression defined in the Electric Power Sector Reform Act. DEFINITIONS
2. This metering will be used for the Market Settlement process of the Market Operator. 2005. • Commercial Meter means the Meter which measure the energy injected or withdrawn from the grid by a Participant.Metering Code – Version 01
2. for the purpose of checking and validating the measurements provided by the Main Metering Systems. which will be used by the Market Operator in the Market Settlement process • Commercial Metering System means the system to measure and send to the Market Operator the energy injected or withdrawn from the grid by a Participant.
• Connection Agreement means an agreement between a Generator. The NERC will issue directives and procedures regarding the Calibration Tests to be performed. or an agreement between a Distribution Company and a customer. Electricity Regulatory
2. When applying the provisions contained in this metering code. • Check Metering means the metering and/or calculation process to determine metering data utilizing the Check Metering System • Check Metering System means the Commercial Metering System which will be used by the Market Operator.1.2. and unless otherwise specified or the subject matter or context otherwise requires: • Act means the Electric Power Sector Reform Act.2.2. Distribution Company or Eligible Customer and the TSP. as amended from time to time. which specifies the terms and conditions pertaining to the connection of the
. Or The Market Rules and that is not defined otherwise in this metering code shall have. • Associated User means a User who does not own the assets at a Connection Point but has a contractual interest in the test results or data flowing from the Metering System • Calibration Tests means a series of tests and checks performed by an authorised Meter Test Station to determine that the accuracy of an existing Metering Installation is within the specifications of this MC. or to replace measured data in case of failure or malfunction of the Main Metering System. • Commission (NERC) means the Nigerian Commission (NERC) created in the Act. • Check Meter means the Meter which is used to cross-check the measurements of the Main Meter. in Market Settlement process.2. 2005. unless the contrary intention appears. the same meaning and interpretation when used in this metering code. as the case may be.
service lines and overhead lines. meters. meters. where Generators are connected. registers and stores the information received from the Meters. electrical apparatus / equipment having design voltage of 33 KV and below. Data registers could be incorporated into the Meters itself or constitute a separated piece of equipment. • Distributor has the same meaning as Distribution Company • Effective date means the date on which this Code comes into force • Electricity Network means any connection of cables.Metering Code – Version 01
Generation Company. for use in the Market Settlement • Data Registers means the equipment which receives. electrical apparatus / equipment and having design voltage of 33 kV and below used to transport electric power on a Distribution System • Distribution System means any system consisting mainly of cables.
. service lines and overhead lines. provided that until such companies are created it will refer to a distribution zone. and serves as a link to the remote reading. Distribution Company or Customer system or equipment to the Transmission or Distribution System • Connection Capacity means the maximum capacity of a connection as stated in the associated Connection Agreement • Connection Point means a site or point of connection between a Generation Station or Load Facility and the System Operator Controlled Grid or Distribution System. plus related system used in the safe operation of an Electricity Network. or a person holding a Distribution Licence • Distribution Metering Code (DMC) means Part 3 of this Code • Distribution Network means any connection of cables. and which will be considered its Market trading point for Market Settlement and energy commercial metering Transmission System • CT is an acronym for current transformer • Data Collection System means the data collection system operated by the Market Operator. • Generation Substation means a substation in the Transmission Network or the Distribution Network. as corresponds. • Distribution Company (Disco) means a successor Distribution Company created in the restructuring of the PHCN. where a Participant connects to the system to inject or extract energy. service lines and overhead lines. electrical apparatus / equipment use to transport electric power on a Transmission or Distribution Network or both • Eligible Customer has the meaning assigned to the term in the Act • Generation Station means a facility with one or more Generation Units. meters.
• Large Connection means a connection where the Connection Capacity is greater than [4 MVA] or connections with generation facilities greater than [300 kW]. or a Participant who is licensed to generate electricity under section 60 of the Act. including the mechanical prime mover (e. • Main Metering means the metering process to determine metering data utilizing the Main Metering System • Main Metering System means the Commercial Metering System which will be used by the Market Operator as a prime reference for the measurement of the active or reactive energy interchanged at a Connection Point in Market Settlement process
. whose upper limit of nominal root-mean-square value is less than 1kV • Main Meter means a meter other than the Check Meter that is capable of and is used to measure the flow of active or reactive energy at a Connection Point. and self-generation authorised by the Commission • Generator Group or Generation Group means a group of one or more similar generating units within a power plant. In the case of a multi-generating unit combined cycle block.g. including Successor Generation Companies and Independent Power Producers. in the case of unconventional generating units such as wind and solar energy. turbine or engine) in the case of conventional hydro or thermal plant or the equivalent principle means of converting another form of energy to electricity. • Load Facility means a Distribution Company or a customer which is connected to the Transmission System • Low Voltage (LV) means a voltage. used for the supply of electricity. as amended from time to time in accordance with these Rules with the approval of the Commission • Grid Metering Code (GMC) means Part 2 of this Code • High Voltage (HV) means a voltage. a generating unit is an alternator plus its associated prime mover within the combined cycle block • Grid Code means the “grid code” as defined in the Act to be prepared by the System Operator. A hydro power plant will be considered a Generating Group unless it has separate meters for each generating unit • Generator Unit or Generation Unit means any equipment that produces Energy. used for the supply of electricity. whose lower limit of nominal root-mean-square value is greater than 33 kV • IEC means International Electrotechnical Commission.Metering Code – Version 01
• Generator means a Successor Generation Company. or an Independent Power Producer (IPP). together with the associated plant and apparatus. whose Energy output is separately identifiable and separately metered in the Connection Point.
etc. associated with a Meter. but shall be deemed to exclude instrument transformers • Metering Code (MC) or Code means this Code • Metering Committee has the meaning indicated in Section 3 of this Part. storage capacity.. due from Participants who are required to make payment. • Meter Type means a specific and unique model of Meter of a specific manufacturer. and to be paid to Participants who are due to receive payments. for purposes of this MC as different Meter Types. metering protection equipment including alarms. pursuant to the Market Rules • Medium Connection means a connection where the Connection Capacity is greater than [50 KVA] and up to and including [4MVA] where no generation facility greater than [50 kW] exists for an LV connection and no generation facility greater than [300 kW] exists for an MV connection • Medium Voltage (MV) means a voltage. Manufacturer’s variants of a specific Meter model or trademark. the Market Settlement process the and market payment system • Market Rules means the Market (Settlement) Rules for the Electricity Sector of Nigeria • Market Settlement means the process of calculating charges. voltage transformers. • Meter means a device that measures and registers the integral active Energy or Reactive Energy over a metering interval and may include a data recorder. metering protection equipment including alarms and LV electrical circuitry. • Meter Test Station means a certified test laboratory which has the technical and infrastructure capability to perform accuracy tests for Meters and Metering Equipment. • Metering Equipment means current transformers. which is located at a definite Customer’s location.Metering Code – Version 01
• Market Operator means the company or entity licensed or authorized to provide market administration services and responsible for registration of Participants and commercial metering. • Metering Installation. collection and validation of meter data. identified by a definite trademark and type. or different options of a model as voltage or current ratings. as the case may be. used for the supply of electricity.
. if exists. means a Meter or Meters and their associated Metering Equipment. data transmitters related to the measurement and recording and transmitting to the Data Collection System the active energy and/or reactive energy. whose nominal root-means-square value ranges between 1kV and 33 kV. voltage transformers. associated data collectors. shall be considered. but shall be deemed to exclude the Meter itself. in the DMC. • Metering Market Procedures has the meaning assigned to the term in the Market Rules • Metering System means a Meter and the associated current transformers. LV electrical circuitry.
and stations. Routine Tests shall be performed to each individual Meter or Metering Equipment or by sampling of a group of Meters or Metering Equipments.
• Station Auxiliary Transformer means the transformer at a Generation Substation which feeds exclusively the auxiliary equipments of a Generation Unit or a Generation Group. or the Transmission Network with the equipments or apparatus of an Eligible Customer. • Transmission Network means any connection of High Voltage apparatus. • Transmission System means the System consisting of High Voltage apparatus. lines. equipment. having design voltage of 132 KV and above used in the safe operation of transmitting electrical power from
. Routine Tests shall be performed to each individual Meter or Metering Equipment or by sampling of a group of Meters or Metering Equipments. issued according Article 66 of the Act. • Routine Test means a series of tests and checks performed by an authorised Meter Test Station to determine that a new Meter or Metering Equipment complies with the provisions of this MC. as prescribed by NERC directives which will include sampling techniques and Routine Tests to be performed. issued according to Article 68 of the Act. having design voltage of 132 KV and above used in transporting electric power on a Transmission System • Transmission Service Provider (TSP) means a holder of a Transmission License. lines. as corresponds. • System Operator means the holder of a System Operation License.Metering Code – Version 01
• Participant or Market Participant has the meaning assigned to the term in the Market Rules • Party means any person subject to the provisions of the Metering Code • Power Transformer means the transformers which interconnect the Transmission Network with the Distribution Networks. as prescribed by NERC directives which will include sampling techniques and Routine Tests to be performed. and stations. issued according to Article 65 of the Act. • Step Up Transformer means the transformer that connects the stator windings of a Generation Unit with the Transmission or Distribution Network. • Prepaid Meter means a Meter that requires the Customer pay its consumption in advance in order to allow a connection to the network. • System Operator Controlled Grid has the meaning assigned to the term in the Market Rules • Trader means a holder of a Trading License. equipment.
• Urgent Metering Services means urgent unplanned work by a Distributor on a Metering System as a result of actual or potential equipment failure. or has any type of interest in the outcomes resulting from this MC implementation. The NERC will issue directives and procedures regarding the Type Tests to be performed to each Meter Type. in Part 1 General Conditions. This shall not include any part of the Distribution System • Type Test means a series of tests and checks performed by an authorised Meter Test Station to determine that a new Meter Type complies with the provisions of this MC. actual or suspected tampering or suspected theft • VT Is an acronym for voltage transformer
.Metering Code – Version 01
the generating station bus bars up to the interconnection point with the Distribution System. • User. means any person to which this MC applies.
A Metering Committee shall be appointed for the purposes of this Metering Code.1. Metering Equipment.2.1. the Parties concerned (giving reasons for the decision). Such other matters as the relevant Parties may agree. 3. The Metering Mommittee can demand any information it may properly and reasonably require to settle a dispute from any party and such party shall provide the relevant information on request. and communicated to.
