{"id":"national-electricity-northern-territory-national-uniform-legislation-modification-regulations-2016","name":"NATIONAL ELECTRICITY (NORTHERN TERRITORY) (NATIONAL UNIFORM LEGISLATION) (MODIFICATION) REGULATIONS 2016","slug":"national-electricity-northern-territory-national-uniform-legislation-modification-regulations-2016","collection":"regulation","jurisdiction":"nt","status":"in_force","isInForce":true,"actNumber":null,"makingDate":null,"administeringDepartment":null,"currentVersion":{"id":177044,"registerId":"nt-national-electricity-northern-territory-national-uniform-legislation-modification-regulations-2016-current","compilationNumber":null,"startDate":"2026-04-05","status":"InForce","reasons":null,"registeredAt":null},"sections":[{"sectionNumber":"1","sectionType":"section","heading":"Citation","content":"1 Citation\nThese Regulations may be cited as the National Electricity\n(Northern Territory) (National Uniform Legislation) (Modification)\nRegulations 2016.\n","sortOrder":0},{"sectionNumber":"2","sectionType":"section","heading":"Commencement","content":"2 Commencement\n(1) Regulation 9 and Schedule 3 commence on 1 December 2016.\n(2) The remaining provisions of these Regulations commence on\n","sortOrder":1},{"sectionNumber":"2A","sectionType":"section","heading":"Definitions","content":"2A Definitions\nIn these Regulations:\n","sortOrder":2},{"sectionNumber":"2014","sectionType":"section","heading":"NT Network Price Determination, for Part 3, see","content":"2014 NT Network Price Determination, for Part 3, see\nregulation 4(1).\napplicable regulatory instruments, for Part 3, see regulation 4(1).\nlocal support, for Part 3, see regulation 4(1).\n","sortOrder":3},{"sectionNumber":"Part 2","sectionType":"part","heading":"Modifications to National Electricity","content":"Part 2 Modifications to National Electricity\n","sortOrder":4},{"sectionNumber":"3","sectionType":"section","heading":"National Electricity Regulations modified","content":"3 National Electricity Regulations modified\nFor section 13(2)(b) of the Act, the regulations in force from time to\ntime under Part 4 of the National Electricity (South Australia)\nAct 1996 (SA) are modified as set out in Schedule 1.\n\nRegulations 2016 2\n","sortOrder":5},{"sectionNumber":"4","sectionType":"section","heading":"Interpretation","content":"4 Interpretation\n(1) In this Part:\n2014 NT Network Price Determination, see the National\nElectricity (NT) Rules, Chapter 10.\napplicable regulatory instruments, see the 2014 NT Network\nPrice Determination, Part B, Schedule 1, clause 1.1.\nlocal support means credit support as defined in the 2014 NT\nNetwork Price Determination, Part B, Schedule 1, clause 1.1.\n(2) An expression used in regulation 6, 6A or 7 that is italicised has the\nsame meaning as it has in the National Electricity (NT) Rules.\n","sortOrder":6},{"sectionNumber":"5","sectionType":"section","heading":"National Electricity Rules modified","content":"5 National Electricity Rules modified\nFor section 13(2)(c) of the Act, the operation of the National\nElectricity Rules is modified as set out in this Part for the purpose of\ntheir having the force of law in this jurisdiction under section 9 of the\nNational Electricity (NT) Law.\n","sortOrder":7},{"sectionNumber":"5A","sectionType":"section","heading":"Application of Rules in this jurisdiction","content":"5A Application of Rules in this jurisdiction\n(1) The following provisions of the National Electricity (NT) Rules have\nno effect in this jurisdiction:\n(a) Chapter 1, rule 1.11;\n(b) Chapters 2, 2A, 3 and 4;\n(c) Chapter 5, clauses 5.2.3(a) and (k), 5.2.4(d), 5.2.5(c) and (e),\n5.3.3(b2), (b3) and (b4) and 5.3.4(e) and (g), rules 5.3.4A and\n5.3.4B, clauses 5.3.5(e), 5.3.6(a2)(3), 5.3.7(c) and (g)(2)(i), (5)\nand (6), 5.3.8(b)(1) and (2)(iv), 5.3.9(a)(2), (b)(4), (c), (c1) and\n(f), 5.3.10(b)(3) and (c), 5.3A.3(b)(5) and (6)(xi),\n5.3A.4(e)(2)(ii), 5.3A.8(h), 5.3A.9(e), (f) and (h) and 5.3A.10(f),\nrule 5.3A.12, clauses 5.3AA(h), (i) and (j), 5.4.3(c) and\n5.4.5(e)(4), rule 5.7.3A, clauses 5.7.5(a)(2), 