SECTION: REVIEW PROCESS AND DISPUTES
3.1. The metering committee may make recommendations to nerc on the payment of cost or/and expenses to any party in respect of any dispute referred to it. METERING COMMITEE
3. Sealing of Metering System.1.1.1. DISPUTES
3.Metering Code – Version 01
3.1. Technical specifications for Meters.1. Any other dispute under this metering code shall be dealt with in accordance with the disputes procedure in the relevant connection agreement.2.5. Compliance of Metering System with technical specifications of this Metering Code. It will comprise: (a) (b) (c) (d) (e) (f) (g) (h) One member representing PHCN successor Generation Companies One member representing IPPs Two members representing successor PHCN Distribution Companies One member representing Meter manufacturers One member from the Meter Instrument Laboratories One member from the Market Operator One member from TCN One member from the Nigerian Electricity Regulatory Commission
. Any dispute relating to meters or metering equipment.2.4.
3. Compensation values. shall be dealt with in accordance with the relevant disputes procedure.
shall be referred to the Metering Committee who shall act as experts and whose decision shall be final and binding on. Any dispute in relation to the following matters: (a) (b) (c) (d) (e) (f) Siting of the Commercial Metering System. which would affect the settlement and/or any payment to be made or received. or the Data Collection System.
(b) Review all suggestions for amendments to the MC which the NERC. Decisions of the Metering Committee shall be made by voting of committee members attending any meeting. (d) Issue guidance in relation to the MC and its implementation. No less than 5 Business Days notice of a meeting of the Metering Committee is required to be given to all committee members entitled to attend such meeting except in the case of an emergency meeting.2. The Market Operator shall act as secretary of the Metering Committee for the purpose. Each committee member shall have one vote. (and unless otherwise provided) shall have a casting vote. The Metering Committee shall operate in accordance with such other rules and procedures as are laid down by it.
The Secretary of the Metering Committee shall consult in writing with Users liable to be affected in relation to all proposed amendments to the MC and shall submit all proposed amendments to the Metering Committee for discussion prior to such amendment. 3.2. Members of the Metering Committee shall be required to enter into confidentiality undertakings in favour of all Parties in a form specified by the Grid Code Review Panel.2. 3.
3. (e) Consider what changes are necessary to the MC arising out of any unforeseen circumstances or derogations approved. The chairman.3.Metering Code – Version 01
3.2.2.6.2.
3. In default of appointment by the relevant Parties NERC shall have the right to appoint representatives from the Parties who have failed to appoint their own representatives.
. by the relevant Party or Parties concerned for a period of two years. where necessary.2. from time to time. The chairman shall be elected by the Metering Committee from among its members.7.8. 3. Metering Committee member or User may wish to submit to the Metering Committee Chairman for consideration by the Metering Committee from time to time. performance and interpretation upon the reasonable request of any User.9. Five (5) committee members shall be a quorum for any meeting of the Metering Committee.5. (c) Publish recommendations as to the amendments to the MC that the Metering Committee feels are necessary or desirable and the reasons for these recommendations. inter alia. The “Metering Committee” shall perform the following functions: (a) Keep the MC and its working under review. with the possibility of renewal.2.4. Members of the Metering Committee shall be appointed. (f) Resolve disputes that may arise from the implementation of this Code
3. of giving and receiving of notices.
Nominated representatives to the metering committee shall be competent staff of managerial status in the organization which they are representing.2.
3. the provision shall apply with such minimum modification as may be: (a) necessary to make it valid and effective.
3.10.3. If circumstances not envisaged in the provisions of the MC or divergent interpretations of any provisions included in the MC should arise.
. are not binding on the NERC. Any decision for amendment to the MC must be approved by the NERC and be published by the Market Operator in a manner agreed with the NERC. consult promptly with all affected Users in an effort to reach agreement as to what should be done.2.4.1.2.
3. If agreement cannot be reached in the time available.3.4.4.4. the Market Operator shall in good faith determine what is to be done and notify all Users affected. except when it settles disputes. UNFORESEEN CIRCUMSTANCES
3. The Market Operator shall promptly refer all such unforeseen circumstances and any determination to the Metering Committee for consideration.2. If part of a provision of the MC is found to be unlawful or invalid but the rest of such provision would remain valid if part of the wording were deleted.2 for consideration by the Metering Committee. and (b) most closely achieves the result of the original wording but without affecting the meaning or validity of any other provision of the MC. 3. If any provision of the MC should be found to be unlawful or wholly or partially invalid for any reason.1 and 3. but shall have only the nature of an opinion.
3.3. The Metering Committee decisions.1. ILLEGALITY AND PARTIAL INVALITY
3. the validity of all remaining provisions of the MC shall not be affected.4.
3. The Market Operator shall prepare a proposal to correct the default referred to 3.4. to the extent reasonably practicable in the circumstances. the Market Operator shall.
provided that they qualify as Participants in the Market. whether they qualify or not as Market Participants.
1.1. (vii) Traders. OBJECTIVE
1. Customers with and without self-generation directly connected to the Transmission Network. (e) The responsibilities of the Market Operator and Users in relation to ownership and management of Metering System and provision and use of metering data. Participants trading in the Wholesale Market.2. DEROGATIONS
1.3. or expect to be. the TSP and Users who have or plan to have access to the Transmission Network or MV Distribution Network. The objectives of the Grid Metering Code are to establish: (a) The technical.
1. certification and testing of the Meters and Metering Equipment (d) The standards to be met by Market and System Operators.1.
(vi) Eligible Customers with and without self-generation connected to the MV Distribution Network. it shall without delay report such non compliance to the Market Operator stating the reasons for non-compliance and the proposed remedy for this situation.Metering Code – Version 01
PART 2: GRID METERING CODE 1.2. The Grid Metering Code applies to: (a) (b) The Market Operator Users.
. provided in the later case they are.1. design and operational procedure for of the Commercial Metering System (b) The required accuracy and calibration of the Commercial Metering System (c) The procedures for approval.1.1.
(iv) Generators directly connected to the Transmission Network. OBJECTIVES AND SCOPE
1. which in this part of the MC (the Grid Metering Code) are: (i) (ii) (iii) (v) The System Operator The TSP Distribution Companies (Discos).3. If a User finds that an existing installation cannot comply with the standards contained in this GMC or cannot meet the required accuracy levels.
the Market Operator shall promptly consider such a request provided that it considers that the grounds for the derogation are reasonable.3.3. then application can be made to the Market Operator for a derogation. On receipt of any request for derogation.
(f) the date by which the derogation ends if compliance will be achieved.and
1. the User shall be relieved from its obligation to comply with the applicable provision of the GMC and shall not
1.3. The NERC shall inform the Market Operator of its decision within 20 calendar days of receipt of the Market Operator´s notification. the reason for the non-compliance requiring derogation.4.7.2. or impose unreasonable costs on the operation of the Transmission System or on an Interconnected Party’s System. the nature and extent to which the derogation applies including alternate compliance provisions. have a material adverse impact on the accuracy of the settlement system. proposed remedial actions. The Market Operator shall notify the NERC of the request. To the extent of any derogation granted. together with its opinion on: (a) Whether the derogation would. if relevant. (b) identification of the Meters or Metering Equipment in respect of which a derogation applies and. 1.Metering Code – Version 01
Where the costs of modifying existing equipment to meet the GMC standards are excessive and the equipment is expected to be changed or decommissioned within o n e ( 1) year. (c) (d) (e) identification of the provision with which the derogation applies.3.3.5 then such advice and evidence of the performance of the equipment concerned. is capable of performing to the required levels of accuracy contained in Condition 2.
1. can be submitted to the Market Operator as due process for a derogation request if the User wishes. provided that if the NERC does not answer within this timeframe. or is likely to: (i) (ii) (b) 1.3.
. Where a User has received professional technical advice that the proposed equipment or existing equipment. 1.3.5.6. the Market Operator must consider that the opinion of the Market Operator has been accepted.3. Any request for derogations from any provision of the GMC by a User shall contain: (a) the issue number and the date of the GMC provision against which the derogation applies. if any . or by which such derogation expires.
Whether the derogation should be granted. although not fully meeting the standards as listed in Condition 2.
NERC may grant derogation as requested or grant it subject to other provision or reject the request while taking into account the opinion of the Market Operator.
be liable for failure to so comply but shall comply with any alternate provisions as set forth in the derogation. provide a copy of such register of derogations to such User.3.
. The Market Operator shall: (a) keep a register of all derogations which have been granted. 1. a review of any existing derogations. may be initiated by the Market Operator. and any derogations under consideration.8. and (b) on request from any User. identifying the name of the person and User in respect of whom the derogation has been granted. the NERC or an Associated User. the relevant provision of the GMC and the period of the derogation. (c) Where a material change in circumstance has occurred.
LOCATION OF MAIN AND CHECKING METERING SYSTEMS
2.1. will be located as close as practicable to the Connection Point. 4 or 5. Check Metering can be obtained through Redundant Metering or Verification Metering. which corresponds to an interface exists between two or more Participants.
2. 2. Commercial Metering Systems shall be installed to measure active energy and reactive energy. an adjustment for losses between the location of the Metering System and the Connection Point will be calculated by the Market Operator and agreed to by the User. As a general rule.2. at each Connection Point on the Transmission or Distribution Network. installed at the same Connection Point where the Main Meter is installed.1. (b) Verification Metering: Metering Equipment.1.2. whose measurements permits the verification of the Main Meter measurement through simple calculations that eliminates the effect of the network element that could exist between them. In principle.
Main and Check Metering Systems shall be installed in all Connection Points of Type 1.2. In Type 6 Connection Points only Main Metering Systems shall be installed.Metering Code – Version 01
2. although an installation of a Check Metering System is advisable.4. Such loss adjustments may
. (a) Redundant Metering: Metering Equipment.5. Commercial Metering Systems comprises both the Main Metering System and the Check Metering System. when the later is required.1. with a Connection Capacity equal to or higher than [10 MW] (d) (e) (f) 2.1. This will comprise both Import and Export metering when reasonably required by the Market Operator. For the purposes of this GMC the Connection Points shall be classified as follows: (a) Type 1: Between a Generator Unit or Generator Group with a Connection Capacity equal to or higher than 10 MW and the Transmission Network (b) Type 2: Between the Transmission Network and a Distribution Network (c) Type 3: Between the Transmission Network and an Eligible Consumer.1. 3.3. Where there is a material difference in location.1. or set of Metering Equipments installed in different locations than the Main Meter. 2. Type 4: International Interconnections Type 5: Between two Distribution Networks of different licensees Type 6: All other Connection Points
2. both Main Metering System and Check Metering System.1. Main and Redundant Meters measurements shall be coincident.
SECTION: METERING REQUIREMENTS
2. TYPE OF CONNECTION POINTS
In this case.2.2.2. of the line that interconnects Nigeria with any neighbouring country. or Exceptionally. Provision 2.2. or Through Verification Metering. (b) Check Metering shall be obtained either:
.2 (a) shall apply. 2.2.
Type 3 Connection Points (a) The Main Metering System shall be located at the actual Connection Point between the Transmission System and the Eligible Customer. located at the same point as the Main Metering System. or Through Verification Metering. In this case.Metering Code – Version 01
include transformer and line loss compensation resulting from the distance of the Metering System to the physical location of the Connection Point.
2.3 (a) shall apply. in case neither (i) or (ii) could be applied. Type 1 Connection Points (a) As far as possible.
2. (b) Check Metering shall be obtained either: (i) (ii) (iii) Through a Redundant Meter.
Type 4 Connection Points (a) The Main Metering System shall be located at the Connection Point. located at the same point as the Main Metering System. through Verification Metering. In this case.2. with Meters located at each incoming Transmission Line into the Substation. the Main Metering System at Generation Stations shall be located at the actual Connection Points: (i) (ii) (b) (i) (ii) At the HV side of the Step Up Transformer of the Generator Unit for energy exported At the HV side of the Station Auxiliary Transformer Through a Redundant Meter. with Meters located at each of the outgoing MV distribution feeders. in the Nigerian Substation. located at the same point as the Main Metering System.4 (a) shall apply. Provision 2.
Type 2 Connection Points (a) The Main Metering System shall be located at the LV side of the Power Transformers of the substation that connects the Transmission System with the Distribution System. with Meters located at the HV side of the Power Transformers of the substation that connects the Transmission System with the Distribution System. with Meters located at the Connection Points of each outgoing feeder of the Generation Substation
Check Metering shall be obtained either:
2.2.3. (b) Check Metering shall be obtained either: (i) (ii) Through a redundant Meter.2. or Through Verification Metering. Provision 2.5.4.
The following IEC standards approved for use with this GMC are: (a) IEC Standard 62053-22 – Alternating current static meters for active energy (classes 0. (e) (f) (g) IEC Standard 60044 Part 1 – Current transformers.Alternating current static meters for active energy (classes 1 and 2). (b) IEC Standard 62053-21 .
(h) IEC Standard 62056-21 – Data exchange for meter reading – Direct local data exchange.3.2. necessary corrections or modifications shall be made for nominal system frequency. APPLICABLE STANDARDS
2. 2.1. located at the same point as the Main Metering System.5 (a) shall apply.5. IEC Standard 60044 Part 2 – Voltage transformers.2. Whenever the above mentioned IEC Standards are followed. nominal system voltage.5 S). (b) Each licensee shall consider the Metering System at its own substation as Main Metering. humidity and other conditions prevailing in Nigeria before actual adoption of the said Standards.7.
Type 6 Connection Points (a) The Main Metering System shall be located as close as possible to the actual Connection Point. Where relevant standards change from time to time. All Meters and Metering Systems shall comply with the relevant standards.3. In this case.
. (d) IEC Standard 62053-23 – Alternating current static meters for reactive energy (classes 2 and 3). IEC Standard 60044 Part 3 – Combined transformers. 1 and 2). The accuracy of the various items of measuring equipment comprising Meters and Metering Systems shall conform to the relevant IEC standards or any equivalent Nigerian standards.2. Verification Metering can be obtained through the measurements in the other extreme.6.2 S and 0.
2. or Through Verification Metering.Metering Code – Version 01
Through a Redundant Meter.3. with Meters located in the other extreme of the interconnection line (in the neighbouring country).2. (c) IEC Standard 62053-11 – Alternating current electromechanical meters for active energy (classes 0.
Type 5 Connection Points (a) The Metering Systems shall be located at both ends of the line between substations of different licensees. the Market Operator will
2. Provision 2. ambient temperature. if the Market Operator agrees with this possibility and the Interconnection Agreements allows adequate interchange of the information required in a timely manner.3.3.
5. Adequate devices shall be provided to immediately detect the absence of voltage to the metering equipment in any of the three phases 2.Metering Code – Version 01
review such changes and recommend to the NERC through the Metering Committee the extent to which any changes should be implemented. This may be achieved by using one or more metering equipment as may be convenient.4. CHARACTERISTICS OF THE METERING SYSTEM
2. (d) Eventually. 2. In any case.4. (e) Connection cables between VT and the metering equipment shall have a section enough to guarantee that the voltage drop will be always lower than 1 per 1000.4. (c) As a general rule. CT and VT windings and cables connecting such windings to Check Meters may be used for other purposes provided the overall accuracy requirements are met and evidence of the value of the additional burden is available for inspection by the Market Operator. This may be achieved by using one or more metering equipments as it is convenient In cases where separate Data Registers are used. The maximum burden imposed by the cables that connect the current transformers with the metering equipment shall be lower than 4 VA.4. Meters shall be capable of measuring data at least half-hourly. Check Meter and additional burdens shall have separately fused VT supplies. Measuring Transformers characteristics and installation: (a) Measuring transformer shall be always of inductive type.4.4. In any case the section of these cables shall not be lower than 6 mm2. and record them automatically on integral or separate Data Registers.1.3.3.4. Meters shall be static type. each Data Register may store information from one or more Metering Equipment. CT and VT windings and cables connecting such windings to Main or Check Metering shall be dedicated for such purposes and such cables and connections shall be securely sealed. then a derogation submission must be made to the Market Operator in accordance with Chapter 1. Registers of reactive energy shall be done in all the four quadrants reactive energy could flow.
2. Registers of active energy shall be done in all the ways the energy could flow. 2. provided that Redundant or Verification Meters shall have separate Data Registers from the Main Meters.4. (f) The Main Meter.2. and relevant standard regarding the number of wires shall apply. all Meters shall have a display showing the accumulated values of the measured quantities.4
2. (b) Main and Check Metering shall operate from separate current transformer (CT) and voltage transformer (VT) windings. Where a User proposes to utilize equipment that does not meet these standards.
as the case may be.6.
(d) Level 4 . The Meter or the Data Register.Metering Code – Version 01
(iv) Alarm indications.4. (c) Level 3 . Separate security levels shall be provided for the following activities: (a) Level 1 . The Market Operator shall define the communication protocol to be used. Programming the level 3 password and the level 4 password. it shall enter into.
2.4.4.4.Password for removal of Metering Equipment cover(s) necessitating the breaking of the seals for: (i) (ii) Calibration of the Metering Equipment. or that of the System Operator. to allow for any interruptions to the automatic Data Collection System.
In addition to the functions specified for each level it shall be feasible to undertake the functions at the preceding or lower level. shall have an adequate communication channel.
2.9. For redundancy purposes. the Market Operator may use its own data communications network.8. as the case may be. 2 and 3.10. opto-couplers according to IEC Standard 62. to the Data Collection System. including remote interrogation and batch downloading. The selected communication protocol shall be approved by the NERC and communicated to the involved Users at least six (6) month before remote interrogation will start. or any other system the Market Operator may authorize. and (b) Level 2 .Password for programming of (i) (ii) Displays.Password for read only of the following metering data. Energy Metered Values. which shall be unique and of standard type in order to reduce the costs that shall be borne by the Users. Cumulative measured quantities.7.
2.Password for corrections to the time and/or date and resetting of maximum values.4. manage and monitor contracts to provide for the maintenance of all data links by which data is passed from the Meters or Data Registers.056-21.
Data Registers shall have adequate capacity to store at least three (3) months of on site data in non volatile memories. For the purposes of remote interrogation of Meters or Data Registers. This communication channel will permit automatic downloading. by the Data Collection System. tariff schemes and other functions.
2. as the case may be. which shall be transferable on request during the interrogation process: (i) (ii) (iii) (v) Meter of Data Register ID. To prevent unauthorised access to the data in the Meters or Data Registers a security scheme shall be incorporated for both local and remote access. and The passwords for levels 1. Meter or Data Register time and date. either through a serial port RS-232.
The rating and accuracy requirements of Metering System should anticipate any future increase in rating of the primary plant. Accuracy class shall as a minimum be as shown in Table 1.11.5.1.4. generator. Such other methods shall be authorised by the Market Operator. ACCURACY OF METERING
2. Accuracy requirements for the purpose of this GMC are defined by Type of Connection Point (as indicated in 2. rated in MVA.3. transformer. 2. Circuit capacity shall be determined by the lowest rated primary plant of the circuit i. The Meter shall be enclosed in a cabinet or otherwise installed in a manner which shall conform to the manufacturer’s stated environmental conditions. as the case may be. lines etc.2.e. shall be done preferably through GPS systems. including vibration.Metering Code – Version 01
2. and must be based on the primary plant maximum continuous ratings. Time synchronization of Meters and Data Registers. the cabinet or meter must be sealed to prevent unauthorised access. The accuracy class or equivalent of various items of measuring equipment comprising Meters and Metering Equipments shall conform to the relevant IEC standards as listed in 2. In addition.4.. Other synchronization systems may be used provided that they comply with the requirements regarding accuracy and security and do not distort the calculations of the energy balances.
2.2) and circuit capacity.5. The installation shall provide protection from moisture and dust ingress and from physical damage.12.
Note 1: Current transformers shall meet the class accuracy requirements irrespective of CT secondary ratings.2S
0.2S 2
0.5 may be used where energy transfers to be measured by the entry/exit Meter during normal operating conditions is such that the metered current will be above 5% of the Rated Measuring Current for periods equivalent to 10% or greater per annum (excluding periods of zero current).2S/0.5
0.2S/0. 2 and 3 Connection Capacity Current Transformers (Note 1 & 2) Voltage Transformers Active Energy Meters (Note 2 & 3) Reactive Energy Meters >50 MVA < 50 MVA Type 4 all Type 5 > 10 MVA < 10 MVA Type 6 > 1 MVA <1 MVA
0.2S/0.2 0.