5.12.2(c)(6), (6A)\nand (8)(ii), 5.16.3(a)(8) to (11), 5.16.4(b)(4), 5.17.3(a)(7) and\n5.18A.3(d)(1), rules 5.20 to 5.22, schedules 5.1a to 5.3a,\nschedule 5.4A, paragraphs (a)(9), (i1) and (o)(3),\nschedule 5.4B, paragraphs (e) and (e1)(2), schedules 5.5,\n5.5.3, 5.5.4 and 5.5.5, schedule 5.6, paragraphs (c2) and (c3)\nand schedule 5.9, paragraph (h);\n(d) Chapter 5A, clause 5A.A.3;\n\nRegulations 2016 3\n(e) Chapter 6, Parts M and N;\n(f) Chapters 6A, 6B and 7;\n(g) Chapter 8, clauses 8.1.3(b)(5) and (7), 8.6.1(d) and (e),\n8.6.2(l), 8.6.6, 8.6.7, 8.7.2(a)(2) and (4) and (b)(2) and 8.7.6\nand Parts B, E, G and H;\n(h) Chapter 11, Parts A to ZZI, ZZK, ZZL, ZZN (except for\nclause 11.86.8), ZZO to ZZT, ZZV and ZZX.\n(3) The following provisions of the National Electricity (NT) Rules have\nno effect in this jurisdiction until the National Energy Retail Law is\napplied as a law of this jurisdiction:\n(a) Chapter 5A, clause 5A.C.1(c) and (d), the note to\nclause 5A.E.4(c) and clause 5A.F.5(b)(2);\n(b) Chapter 6, clause 6.6.1(a1)(4), (c)(6)(iii), (l) and (m).\n","sortOrder":8},{"sectionNumber":"6","sectionType":"section","heading":"Modification to operation of clause 6.6.1 in relation to local","content":"6 Modification to operation of clause 6.6.1 in relation to local\nevents\n(1) This regulation applies in relation to a positive change event that is\na local event prescribed by regulation 10.\n(2) Under clause 6.6.1(c) of the National Electricity (NT) Rules, the\nwritten statement in relation to the positive change event must\nspecify evidence of:\n(a) the amount to which the Distribution Network Service Provider\nis entitled under any relevant local support; and\n(b) the maximum amount of local support (if any) that the\nDistribution Network Service Provider was entitled to request\nthe retailer to provide under the applicable regulatory\ninstruments; and\n(c) any amount that the Distribution Network Service Provider is\nlikely to receive on a winding-up of the retailer.\n(3) For the purposes of calculating, under clause 6.6.1 of the National\nElectricity (NT) Rules, the eligible pass through amount in relation\nto the positive change event, the increase in costs is the retailer\ninsolvency costs excluding:\n(a) any amount recovered or recoverable from a retailer or a\nguarantor of a retailer under any relevant local support; and\n\n","sortOrder":9},{"sectionNumber":"Part 4","sectionType":"part","heading":"Matters prescribed for National Electricity (NT) Rules","content":"Part 4 Matters prescribed for National Electricity (NT) Rules\nRegulations 2016 4\n(b) amounts that the Distribution Network Service Provider is\nlikely to receive on a winding-up of the retailer; and\n(c) any costs that are recoverable on account of the retailer\ninsolvency under any retailer of last resort scheme established\nunder the applicable regulatory instruments.\n(4) The amount the AER determines, under clause 6.6.1 of the\nNational Electricity (NT) Rules, should be passed through to\nDistribution Network Users in respect of the positive change event\nmust be taken to be a cost that can be passed through and not a\nrevenue impact of the event.\n8 Further modifications to operation of Rules\nSchedule 2 has effect.\n9 Further modifications to operation of Rules commencing on\nSchedule 3 has effect.\n9A Further modifications to operation of Rules commencing on\nSchedule 4 has effect.\nPart 4 Matters prescribed for National Electricity (NT)\nRules\n10 Local event\n(1) For clause 6.6.1(a1)(1AA) of the National Electricity (NT) Rules, a\nlocal event is either of the following:\n(a) the failure of a retailer during a regulatory control period, to\npay a Distribution Network Service Provider an amount to\nwhich the provider is entitled for the provision of direct control\nservices, if:\n(i) an insolvency official has been appointed in respect of\nthat retailer; and\n(ii) the provider is not entitled to payment of that amount in\nfull under the terms of any local support in respect of that\nretailer;\n\nRegulations 2016 5\n(b) a circumstance in which the Power and Water Corporation is\nrequired to pay any amount under a cost recovery scheme\ndetermined by the Utilities Commission under section 44G of\nthe Electricity Reform Act 2000.