.2 0.Metering Code – Version 01
Table 1: Equipment Accuracy Classes Equipment Accuracy Class Equipment Type For Connections Type 1.5
0.5 0.2S
0. Note 2. For new connections made after the date of approval of the first issue of the GMC the higher accuracy class shall be used Note 3: A Meter accuracy class of 0.
3. apply in addition to the requirements of this GMC. so long as they do not prevent compliance with this GMC. If a contract between relevant Users has additional requirements for Metering Systems or requirements in relation to Meters.5. those requirements shall.Metering Code – Version 01
For the measurement of active energy and reactive energy. after taking due account of CT and VT errors and the resistance of cabling or circuit protection.4.
. the Metering Systems shall be designed and the metering equipment shall be tested and calibrated to operate within the overall limits of error set out in Table 2.
0% ±5.0% ±5.0% <1 MVA ±3.5% ±2.0% ±5.5% ±1.0% ±4.0%
Type 5 > 10 MVA ±1.0% ±3. 2 and 3
Current Expressed as a Percentage of Rated Measuring Current
Type 4 All ±0.5% ±3.5% ±0.5% ±3.0% ±3.0%
Metering_Code_ NERC_Nigeria_V01
.5% ±3.5% ±2.0% ±2.7% ±1.5% ±2.8 lead
>50 MVA ±0.0% ±1.0% ±3.0% ±3.0% ±5.5% ±4.0% < 10 MVA ±2.0% ±5.0% ±4.0% ±2.0% ±4.0% ±1.0% ±5.0%
Type 6 > 1 MVA ±2.0% ±5.5% ±0.0%
< 50 MVA ±1.0%
120% to 10% inclusive Below 10% to 5% Below 5% to 1% 120% to 10% inclusive 120% to 10% inclusive Condition 120% to 10% inclusive 120% to 20% inclusive 120% to 20% inclusive
Limits of Error for Reactive Power and Energy at Stated Power Factor ±4.5% ±2.0% ±1.5% ±1.5% ±3.0% ±2.8 lag 0.0% ±5.8 lag 0.0% ±5.Metering Code –Draft Version 02
Table 2: Overall Accuracy of Metering System Limits of Error at Stated Power Factor for Active Power and Energy Measurement Equipment Type For Connections Type 1.0% ±5.5% ±3.0% ±5.0% ±5.5%
Power Factor 1 1 1 0.8 lead Power Factor 0 0.0% ±1.7% ±1.0% ±4.0% ±4.0% ±5.0% ±5.0% ±2.0% ±4.
Main and Check Metering System shall be owned by the relevant Discos. unless something different has been agreed in the relevant Interconnection Agreements Ownership of Check Metering Systems shall be governed by the relevant Interconnection Agreement. Unless something different is agreed among Users.
The relevant owner shall be responsible for installing and maintaining his own metering equipment at the Connection Point.1.Metering Code – Version 01
3. the Market Operator shall be responsible for approving the initial design.1. The User who owns the substation where the metering equipment is located shall provide the Market Operator with:
International Interconnections (Type 4)
Interfaces among different Discos (Type 5) (i)
3. if Verification Metering. shall be owned by the TSP Main Metering System shall be owned by the TSP: Check Metering. and authorised by the Market Operator. if Redundant Metering shall be owned by the relevant Generation Company Check Metering. if Redundant Metering shall be owned by the TSP Check Metering.
3. if Verification Metering.1.3.1.1.1. and for the testing. unless the User agrees with the Market Operator otherwise. Ownership of Metering Systems shall conform to the following rules: (a) Generation Stations directly connected to the Transmission Network (Either Type 1 or 6) (i) (ii) (iii) (b) (i) (ii) (iii) Main Metering System shall be owned by the relevant Generation Company: Check Metering.
SECTION: OWNERSHIP AND ASSOCIATED OBLIGATIONS
3.4. shall be owned by the relevant Disco
Distributors Connected to the Transmission Network (Type 2)
(c) Eligible Customers Connected to the Transmission Network (Either Type 3 or 6) (i) (ii) (d) (i) (ii) (e) Main Metering System shall be owned by the Eligible Customer: Check Metering shall be owned by the TSP Main Metering System shall be owned by TCN.
. commissioning and sealing of any Commercial Metering System in Nigeria.2. Regardless of ownership.
measured by the relevant Meters. but not be limited to: (a) (b) (c) (d) (e) (f) (g) A unique meter identification/serial number.
unrestricted access to the facilities where the Metering System
adequate space for installing communications devices. on the operation and maintenance of the communication equipment. recording and transmission of the required data relating to active and reactive energy.3.1.5. type and model. to the extent necessary to ensure the correct registration. redundant or verification. METERING INFORMATION REGISTER
3.2. repair and condition all Meters and Metering Equipment in respect of which it is responsible. the Market Operator will advise the relevant owner of the noncompliance and such owner will rectify this situation forthwith unless a derogation is granted under the Chapter 1. either with the System Operator or the TSP.2.3. Data Registers.3. (i) Organization which issue the certification of the Meter and Metering Equipment (j) Calibration and test performed on the Meters and/or the Metering Equipment at least during the last 5 years 3. Each owner shall at its own cost keep in good working order. The specifications of metering equipment including accuracy. The adjustment factors including circuit losses to be applied. export. PROPER ORDER
3. Where the data in the metering information register indicates that the Commercial Meters or Metering Equipment do not comply with the requirements of this GMC. The identification of the Users concerned. Meters.1. and reliable power supplies
Any remote communications to the metering equipment. as it considers suitable. The owner of each Commercial Meter. import).
3. The Market Operator may agree.
(h) Metering System function (main.1.3 of this GMC. The Market Operator will maintain a register of all Commercial Meters for settlement purposes at all Connection Points. check. This register will contain.Metering Code – Version 01
(a) 24 hour is located (b) (c) 3. Location of the Commercial Meters and Metering Systems. Meter manufacturer. as well as the services associated with the remote reading.2. and connection equipment will be the responsibility of the Market Operator.
shall perform to verify compliance with this GMC. The minimum set of tests a manufacturer or an authorised Metering Test Station. Electricity Meters may be purchased ready certified (in which case independent certification shall be provided by the manufacturer).
. or ask for a new certification or an extension of the existing certification.1. by an approved Metering Test Station. in order to make or inspect any adjustments thereto and to attend any tests or inspection thereof required pursuant to this Grid Metering Code.1.5 of this GMC. CALIBRATION AND TESTING OF METERING SYSTEM
4. and the User shall replace the Meter.1.1.7.1. In the later case. calibrated or compensated in accordance with this Grid Metering Code in order to meet the accuracy requirements stated in Chapter 2. which in no case will exceed [fifteen (15)] years.4. the Meter Test Station which will perform the test will issue the required certification.
4.5. and shall be further certified in Nigeria by an authorised Meter Test Station. be certified.
SECTION: CERTIFICATION. This new certification or extension of the existing certification shall be issued by an authorised Meter Test Station. shall be issued for a pre-definite period of time. The Market Operator shall be granted access to such Metering Equipment upon reasonable notice and at reasonable times.
4.2. which may require performing additional test or verifications by an authorised Meter Test Station before issuing it. as the case may be.6. as the case may be.1. All these tests shall be performed not later than one (1) year from the Effective Date the code comes into effect. or tested to confirm that their accuracy conforms to this GMC within the permitted recalibration interval by an authorised Meter Test Station.Metering Code – Version 01
4. The adequacy of any certification issued by a manufacturer shall require prior approval by the NERC.1. at the Effective Date and thereafter. and will contain different provisions regarding the frequency and characteristics of the calibration tests to be performed. and shall clearly indicate the minimum required calibration tests and their frequency to maintain its validity.
4.3. All electricity Meters and Metering Equipment used in Nigeria shall be certified to the required accuracy and the standards specified in this code.1. after the execution of tests and verifications the Metering Test Station considers relevant. Each User shall ensure that all Meters and Metering Equipments for which it is responsible shall. CERTIFICATION
4. After that period the certification will expire.1. and issuing the corresponding certification shall be in accordance with Appendix A of this GMC. Certifications of Meters issued by an authorised Meter Test Station or the approval issued by the NERC in case of certifications issued by the manufacturers.
4. Existing uncertified Meters and metering equipment shall be replaced by certified meters.
4. Meters shall be periodically checked. All initial calibration of Meters and Metering Equipment shall be performed by authorised Meter Test Station. at Connection Points of Type 1.2.4. challenge invoices on a prompt. 3 or 4 (i) (ii) Meters: Every 2 years CTs and VTs every 5 years. and 4. These tests shall be performed in accordance with the relevant IEC standards and shall confirm that Meter and Metering Equipment accuracy is within the limits stated in 2. A unique identifiable calibration record shall be provided before the connection is made live. and keep appropriate records of meter readings and where appropriate. upon an instruction by the Market Operator.4. INITIAL CALIBRATION
4.1. will undertake the testing of the Meters and associated Metering Equipment. The User will.2.
4. Where there is a change to a previously notified commissioning date. to ensure that meters are operated within the acceptable accuracy limits specified in this GMC so that the Users are able to prepare. calculate.2. the relevant User must notify the Market Operator and any Users of the details of the new Metering System or changes to the existing system at least one (1) calendar month prior to the commissioning date. at Connection Points of Types 5 and 6 (i) (ii)
.5 below.
4. Such testing shall be in accordance with Appendix B of this GMC.5.3.2. If the Meters are adjusted to compensate for errors in the CTs and VTs. prior to the completion of commissioning. as stipulated in sections 4.
4. Where commissioning is required owing to the installation of new Metering Equipment or a modification of existing Metering Equipment. COMMISSIONING TESTS
Meters and Metering Equipment.Metering Code – Version 01
4. 2. New voltage transformers and current transformers shall be calibrated by the Meter Test Station prior to installation at any site.3.2.1. Regardless of the calibration requirements stated in the certification issued. the User must notify the other parties of such change. assess and validate. undertake testing in accordance with t h i s clause to ensure that the metering complies with the requirements of Chapter 2. Meters: Every 5 years CTs and VTs every 5 years.1.4. then the CTs and VTs will also be tested every year. comprehensive and accurate basis.5 and that such testing is witnessed by the nominated representative of the Market Operator. according the following schedules: (a) Meters and Metering Equipment.2. Meter owners shall provide manufacturer’s test certificates to the Market Operator to show compliance with the accuracy standards. PERIODIC TESTS
4. the owner.
5. With regards to all testing in Nigeria. in addition to the costs that the owner must now incur to restore the Metering System to compliance with the GMC. The cost of calibration testing must be met by the party requesting the test unless the test shows the accuracy of the Metering System does not comply with the requirements of this GMC. and will be witnessed by the nominated representative of the Market Operator. The cost of routine testing shall be met by the owner of the Metering System.5. TEST FAILURE
4. the certification issued for the Meter or Metering Equipment which has failed the test will automatically expire. if necessary.1.4. OTHER PERIODIC TESTS
4. in which case the cost of the tests must be met by the owner of the Metering System.1. relevant User or Associated User.4. then the Market Operator and all Users and Associated Users that have an interest in this Metering System shall also be informed of the failure.5.6.5. and (b) make repairs or replacements to the Metering System to restore the accuracy to the required standards. the accuracy of the Metering System is shown not to comply with the requirements of this GMC. or non-compliant or outside the accuracy stated in Chapter 2.2. and a new one will be required.
4. Results of the tests that shown the Commercial Metering comply with this GMC will be sent to the Market Operator and the party that has requested the tests within 5 Business Days of the completion of such tests by the Meter Test Station. Such notification shall include the plans by the
4. then such testing shall be witnessed by a representative from the Market Operator and.
. The owner of a Check Metering System or a Commercial Metering System will undertake calibration testing upon request by the Market Operator. Where a User undertakes testing of its own Commercial Metering. an Associated User.5.
4. The owner will at its own cost: (a) consult with the Market Operator and the Associated Users in regard to the errors found and the possible duration of the existence of the errors.Metering Code – Version 01
4.4.6. Where a Commercial Metering System is found to be faulty. Where. 4.5.5.3.
4.6. it may request accuracy checks in accordance with Appendix A.2. following a test.
The above mentioned test shall be performed by an authorised Meter Test Station.4.5. such work will only be undertaken by an authorized Metering Test Station.
4. Where a User or Associated User reasonably believes the Commercial Metering System used for its data collection is operating outside the accuracy limits required by this GMC.3. The User shall notify the Market Operator and the Associated User its intention to undertake such test with at least 15 business days in advance.
to be sealed by the Market Operator or on its behalf. replacement or renewal and to recover its own costs.1. Following the Effective Date.
5.2. make arrangements for all Metering Equipment as are capable of being made secure. A record of any such access shall be maintained by the Market Operator and the User on whose premises the Meters and Metering Equipment are positioned. All relevant Users shall ensure. unless it is necessary to do so in circumstances where: (a) Both main and check meters are malfunctioning or there occurs a fire or other similar hazard and such removal is essential and such consent cannot immediately be obtained (provided that the person which has affixed the seal and which has not given such consent shall be informed forthwith thereafter) or (b) Such action is required for the purposes of Provision 4.3. No seal applied pursuant to this Grid Metering Code shall be broken or removed except in the presence of. Where verbal consent is given it must be confirmed in writing forthwith. including any revised readings that were provided during the period that the Metering System was faulty or non-compliant.1. if appropriate. if necessary. the Associated User. or following any test or inspection carried out according to Section 4. where practicable. In addition all Meters and
5. or on whose behalf the seal has been affixed. that physical access to Meters and Metering Equipment is. the Market Operator and. having regard to the physical and electrical configuration at each Connection Point. expenses and profit thereon from such User forthwith on demand (such profit to be based on a reasonable rate of return which shall be approved by NERC).1. in accordance with the procedures stated in Appendix B. or with the prior consent. following the Effective Date.6. restricted to personnel who are required to have such access for the proper performance of their duties and have received permission for such access. the Associated User affixing the seal. Copies of such records shall be provided to the the Associated User on request.1. Sealing shall be in accordance with the procedures stated in Appendix C.1. 5. SEALING:
5. except where sealing is impossible or impractical in the reasonable opinion of the Market Operator or the Interested User.1. except where impossible or impractical having regard to the physical and electrical configuration at each Connection Point.
SECTION: SECURITY AND DATA ACCESS
5. adjust or replace or renew any defective component.6. so far as they are able.4. the Commercial Meters shall be sealed by or on behalf of the Market Operator and.Metering Code – Version 01
owner to restore the Metering System to compliance with this GMC and the procedures to be followed to determine any estimated readings during the period. adjustment.4. Each User shall. the Market Operator or the Associated User shall have the right to carry out such repair.4.
. 4. of the owner. In the event that a User cannot or does not comply with its obligations to repair.
5.5. where practicable.2.1. or with written agreement of the Associated User. With respect to any Commercial Metering only the owner of the Metering System will change data and settings within its metering equipment and in: (a) The presence of the Market Operator. ACCESS TO METERING DATA
5. All such pliers shall bear a distinctive mark. Access to Meter data by any User of the Commercial Metering Systems. if necessary by making the lock and keys subject to similar access restrictions.Metering Code – Version 01
Metering Equipment. unless agreed otherwise in writing by the parties concerned.1.2. and shall keep an accurate register of all such pliers and the authorised persons to whom they are issued.3. must be made secure. the owner of the Metering Systems will allow reading of the Meters by the Market Operator and by the User whose consumption is measured by the Metering Systems. Each User.
5. 5. Associated User or Market Operator shall control the issue of its own seals and sealing pliers. or its authorised representative.2. or with the written agreement of the Market Operator (b) The presence of the Associated User.
.2. will be at that User’s cost. or its authorised representative. including the provision of any remote access equipment required.2. With respect to any Commercial Metering.
.1. maintain. including the procedures to be complied with by the distributor. operate.2. other than Prepaid Meters. or seeking connection to the Distribution System which in this part of the MC (the Distribution Metering Code) are: (i) (ii) (iii) 1. The Distribution Metering Code applies to the following: (a) Distributors (b) Users connected to. Ensure that each Metering System installed on its Distribution System is certified. and the NERC may or may not grant such derogation and may impose any conditions as it reasonably sees fit. It also applies to users in so far as their equipment may affect the distribution system.3. verify.1. Customers connected to the LV Distribution Network Customers connected to the MV distribution network. other than Prepaid Meters. PURPOSE AND SCOPE
The Distributor shall: (a) (b) Own. is in working condition and has been tested for accuracy where so required by this MC.1. Retrieve data from each Metering System. in carrying out its obligation to provide metering services to users at each metering point.1. installed on its Distribution System for the purposes of billing and settlement. inspect and replace all Metering Systems at Metering Points on the Distribution System. provided they are not Participants in the Market
1. install.Metering Code – Version 01
PART 3: DISTRIBUTION METERING CODE 1. The purpose of this distribution metering code (dmc) is to specify the technical and operational criteria. SECTION: INTRODUCTION
1. functional and technical requirements and applicable standards set out in this DMC. and Notify the NERC of all Metering Systems where the Distributor cannot comply with this Distribution Metering Code and shall seek derogation from the NERC.1. installed on its Distribution System for the purposes of billing and settlement. provided they are not Participants in the Market Generation Connected to Distribution. Process data retrieved from each Metering System. Ensure that each Metering System installed on its Distribution System meets the performance.
2. the NERC shall promptly consider such a request provided that the commission considers that the grounds for the derogation are reasonable. 1. if relevant.2
1. if any . although not fully meeting the standards as listed in Condition 2. it shall without delay report such non compliance to the NERC stating the reasons for non-compliance and the proposed remedy for this situation Where a Distributor has received professional technical advice that the proposed equipment or existing equipment. can be submitted to the Distributor or the NERC. 1. or by which such derogation expires.and
1.5 To the extent of any derogation granted. the commission may contact the relevant users to obtain clarifications of the request or request additional information or to discuss changes to the request.6 The NERC shall:
.2. (b) identification of the Meters or Metering Equipment in respect of which a derogation applies and.4 On receipt of any request for derogation. 1. the reason for the non-compliance requiring derogation. DEROGATIONS
1. (c) (d) (e) identification of the provision with which the derogation applies.4 Technical Requirements and Accuracy of Meters is capable of performing to the required levels of accuracy contained in t h i s D M C and/or then such advice and evidence of the performance of the equipment concerned. the nature and extent to which the derogation applies including alternate compliance provisions. Any request for derogations from any provision of the DMC by a Distributor shall contain: (a) the issue number and the date of the DMC provision against which the derogation applies. as due process for a derogation request if the Distributor wishes.2.2. In its consideration of a derogation request. as appropriate.2.Metering Code – Version 01
1. proposed remedial actions.2. the distributor shall be relieved from its obligation to comply with the applicable provision of the dmc and shall not be liable for failure to so comply but shall comply with any alternate provisions as set forth in the derogation.2.1 If a Distributor finds that an existing installation cannot comply with the standards contained in this DMC or cannot meet the required accuracy levels. and review possible remedial actions to achieve compliance as soon as reasonably practicable.3
(f) the date by which the derogation ends if compliance will be achieved.
provide a copy of such register of derogations to such User. (c) Where a material change in circumstance has occurred. identifying the name of the Distributor in respect of whom the derogation has been granted. the relevant provision of the DMC and the period of the derogation. and any derogations under consideration. and (b) on request from any User.Metering Code – Version 01
(a) keep a register of all derogations which have been granted.
. may be initiated by the NERC. a review of any existing derogations.
The Distributor shall. and Documentation of Meter testing prior to installation.Metering Code – Version 01
2. Record the identification of the ancillary equipment. and Record the initial Meter register reading. in accordance with the provisions of the Distribution Code.3 and 2. The distributor shall maintain the following information for each metering system: (a) (b) (c) (d) Location of the Metering System. unless that replacement is provided as part of urgent metering services.1.5. on request.
The distributor may replace metering equipment for which it is responsible at any time after it has been installed. cross-referenced to the location of the Metering System. A record of any calibration of the Metering System including any test results made to the Metering System A record of any malfunction of the Metering System including any repairs made to the Metering System. shall ensure that a final Meter reading is obtained.1. The Distributor shall: (a) (b) (c) Assign a unique identifier to the Metering System.1.