\n(2) In this regulation:\n2014 NT Network Price Determination, see the National\nElectricity (NT) Rules, Chapter 10.\nlocal support means credit support as defined in the 2014 NT\nNetwork Price Determination, Part B, Schedule 1, clause 1.1.\n(3) An expression used in subregulation (1) that is italicised has the\nsame meaning as it has in the National Electricity (NT) Rules.\n","sortOrder":10},{"sectionNumber":"11","sectionType":"section","heading":"Expiry of certain provisions","content":"11 Expiry of certain provisions\n(1) Schedule 2, clauses 64, 65, 71, 76 and 100 expire on 1 July 2019.\n(2) The following expire on 1 July 2024:\n(a) regulations 6A, 7 and 10A;\n(b) Schedule 1, clause 3;\n(c) Schedule 2, clauses 46, 48, 58, 59, 66, 67, 73 and 101.\n(3) Schedule 2, clauses 77, 78, 80, 82 and 102 expire on 1 July 2029.\n(4) The following expire when the National Energy Retail Law is\napplied as a law of this jurisdiction:\n(a) regulations 6 and 10;\n(b) Schedule 2, clauses 57 and 103.\n(5) Regulations 2A and 4 expire on the later of the following:\n(a) the day on which the National Energy Retail Law is applied as\na law of this jurisdiction;\n(b) 1 July 2024.\n(6) This Part expires on the later of the following:\n(a) the day on which the National Energy Retail Law is applied as\na law of this jurisdiction;\n\nRegulations 2016 6\n(b) 1 July 2029.\n\nSchedule 1 Modifications to National Electricity Regulations\nRegulations 2016 7\nSchedule 1 Modifications to National Electricity\nregulation 3\n1 Regulations modified\nThis Schedule modifies the regulations mentioned in regulation 3.\n2 Regulation 8 modified\nAfter regulation 8(2)\n(2A) For the purposes of subregulation (1)(d), the reference to \"the\nnational electricity system\" in the national electricity objective stated\nin section 7 of the new National Electricity Law must be regarded as\nincluding a reference to one or more, or all, of the local electricity\nsystems, as the case requires.\n","sortOrder":11},{"sectionNumber":"3A","sectionType":"section","heading":"Schedule 1 modified","content":"3A Schedule 1 modified\nSchedule 1, after \"clause 7.16.2(c)\"\nclause 7A.2(a)\nclause 7A.3.2(a) – (b)\nclause 7A.3.2(d) – (f)\nclause 7A.6.1(a)\nclause 7A.6.1(c)\nclause 7A.6.2 (a)(1) – (11)\nclause 7A.6.2(e) – (f)\nclause 7A.6.5(a)(1) – (2)\nclause 7A.6.6(c)\n\n","sortOrder":12},{"sectionNumber":"Sch 1","sectionType":"schedule","heading":"Modifications to National Electricity Regulations","content":"Schedule 1 Modifications to National Electricity Regulations\nRegulations 2016 8\nclause 7A.6.9(a)\nclause 7A.6.9(d) – (e)\nclause 7A.6.13(c)(1) – (3)\nclause 7A.7.2(b)\nclause 7A.7.2(e)\nclause 7A.7.2(g) – (h)\nclause 7A.7.3(a)\nclause 7A.8.3(a)(3) – (4)\nclause 7A.8.4\nclause 7A.8.9(a) – (c)\nclause 7A.9.3\nclause 7A.13.2(a)\nclause 7A.13.3(a) – (b)\nclause 7A.13.3(d)\nclause 7A.13.4\n4 Schedule 2 modified\nSchedule 2, clause 22, at the end\nHowever, this clause has no effect in this jurisdiction.\n\nRegulations 2016 9\n","sortOrder":13},{"sectionNumber":"Sch 2","sectionType":"schedule","heading":"Further modifications to operation of National","content":"Schedule 2 Further modifications to operation of National\nElectricity Rules\nregulation 8\nRules.\n2 Clauses 1.7.1A and 1.7.1B inserted\nAfter clause 1.7.1\n1.7.1A Inconsistency with National Measurement Act\nIf there is an inconsistency between the Rules and the National\nMeasurement Act, the National Measurement Act prevails to the\nextent of the inconsistency.\n1.7.1B Instruments\n(a) In an instrument made under the Rules:\n(1) a reference to the \"National Electricity Law\", \"Law\" or \"NEL\"\nmust be regarded as a reference to the National Electricity\n(NT) Law; and\n(2) a reference to the \"National Electricity Rules\", \"Rules\" or\n\"NER\" must be regarded as a reference to the National\nElectricity Rules as defined in section 2(1) of the National\nElectricity (NT) Law.