The installation of Metering Equipment shall be made as close as practicable to the Connection Point. 2.2.
(g) (h) 2.
SECTION: OBLIGATIONS AND REPLACEMENT OF METERING
2. Record the date of installation of the Metering System.1. if the later exists.1.1.3. where required by this Distribution Metering Code.4.
2.1.1. subject to the provisions of this distribution metering code. Ensure that the metering data stored in the Metering System is retrieved and. INSTALLATION EQUIPMENT
2. where a meter is removed. Record any site-specific loss adjustment factors to be applied.4 to: (a) The User. as it corresponds. make available for each Metering System the information listed in DMC Paragraphs 2.1. and identification of the meters designated as the main Meter and as the Check Meter. Record the functionality of the Meter and the unit of measurement used to measure active or reactive Energy flowing through the Metering System or Maximum Load. The distributor shall notify the user in advance of any replacement. Record redundancy details and sources of check metering data.
6.0 The Distributor may agree with the User the use of more accurate Meters or Metering System in particular cases of Medium or Large Connections. (b) Metering CT of accuracy class 0.5.0 or better with 110 volts secondary voltage and 100VA burden per phase for star-star shall be provided. provided that for new connections made after the date of approval of the first issue of the GMC the minimum accuracy class shall 1. where applicable.Standard Medium Voltage Metering Systems: (a) (b) (c) (d) (e) 2.
Accuracy shall be as minimum class 2.5 or better with 5 amperes secondary current and 5VA burden shall be provided
2. Each Metering Point shall be situated as close as is reasonably practicable to the relevant Connection Point.0.4. . Shall record Active Energy (kWh).2.1.2. STANDARD METERING SYTEMS
2. being either 1-phase. 2.2. 2.2.2. 2-wire or 3-phase. Shall record Maximum Load in the cases the applicable tariffs specifies that.2. Shall contain a Meter or more than one Meter.2.Metering Code – Version 01
The NERC. Shall record Reactive Energy (kVArh). each of which is certified and complies with the standards stated in this DMC.
For each circuit: (a) Metering VT of accuracy class 1. or 20kA for 3 seconds for MV Metering Points at 11 kV and below. May record Reactive Energy (kVArh). and Shall have metering current and voltage transformers that are tested and comply with the standards stated in this DMC. of accuracy class 0.7.0 and metering current transformers.2. 4-wire type of accuracy class 2. Standard Low Voltage Metering Systems: (a) Shall contain a Meter or more than one Meter.
2.3. Shall record Maximum Load in the cases the applicable tariffs specifies that.5 with 5 amperes secondary current and 5VA burden.
The rated short-time current rating shall not be less than (a) (b) 25kA for 3 seconds for MV Metering Points above 11 kV.
2. Shall record Active Energy (kWh). each of which complies with the standards in this DMC.2.
repairs and replacement.4. ± 1.
(f) 2.4.2.5 watt-hour meters. where necessary. The maximum service life of Meters and Metering Equipment shall be as specified by the manufacturer of such equipments. in which to house the Metering System.1.
2.2. TECHNICAL REQUIREMENTS AND ACCURACY OF METERS
2. 2. metering current transformer(s) provided by the Distributor which are tested and comply with the standards stated in this DMC.2% for class 0.
2.0 watt-hour meters.5 S static watt-hour meters. and Shall contain a suitable facility (including all necessary pre-wiring). the Distributor may arrange for a Metering System to install a check meter. maintenance.4. ± 0. ± 0.4.0 watt-hour meters.9. The limits of accuracy for the following classes of Meters shall be: (a) (b) (c) (d) (e) 2. operation. Meters and Metering Equipment shall have a minimum service life of 10 years without maintenance from date of manufacture.5% for class 0.
2. but in any case not longer than 20 years unless a larger value will be authorized by the NERC.
.0% for class 2.Metering Code – Version 01
Shall contain. ALTERNATIVES TO STANDARD METERING SYSTEMS
(a) Upon the request of a User. The Distributor shall ensure that the accuracy of each Meter in each Metering System is certified by an authorised Meter Test Station and meets the applicable accuracy limits.5% for class 0. and (c) The additional features or equipment are compatible with the rest of the Metering System and do not lead to any degradation of the capability of the Metering System that would cause the Metering System to fail to meet any standards contained in this Distribution Metering Code.3. The following IEC standards approved for use with this DMC are: (a) IEC Standard 60044 Part 1 – Current transformers.
The Distributor may agree with the User the use of more accurate Meters or Metering Systems in particular cases of Medium or Large Connections. including the costs of installation. or to contain features or equipment in addition to those specified in this Distribution Metering Code provided that: (b) The User agrees to pay the full costs of the additional features or equipment. provided by the Distributor.2 S static watt-hour meters.
The accuracy of the various items of measuring equipment comprising Meters and Metering Systems shall conform to the relevant IEC standards or any equivalent Nigerian standards. ± 2.0% for class 1. ± 0.8.2.3.
IEC Standard 60044 Part 3 – Combined transformers. (e) IEC 60687 .5S (f) IEC 60136 . tests and test conditions (i) IEC 60253 . General requirements.Alternating Current Static Var-Hour Meters for Reactive Energy (Class 2 and 3) (h) IEC 60252 .Electric Metering Equipments (AC).Alternating Current Static Watt-Hour Meters for Active Energy classes 1 and 2 (g) IEC 61268 .Electric Metering Equipments (AC).Alternating Current Static Watt-Hour Meters for Active Energy classes 0.2S and 0. Particular requirements
(d) IEC Standard 60186 – Inductive voltage dividers (Only for Metering Systems installed before the Effective Date of this MC).Metering Code – Version 01
IEC Standard 60044 Part 2 – Voltage transformers.
shall be issued for a pre-definite period of time.
3. Prior to the installation of any Meter or Metering shall be: (a) Submitted by the Distributor to a Meter Test Station. Certifications of Meters or Metering Equipment issued by a manufacturer or an authorised Meter Test Station.1. The NERC shall permanently maintain a register of authorized Meter Test Stations. which has been accredited by the NERC for by the NERC to perform Routine Tests and certification. and shall clearly indicate the minimum required calibration tests and their frequency to maintain its validity. or (b) Received by the Distributor directly from a manufacturer with a test certificate endorsed by a Meter Test Station accredited by the NERC to endorse manufacturer’s certifications.7. These procurement recommendations should be used by the operators in order to purchase Meters and Metering Equipment of acceptable quality and performance. Certification of a Metering Installation will be valid as long as the certifications of all components of the Metering Installation remain valid. Regardless of the above mentioned recommendations. The Distributor shall submit copies of these certificates upon notice from the NERC.1. it is up to the Distributor responsibility to select the Meters and Metering Equipment which meet the accuracy and performance requirements contained in this DMC.1. CERTIFICATION OF NEW METERING INSTALLATIONS
3.1. 3.
3. and for Metering Equipment that is no longer in use. Every Meter Type (model) of meter intended to be used in a Metering Installation shall be certified (type-tested) by National Meter Test & Calibration Laboratory (NMTCL) or any other body as may be approved by NERC to perform this Type Tests. Test certificates shall be retained by the Distributor whilst the Metering Equipment is in use.
3.3. which in no case will exceed [twenty (20)] years. accredited to perform either: (a) Type Tests certification
SECTION: CERTIFICATION AND TESTS
3.4.Metering Code – Version 01
3.1.6. to confirm its specific characteristics and to prove that it complies with the requirements of relevant standards and accuracy class as outlined in Section 2.1.1. for a minimum period of five (5) years after the Metering Equipment has been decommissioned and rendered un-useable or scrapped. The NERC shall permanently maintain registers with the list of certified Meter Types The NERC will issue recommendations for Meters and Metering Equipment procurement.1. Certification shall be confirmed by the attachment of a seal or certification sticker for the individual Meters and Metering Equipment.2.5.
within the first twelve (12) months of the Effective Date of this DMC.2.2. in cases of sampling testing of more than one meter.2. The NERC will evaluate the submitted documentation. the installed Meter and Metering Equipment have undergone calibration or verification tests which are deemed compatible with the provisions of this MC. otherwise.2. which should demonstrate that the overall accuracy requirements stated in this MC are met. a pre-defined percentage of Meters shall comply with more stringent accuracy. In this case the NERC will determine the additional period of time that this certification will remain valid. The Distributor shall replace the equipment or obtain the above mentioned certification within [eight (8)] years of Effective date
3. before issuing or rejecting the required certification.
. Meters and Metering Equipment already installed in the Distribution System at the Effective Date shall be considered either: (a) Certified. Calibration reports will be required as part of the input to certification reports for Metering Installations.Metering Code – Version 01
Routine Tests certification Endorsement of manufacturer’s certifications Calibration Test certifications
On request from any Distributor or User the NERC shall provide a copy of such register to such Distributor or User 3. (b) 3. the Distributors shall replace the involved equipments or obtain a valid certification according with the procedures stated in Condition 3.3 Re-certification.1 (a). of specific samples of the Meters or Metering Equipment.2.
In order to obtain NERC’s certifications indicated in paragraph 3. by an authorised Meter Test Station. Non certified.3. CERTIFICATION OF EXISTING INSTALLATIONS
3. require clarifications and conduct independent analysis which should include testing.8.2.1. the Distributor shall submit. For uncertified Meters or Metering Equipment. a requirement to the NERC with all supporting documentation the Distributor considers suitable to support its claim.1.
3. The NERC will issue directives with the procedures to be applied and tests to be conducted to: (a) (b) (c) (d) Issue a Type Test certification Issue a Routine Test certification Issue a Calibration Test certification Endorsement of a manufacturer’s certification
These directives could specify that. if at NERC discretion.
or replacement.Metering Code – Version 01
3.1. or if additional components are connected to the Metering Installation (other than testing or monitoring equipment temporarily connected via the test block).3.2. Before the certification of a Metering Installation.3. including prepayment 3. approved by NERC.3. either static type or electromechanical) 4 years 8 years 8 years 8 years (see Note) Frequency
NOTE: For direct connected meters (without CTs).