\n(b) Paragraph (a) applies despite any provision to the contrary in an\ninstrument.\n\nRegulations 2016 10\n(c) For the purposes of the application in this jurisdiction of an\ninstrument made under the Rules:\n(1) the reference to \"the national electricity system\" in the national\nelectricity objective stated in section 7 of the Law must be\nregarded as a reference to one or more, or all, of the local\nelectricity systems, as the case requires;\n(2) if the context or subject matter indicates or requires, a\nreference in the instrument to:\n(i) \"regulatory control period\" must be regarded as including\na reference to the 2009-14 NT regulatory control period\nand the 2014-19 NT regulatory control period; and\n(ii) \"distribution determination\" must be regarded as\nincluding a reference to the 2009 NT Network Price\nDetermination and the 2014 NT Network Price\nDetermination; and\n(3) the AER must interpret the instrument consistently with the\nobjects of the application Act of this jurisdiction and the\nmodifications made to the National Electricity Law and the\nRules by or under that Act.\n(d) In this clause:\n","sortOrder":14},{"sectionNumber":"2009","sectionType":"section","heading":"NT Network Price Determination means the \"Final","content":"2009 NT Network Price Determination means the \"Final\nDetermination – Networks Pricing: 2009 Regulatory Reset\" made\nby the Utilities Commission under the Utilities Commission Act\n(NT), Electricity Reform Act (NT) and Chapter 6 of the NT Network\nAccess Code that applied from 1 July 2009 to 30 June 2014.\n3 Clause 1.8.1 modified\nClause 1.8.1(b)\nomit\nof Registered Participants maintained by AEMO\nkept by the Utilities Commission under section 37 of the Electricity\nReform Act (NT)\n\nRegulations 2016 11\n3A Rule 1.9A inserted\nAfter rule 1.9\n1.9A NTESMO's costs in connection with these Rules\nNote\nCosts for NTESMO are to be considered as part of the progressive application of\nthe Rules in this jurisdiction.\nWhere, for any provision of these Rules, a corporate entity is both a\nNetwork Service Provider and NTESMO, any costs incurred by that\ncorporate entity in complying with any requirements imposed on\nNTESMO under a provision where this clause applies are not to be\nrecovered by that corporate entity as a Network Service Provider\nunder Chapter 6.\n4 Rule 1.11 modified\nAfter rule 1.11, heading\n5 Chapters 2, 2A, 3 and 4 modified\nAfter Chapters 2, 2A, 3, and 4, headings\nThis Chapter has no effect in this jurisdiction (see regulation 5A of the National\nRegulations). The application of this Chapter will be revisited as part of the\n\nRegulations 2016 12\n6 Clause 5.1.2 modified\n(1) Clause 5.1.2(d), table\nConnection Applicant Process\nA Registered Participant or a person intending to\nbecome a Registered Participant for a generating\nplant connecting to a transmission network or a\nperson who is covered by an exemption from the\nrequirement to hold a licence for operating in the\nelectricity supply industry for a generating plant\nconnecting to a transmission network\nA Registered Participant or a person intending to\nbecome a Registered Participant (or a person\npursuant to clause 5.1A.1(c)) for a load\nconnecting to a transmission network\nA load connecting to a distribution network where\nthe Connection Applicant is a Registered\nParticipant or a person intending to become a\nRegistered Participant (and is not acting as the\nagent of a retail customer)\nA distribution network connecting to another\ndistribution network or to a transmission network\nwhere the Connection Applicant is a Registered\nParticipant, intending to become a Registered\nParticipant or will obtain an exemption from\nregistration\nA Market Network Service Provider or person\nintending to register as one seeking connection to\na distribution network or a transmission network\nAn embedded generating unit connecting to a\ndistribution network where the Connection\nApplicant is a Registered Participant or a person\nintending to become a Registered