3.2. including prepayment. INSPECTION AND PERIODIC TESTS
3. Any such component would be recertified by removal and tests. Certification of the overall Metering Installation expires when the individual certification of any one of its components expires.4. the certification of the Metering Installation should be deemed to be cancelled until the tests and checks prescribed by this MC have been satisfactorily carried out by an authorized Meter Test Station. provided that the Distributor has implemented sampling accuracy tests. has expired. the Metering Installation should require re-certification. If any part of the wiring of the Metering Installation is modified.3. Results of such sampling accuracy tests shall be kept by the Distributor for at least five (5) years and shall be made available to the NERC on request. which can demonstrate the statistical confidence that the calibration of the meter population for that category of meters is within limits. or of any of its components. Frequency Once every year Once every 3 years
The Distributor shall ensure that each Metering System is tested and calibrated by an authorised Meter Test Station accredited to perform Calibration Tests according to the minimum frequencies specified in following Table: Type of Metering System Medium Voltage Connection Capacity above 10 MW Connection Capacity between 1 and 10 MW Connection Capacity below 1 MW Low Voltage. RE-CERTIFICATION
3.3. as appropriate. by an authorized Meter Test Station accredited to perform Calibration Tests certifications.
.4.1.4. testing online. the calibration intervals shown above will not apply. 3. The Distributor shall ensure that each Metering System is inspected according to the minimum frequencies specified in following Table: Type of Metering System Medium Voltage Low Voltage.
random and unannounced inspection and or testing of any Metering System and associated data for the purpose of ascertaining whether the Metering System complies with the requirements of this DMC.4.
3.4. In addition.5.2. The Distributor shall. If a Metering System fault occurs. however caused.5. utilizing an authorised Metering Test Station if considered suitable. or malfunction not caused by the User is discovered. make the results of any inspection and or tests conducted pursuant to this section available to the requesting party and to the User associated with the Metering System. The Distributor shall ensure that suitable data is obtained or estimated for the period of time commencing when a Meter or Metering Equipment becomes faulty until the completion of the repair or replacement.
The Distributor may.
3. the NERC may carry out its own unannounced inspection and or test.3.
3. the Distributor shall provide Urgent Metering Services to repair or replace the Metering System as soon as is reasonably practicable and in any event within two working days of the Distributor discovering that the fault exists.5.5. and on the direction of the NERC shall. The User shall notify the Distributor of any damage to the Metering Equipment.5.5.Metering Code – Version 01
3. provided that the User pays the cost.3.4. The User may request the Distributor to carry out such inspection and or testing.1. The Distributor shall record all relevant Meter parameters for a replacement Meter in that Metering System.4. in which case the User shall grant access to the NERC. unless the test shown overall accuracy of the Metering Installation is not within the limits specified in this DMC.
3. The User shall use Metering Equipment in a safe and prudent manner and shall take due care to avoid damage.
. FAULTY METERING EQUIPMENT
3. as soon as practicable. carry out periodic. A Metering System shall be considered faulty and not in compliance with this Distribution Metering Code if it is determined that any part of that Metering System does not comply with this Distribution Metering Code.
4. random and unannounced audits required by DMC Section 3. Seals shall be replaced following works requiring the removal of any seals. maintain the security of the metering data stored in or obtained from each Metering System.
Prior arrangement by the Distributor shall not be required in respect of routine Meter reading.2.1. SECURITY OF METERING SYSTEMS
4.Metering Code – Version 01
4. 4. circuits. The Distributor shall. data storage and data processing systems.1. Ensuring that the Metering System meets the requirements for the security of Metering Systems set out in this Distribution Metering Code.2.
4. Where practicable.3. The Distributor shall use reasonable endeavours to ensure that all metering data within each Metering System is secure. The Distributor’s procedures for the control of seals and sealing pliers shall be subject to approval by the NERC. and The production of identification by the Distributor’s staff or contractor.
.1.3.2. or periodic. Appropriate seals shall be applied to each Metering System. ACCESS TO METERING SYSTEMS
4.2.2. prior notice by the Distributor.1. so far as is reasonably practicable.1. or when the Distributor is performing Urgent Metering Services. This right of access is conditional upon: (a) (b) 4. ensure that physical access to each Meter contained in each Metering System is protected by: (a) (b) (c) Sealing all associated links. so far as is reasonably practicable. The Distributor shall.
SECTION: ACCESS AND SECURIY
4.2. The User shall grant access to the Distributor to enable the Distributor to fulfil its obligations under this Distribution Metering Code.
The Distributor shall schedule at least once in four (4) reading for all manually read meters. Where the User is billed for maximum Reactive Power. inaccurate.3..
5. Validate metering data for each Metering System.2. and Details of any Meter alarms that were recorded during the period (e.g. the Distributor shall verify at each Meter reading that the Meter identification number on the Meter matches the Meter identification number on the Meter reading schedule.1.
.2. system outages.3.1. Where the User is billed for maximum Active Power. the cumulative Reactive Energy (kVArh) recorded during the Meter reading period.
5.1. or otherwise not suitable for settlement purposes. The Meter reading and read date at the beginning of the Meter reading period.
SECTION: METER READING AND DATA MANAGEMENT
5. The Distributor shall specify the type of equipment to be used for communication with remote meters. The cumulative Active Energy (kWh) recorded during the Meter reading period. The Distributor shall conduct such tests as it deems necessary to verify production or consumption recorded at each Metering Point. DATA MANAGEMENT
5. the maximum Active Power recorded during the Meter reading period.1. The Meter reading and read date at the end of the Meter reading period. the maximum Reactive Power recorded during the Meter reading period. The Distributor shall record: (a) (b) (c) (d) (e) (f) (g) (h) The Meter identification number. Estimate usage when Meter readings are not available.Metering Code – Version 01
5.2.1.1.1. REMOTE METERING EQUIPMENT
5. Where the User is billed for Reactive Energy. VT failure). 5.2. The Distributor shall: (a) (b) (c) Maintain a metering data registry that contains usage data for each User and data required for settlement purposes in respect of each Metering System. 5.3.
5. For kilowatt-hour meters.2. METER READING
The existence of redundancy and sources of check metering data. Data for each Meter following completion of the validation and estimation procedures. The Meter Type installed Identification of the ancillary equipment. Any site-specific adjustment factors to be applied. including a cross reference to the unique identifier specified in (a) above. Where necessary.5. determine site-specific loss adjustment factors for each Metering System. The Distributor shall establish and maintain a register that contains the following information for each Metering System: (a) A unique identifier assigned by the Distributor to the Metering System crossreferenced to the location of the Metering System and cross referenced to the User’s account. and identification of the meters designated as the Main Meter and as the Check Meter.4.g.
5. kWh meter. where required by this DMC. DATA VALIDATION AND LOSS ADJUSTMENT FACTORS
5. kVArh meter). Multiply each valid reading by the appropriate loss adjustment factor to produce loss adjusted production or consumption.1.Metering Code – Version 01
Apply adjustments to metering data to account for system losses and unaccounted for energy. The functionality of the Meter and the unit of measurement used to measure Energy flowing through the Metering System (e. and Shall maintain both unadjusted and loss-adjusted values in the metering data registry in respect of each Metering System. and The data covering a period of not less than twelve months which shall be immediately accessible in electronic form.5.
. DATA REGISTRATION
5.. The Distributor shall: (a) (b) (c) (d) Have in place data validation procedures and loss adjustment calculation methodologies approved by the NERC.1.
5. Aggregate metering data for settlement and loss calculation purposes. and Use reasonable endeavours to maintain the security and confidentiality of the metering data.4. The date of installation of the Metering System. Billing data for each Meter following completion of adjustments for losses and unaccounted for energy.
METERING CODE – APPENDIXES
1. This Section sets out those tests and checks that shall be performed by a manufacturer or a Metering Test Station to the Meters and Metering Equipment in order to certify compliance with this MC. GENERAL
Potential Transformer (PF) (a) (b) (c) (d) Verification of marking and polarity wiring HV Power Factor :. MEASUREMENT TRANSFORMERS
1.1.secondary windings to earth at 3KV injection for 1 minute (c) (d) (e) HV Power Factor (HP) test at 2KV for 1 minute on secondary winding Interturn over-voltage test (injection 1 Amp on secondary) Partial discharge in accordance with ICE60270-2000
APPENDIX A – CERTIFICATION TESTS
1. Current transformer (CT) The following test shall be conducted in compliance ICE 60044-1: (a) Verification of marking and polarity wiring (b) HV Power Factor (HP) test:.1.2.1.Metering Code – Version 01
1.secondary winding to earth at 3KV injection for 1minute HV power Factor test at 2KV for 1 minute on secondary winding Partial discharge in accordance with IEC 60270-2000
(e) Induced over-voltage test by injecting 234V at 150c/s on secondary winding for 40second
6 % -/+ 1.Metering Code – Version 01
1.5 Lagging Power Factor.5 % -/+ 1.0 % -/+ 0.6 % -/+ 0. Test Condition Expected results
The meter accuracy should be within the limits as specified below
The meter is connected to voltage equal to Vref and the accuracy is checked at following values of current and power factor in all the Phases.)
Unity Power Factor 1 2 3 4 5 6 7 8 9 10 11 12 1 % In 5 % In In Imax 2 % In 10 % In In Imax 2 % In 10 % In In Imax -/+ 1.0 % -/+ 0.5 Volts (Phase.0 % -/+ 0.8 Leading Power Factor.
0.6 % -/+ 0.5 % -/+ 0.e.6 % -/+ 0. (i.6 % -/+ 0.5s Vref: 65.
0.Neutral) In: 5 Amps or 1 Amps Imax: 10 A or 2 Amps PF: Lag / Lead / UPF Sr. Earthed load condition.
Accuracy Accuracy Testing for Meters of Accuracy: 0.3.No.1.3.5 % -/+ 0.
e no supply to be given to the meter.
No load test No Load Test
Vref: 73. The maximum test period should be limited to 200mins.Neutral) In/ Ib= 0 Amps (Current circuit Open) Time Duration: 200 Mins. Meter should be fully functional within 5 seconds after rated voltage applied
1. Sr.2.Metering Code – Version 01
1.No. current and auxiliary circuits (if any) connected together and frame.3.
Meter should not produce more than one output pulse.02 Volt (Phase.
The current circuit of the meter should be open circuit and a voltage of 115 % of the reference voltage should be applied for min 20 times the actual test period of starting conditions.