Participant\nRules 5.3 and 5.3A apply\n(see clause 5.3.1A for the\ninteraction between the\ntwo rules)\nA non-registered embedded generator who\nmakes an election for rule 5.3A to apply instead\nof Chapter 5A or a non-registered embedded\ngenerator above the relevant materiality threshold\nRules 5.3 and 5.3A apply\n(see clause 5.3.1A for the\ninteraction between the\ntwo rules)\n\nRegulations 2016 13\nConnection Applicant Process\nA Generator wishing to alter a connected\ngenerating plant in the circumstances set out in\nclause 5.3.9\nClause 5.3.9 applies\nA Connection Applicant for prescribed\ntransmission services or negotiated transmission\nservices that do not require the establishment or\nmodification of a connection or alteration of a\nconnected generating plant in the circumstances\nset out in clause 5.3.9\nRule 5.3 applies as\nmodified by clause\n5.2A.3(c)\nAn Embedded Generator or Market Network\nService Provider applying for distribution network\nuser access\nRule 5.3 or 5.3A (as\napplicable) and rule\n5.3AA apply\nA load or generating plant connecting to a\ndeclared shared network\nRule 5.3 as modified by\nclause 5.1A.1(d) to (g)\nand rule 5.3B apply\nA load that is above the relevant materiality\nthreshold connecting to a distribution network\nwhere the Connection Applicant is not a\nRegistered Participant and is not intending to\nbecome a Registered Participant (unless it is\nacting as the agent of a retail customer)\nA load that is below the relevant materiality\nthreshold connecting to a distribution network\nwhere the Connection Applicant is not a\nRegistered Participant and is not intending to\nbecome a Registered Participant (unless it is\nacting as the agent of a retail customer)\nA non-registered embedded generator who does\nnot make an election for Rule 5.3A to apply\ninstead of Chapter 5A, other than a non-\nregistered embedded generator above the\nrelevant materiality threshold\n","sortOrder":15},{"sectionNumber":"Part 5A","sectionType":"part","heading":"applies","content":"Chapter 5A applies\nA retail customer (or a retailer on behalf of that\ncustomer) connecting a micro embedded\ngenerator to a distribution network\nChapter 5A applies\n\nRegulations 2016 14\n(2) Clause 5.1.2(f)(1)\n(1) the negotiating principles set out in Chapter 6, rather than\nschedule 5.11, will apply to negotiations between a\nTransmission Network Service Provider and a Connection\nApplicant for negotiated transmission services (as if they were\nnegotiated distribution services);\n(3) Clause 5.1.2(f)(3)\n(3) disputes between a Transmission Network Service Provider\nand a Connection Applicant as to terms and conditions of\naccess for the provision of prescribed transmission services or\nfor the provision of negotiated transmission services will be\ndetermined under Chapter 6, rather than rule 5.5 (as if they\nwere negotiated distribution services).\n","sortOrder":16},{"sectionNumber":"7","sectionType":"section","heading":"Clause 5.1.3 inserted","content":"7 Clause 5.1.3 inserted\nAfter clause 5.1.2\n5.1.3 Definitions\nIn this Chapter:\nnon-registered embedded generator has the same meaning as\nin clause 5A.A.1\nrelevant materiality threshold means a generation or load\ncapacity threshold (for a local electricity system or part of a local\nelectricity system), in MW, specified by a local instrument for the\npurposes of this definition.\nNote\nThe requirements of this Chapter 5 relating to the materiality threshold will take\neffect in this jurisdiction when a threshold is specified by a local instrument.\n\nRegulations 2016 15\n","sortOrder":17},{"sectionNumber":"8","sectionType":"section","heading":"Clause 5.1A.2 modified","content":"8 Clause 5.1A.2 modified\n(1) Clause 5.1A.2(c)\n(c) the technical terms and conditions of connection agreements\nregarding standards of performance must be established in\naccordance with the requirements of jurisdictional electricity\nlegislation, with the objective of ensuring that the power system\noperates securely and reliably and in accordance with any system\nstandard;\nNote\nout in schedules 5.1, 5.2 and 5.3 in the Rules applying in other participating\njurisdictions. The system standards referred to in paragraph (c) are those that\ncorrespond to the system standards in schedule 5.1a in the Rules applying in\nother participating jurisdictions. The application of paragraph (c) will be revisited\n(2) Clause 5.1A.2(e)(2)\nomit\nAEMO\n","sortOrder":18},{"sectionNumber":"9","sectionType":"section","heading":"Clause 5.1A.3 inserted","content":"9 Clause 5.1A.3 inserted\nAfter clause 5.1A.2\n5.1A.3 Dedicated connection asset service providers\n(a) A person must not engage in the activity of owning, controlling or\noperating a dedicated connection asset unless the person is a\nTransmission Network Service Provider, or a person who holds an\nexemption from the requirement to hold a licence under Part 3 of\nthe Electricity Reform Act 2000 (NT) to own or operate that\ndedicated connection asset.\n(b) A person who holds an exemption from the requirement to hold a\nlicence under Part 3 of the Electricity Reform Act 2000 (NT) to own\nor operate a large dedicated connection asset must, in relation to\nthat dedicated connection asset, comply with clause 5.2A(6)(c),\n\nRegulations 2016 16\nclause 5.2A.8 and rule 5.5 as if that person were a Dedicated\nConnection Asset Service Provider.\n(c) A Dedicated Connection Asset Service Provider is:\n(1) only required to comply with a rule that is expressed to apply\nto a Network Service Provider or a Transmission Network\nService Provider in those capacities where the rule expressly\nprovides that it applies to a Dedicated Connection Asset\nService Provider; and\n(2) required to comply with all rules which are expressed to apply\nto a Registered Participant.\n(d) A Transmission Network Service Provider is taken to be a\nDedicated Connection Asset Service Provider only in so far as its\nactivities relate to any of its dedicated connection assets.\n","sortOrder":19},{"sectionNumber":"10","sectionType":"section","heading":"Clause 5.2.1 modified","content":"10 Clause 5.2.1 modified\nClause 5.2.1(b)(4)\nomit\nregions or partly combined regions, intra-regional transmission\nbreak-up\nnetwork elements, or network break-up,\n11 Clause 5.2.2 modified\n(1) Clause 5.2.2(a)\n(a) If requested to do so by a Transmission Network User, Distribution\nNetwork User, NTESMO or the AER, the Utilities Commission (in\nrelation to a dedicated connection asset), a Network Service\nProvider and a Transmission Network User or Distribution Network\nUser (as the case may be) must document the terms of any\nnetwork connection arrangements made prior to 1 July 2019 and\nthe resulting document will then be deemed to be a connection\nagreement for the purposes of the Rules.\nNote\n\nRegulations 2016 17\n(2) Clause 5.2.2(b)(1) and (3)\nomit\n","sortOrder":20},{"sectionNumber":"12","sectionType":"section","heading":"Clause 5.2.3 modified","content":"12 Clause 5.2.3 modified\n(1) After clause 5.2.3, heading\nNote\nParagraphs (a) and (k) of this clause have no effect in this jurisdiction (see\n(2) Clause 5.2.3(b)(1)\nomit\n(3) Clause 5.2.3(b)\nomit\nbetween schedule 5.1\nbetween jurisdictional electricity legislation\n(4) Clause 5.2.3(b)(3)\nomit\nthe jurisdictional electricity legislation\n\nRegulations 2016 18\n(5) After clause 5.2.3(b), note\nNote\nout in schedule 5.1 in the Rules applying in other participating jurisdictions. The\napplication of paragraph (b) will be revisited as part of the phased implementation\n(6) Clause 5.2.3(c)\n(c) Where the provisions of the connection agreement vary the\ntechnical requirements set out in jurisdictional electricity legislation,\nthe relevant Network Service Provider must report on such\nvariations to NTESMO on an annual basis.