Insulation Test Insulation Test Parameters This test is to be conducted in power off conditions i.3.
>= 5 Mohms (MΩ)
Between circuits not intended to be connected together in service
>= 50 Mohms (MΩ)
.3. Test Condition
Insulation resistance to be measured with 500 VDC megger
Between all voltages.
4. Test condition 1 Power consumption circuit: in Expected Result voltage Less than 1W and 2VA.Neutral) HT Meters In/ Ib= 0 Amps (Current circuit Open) Power Factor: UPF (Unity) Sr.5 Volt (Phase.Neutral) In= 1 A for 33 kV HV Meters 2 Power consumption in Current Less than 1VA circuit: Current equal to In to be passed through current circuit.
Voltage circuit is connected to rated voltage and the current circuit is kept open. Test of Power Consumption-Current Circuit Parameters Vref: 0 Volt (Phase.No.
Test of Power Consumption Test of Power Consumption-Voltage Circuit Parameters Vref: 63.3.Metering Code – Version 01
for 1 A for Cl.5 Volt (Phase. to 0.1 % of In= 0.5s PF: UPF (Unity Power Factor) Test Condition Expected Results
The meter should be connected to Meter should start and continue voltage equal to Vref and current equal to register.5 meters The Variation in the percentage error should not exceed 0.5 meters.25 for class 0.25 for class 0.Neutral) In: 5 or 1 Amps Imax: 10 A for In 5 A Imax: 2 A for In 1 A PF: UPF (Unity Power Factor) Time Intervals: 5 Min Sr.5 meters
5 % In 10 % In In
The Variation in the percentage error should not exceed 0.001 A.
Repeatability of Error Test Repeatability of Error Test for Accuracy class 0.3. Twenty error samples should be taken for the test.
Starting Condition Starting Condition Test Parameters Vref: 63.6. of accuracy 0.3.5s Vref: 63.5 meters The Variation in the percentage error should not exceed 0.5s at unity power factor.
1.Metering Code – Version 01
1. The same procedure is to be adopted for each circuit
The Variation in the percentage error should not exceed 0.No.5 Volt (Phase.1 % of In for meters having accuracy class as 0. Test Condition
The meters should be connected to voltage equal to Vref and the accuracy should be measured at time interval of 5 minutes at the following currents at unity power factor.Neutral) for HT Meters I= 0.25 for class 0.25 for class 0.
± 0.5 Lag
Reference Frequency: 50 Hz
Sr.4 %
Frequency Variation Test for Accuracy class 0. Voltage and Current.2 %
. The same procedure should be adopted for each phase circuit
Unity power factor and Voltage = -10 % Vrated Unity power factor and Voltage = +10 % Vrated 0.Neutral) for HT Meters In: 5 A or 1 A Imax: 10 A for In A Imax: 2 A for In 1 A PF: UPF (Unity Power Factor) & 0.5 Lag power factor and Voltage = -10 % Vrated 0.
Voltage and frequency Variation Voltage Variation Test for Accuracy class 0.4 % ± 0.2 % ± 0.2 %
± 0.No.5 Lag power factor and Frequency= 49 Hz (-2% of rated Frequency) 0. power factors as listed below.5s
The impact of frequency variation on the meter should be checked at current equal to Ib and voltage equal to Vn.5 Volt (Phase.Metering Code – Version 01
1.2 % ± 0.
The impact of voltage variation on the meter should be checked at current equal to In and the voltages. The same procedure is to be adopted for every phase circuit The variation in errors should not exceed by the following values as compared to the errors at Rated Frequency.3.7.
Unity power factor and Frequency= 49 Hz (-2% of rated Frequency) Unity power factor and Frequency= 51 Hz (+2% of rated Frequency) 0.5 Lag power factor and Frequency= 51 Hz (+2% of rated Frequency)
± 0. Power factors and Frequency as listed below. Test procedure Expected Result The variation in errors should not exceed by the following values as compared to the error at rated voltage.5 Lag power factor and Voltage = +10 % Vrated
± 0.5s
Vref: 63.
If it is not possible to confirm the CT ratio on site then the reason must be recorded on the commissioning record and details must be obtained from any relevant other party.
For installations with existing measurement transformers the Market Operator and/or User shall ensure that.
2. accuracy classes.2.3. (b) (c) 2. VT ratio and phasing for each winding. items a.
(c) Determine and record the value of any burdens (including any nonCommercial Metering burdens) necessary to provide evidence of the overall metering accuracy.1. insulation and continuity. Metering equipment shall in addition have basic tests carried out on earthing. ratio(s).3. including serial numbers.
2.1. MEASUREMENT TRANSFORMERS
2. wherever practically possible.1. MEASUREMENT TRANSFORMERS LEADS AND BURDENS
2. Confirm that the VT and CT burden ratings are not exceeded.Metering Code – Version 01
2. CT ratio and polarity for selected tap.2. voltage transformer. In addition during the commissioning of new or modified parts of the installation including the meter.1. current transformer and data recorders then these shall be confirmed as being in accordance with the approved drawings to avoid equipment with for example a wrong ratio or a wrong specification being inadvertently connected.2.
APPENDIX B – COMMISSIONING TESTS
2. For all installations with new/replaced measurement transformers the Market Operator and/or User shall ensure that from site and/or factory tests and inspections the following are confirmed and recorded: (a) Details of the installed units. together with such other tests that would normally be conducted in accordance with Prudent Utility Practice. rating. b and c above are implemented but as a minimum must confirm and record VT and CT ratios. This Section sets out those tests and checks that shall be included in the metering commissioning programme.2. For all installations the Market Operator and/or User shall wherever practically possible: (a) (b) Confirm that the VT and CT connections are correct. GENERAL
factory. The following tests shall be performed on site: (a) Check any site cabling.1.. any Meter VT/CT ratios. (c) Confirm correct operation of Meter test terminal blocks where these are fitted (for example. (e) Confirm that meter registers advance (and that output pulses are produced for Meters which are linked to separate outstations) for import and where appropriate export flow directions.
.): (a) Record the Metering System details required by the Data Collection System. METERING
GENERAL TESTS AND CHECKS 2. (d) Check that all cabling and wiring of the new or modified installation is correct and is clearly marked and or colour coded. (f) Confirm Meter operation separately for each phase current and for normal polyphase current operation. connections not previously checked under clause the General Tests above.Metering Code – Version 01
2. SITE TESTS 2. laboratory.2. where applicable. (f) Where for practical or safety reasons the previous site test (e) above is not possible then the reason shall be recorded on the commissioning record and a secondary prevailing load or injection test shall be performed to confirm that the Meter registration is correct including. (g) Where separate outstations are used confirm the Meter to outstation channel allocations and that the Meter units per pulse values or equivalent data are correct. (c) Check that the voltage and the phase rotation of the measurement supply at the Meter terminals are correct.4. In such cases the VT/CT ratios shall have been determined separately as detailed. a primary prevailing load test (or where necessary a primary injection test) shall be performed which confirms that the Meter(s) is registering the correct primary energy values and that the overall installation and operation of the Metering System is correct. (d) Record Meter starts readings (including date and time of readings). operate correctly. (b) Confirm that Meter/outstation is set to UTC + 1 within ± 5 seconds. Meter Test Station. wiring. etc.4.4. (h) Confirm that the local interrogation facility (Meter or outstation) and local display etc. (e) Wherever practicable. CT/VT operated metering). (b) Confirm that the VT/CT ratios applied to the Meter(s) agree with the site measurement transformer ratios. The following may be performed on-site or elsewhere (for example.
(h) Confirm the operation of metering equipment alarms (not data alarm or flags in the transmitted data).Metering Code – Version 01
(g) Record values of the Meter(s)/outstation(s) displayed or stored data (at a minimum one complete half-hour value with the associated date and time of the reading) on the commissioning record.
3.1. SEALING PROCEDURE AT THE LABORATORY
3. 3. Every meter terminal cover shall be sealed after installation at the customer premises in the case of 1-phase and 3-phase meters In the case of MD meters.2.4. For any of the above mentioned purposes.3. The Meter Test Station shall keep records of the seals fixed on meters certified by the Station.3. Every meter cover shall be sealed after certification at the laboratory by the Meter Test Officer. the meter terminal cover shall also be sealed.1 and 2. 3.2.1. SEALING PROCEDURE AT POINT OF INSTALLATION
3.6.2. voltage fuse holders.1. CT terminal. RECALIBRATION. breaking of seals shall be done in the presence of the customer or his representative
. SITE TESTING OF METERS ETC
3.3. SEALING PROCEDURE AT POINT OF MAINTENANCE. The sealing procedure described in 2.2.2.2 above shall be witnessed by the representative of the customer.
3.2. 3. a copy of the certificate shall be forwarded to the Market Operator to update his records The sealing certificate shall contain the following information:(a) (b) (c) (d) (e) (f) (g) (h) Present seal serial number.
APPENDIX C – SEALING PROCEDURES
3. 3. the terminal cover test terminal block. VT terminals. For MD meter. INSPECTING.1.1.2.
3. meter boxes/cubicle shall be sealed by the meter installer. Previous seal serial number Date of sealing Purpose of sealing Meter serial number Name of the Installer Name and signatures of Meter Installer Name and signature of Customer or his representative.2. 3. A certificate duly signed by the Meter Installer and the customer or his representative shall be issued by both parties For meters at the electricity trading points.1.5.2.
To withstand operating temperature of up to 70oc Colour -To be of any colour Wire Dimension .Not more than 2.
Average Break Strength .Compressible or non-compressible type Material .
3. SEALS SPECIFICATIONS Type .2. 3. For meters at the electricity trading points procedure 3.Reasonably large break strength
3.3.4.6 above.Plastic with embossed serial number Temperature Range .
All the sealable points where seals were broken for any of the above-mentioned purpose shall be resealed in the presence of the customer or his representative and an updated seal certificate issued.5mm2 cross-sectional area. and Metering box or cubicles
. SEALING POINTS Every metering system shall be sealed at the following sealing points:(i) (ii) (iii) (iv) (v) (vi) (vii) Meter cover Meter terminal cover Test terminal cover Voltage fuses & Links CTs and VTs terminals Associated circuits.3.2.5 shall be followed A sealing certificate for this purpose shall contain information listed on 3.3.
3.3.Metering Code – Version 01
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