\nNote\nNote\nout in the schedules to Chapter 5 in the Rules applying in other participating\njurisdictions. The application of paragraph (c) will be revisited as part of the\n(7) Clause 5.2.3(d)(3)\nomit\n(8) Clause 5.2.3(d)(9) and (10)\nAEMO\n\nRegulations 2016 19\n(9) Clause 5.2.3(d)(11)\n(11) provide to NTESMO the information required from Generators\nand Customers to support a connection application under\nthese Rules and jurisdictional electricity legislation; and\n(10) After clause 5.2.3(d)(11), note\nNote\npurposes of paragraph (d)(3) will be requirements that correspond to the matters\nset out in schedule 5.1, in the Rules applying in other participating jurisdictions.\nThe information referred to in paragraph (d)(11) corresponds to the information\nrequired under schedule 5.2 or 5.3 in the Rules applying in other participating\njurisdictions. The application of paragraph (d)(3) and (11) will be revisited as part\nof the phased implementation of the Rules in this jurisdiction.\n(11) Clause 5.2.3(e)\nomit\nAEMO\n(12) Clause 5.2.3(j)\n(j) If in NTESMO's reasonable opinion, there is a risk a Network\nService Provider's plant or equipment will:\n(2) adversely affect the use of a network by a Network User,\n\nRegulations 2016 20\nNTESMO may request the Network Service Provider to provide\ninformation relating to the protection systems and the control\nsystems of the equipment, and following such a request, the\nNetwork Service Provider must provide the information to NTESMO\nand any other relevant Network Service Provider(s).\nNote\nNote\nThe application of paragraph (j) will be revisited as part of the phased\n(13) Clause 5.2.3(l)\n(l) All information provided to NTESMO and the relevant Network\nService Provider(s) under paragraph (j) must be treated as\n","sortOrder":21},{"sectionNumber":"13","sectionType":"section","heading":"Clause 5.2.4 modified","content":"13 Clause 5.2.4 modified\n(1) After clause 5.2.4, heading\nNote\nParagraph (d) of this clause has no effect in this jurisdiction (see regulation 5A of\n(2) Clause 5.2.4(b)(2)\nomit\nschedule 5.3\nany relevant technical requirements in jurisdictional electricity\n\nRegulations 2016 21\n(3) After clause 5.2.4(b)\nNote\npurposes of paragraph (b)(2) will be requirements that correspond to the matters\nset out in schedule 5.3 in the Rules applying in other participating jurisdictions.\nThe application of paragraph (b)(2) will be revisited as part of the phased\n(4) Clause 5.2.4(c)\n(c) If in NTESMO's reasonable opinion, there is a risk that a\nCustomer's plant will:\n(2) adversely affect the use of a network by a Network User,\nNTESMO may request a Customer to provide information relating\nto the protection systems and control systems of the equipment,\nand following such a request, the Customer must provide the\ninformation to NTESMO and the relevant Network Service\nProvider(s).\nNote\nNote\nThe application of paragraph (c) will be revisited as part of the phased\n(5) Clause 5.2.4(e)\n(e) All information provided to NTESMO and the relevant Network\nService Provider(s) under paragraph (c) must be treated as\n\nRegulations 2016 22\n","sortOrder":22},{"sectionNumber":"14","sectionType":"section","heading":"Clause 5.2.5 modified","content":"14 Clause 5.2.5 modified\n(1) After clause 5.2.5, heading\nNote\nParagraphs (c) and (e) of this clause have no effect in this jurisdiction (see\n(2) Clause 5.2.5(b)(2)\nomit\n","sortOrder":23},{"sectionNumber":"Sch 5","sectionType":"schedule","heading":"2","content":"Schedule 5.2\nany relevant technical requirements in jurisdictional electricity\n(3) After clause 5.2.5(b)\nNote\npurposes of paragraph (b)(2) will be requirements that correspond to the matters\nset out in schedule 5.3 in the Rules applying in other participating jurisdictions.\nThe application of paragraph (b)(2) will be revisited as part of the phased\n(4) Clause 5.2.5(d)\n(d) If in NTESMO's reasonable opinion, there is a risk that a\nGenerator's plant will:\n(2) adversely affect the use of a network by a Network User\n\nRegulations 2016 23\nNTESMO may request a Generator to provide information relating\nto the protection systems and the control systems of the equipment,\nand following such a request, the Generator must provide the\ninformation to NTESMO and the relevant Network Service\nProvider(s).\nNote\nNote\nThe application of paragraph (d) will be revisited as part of the phased\n(5) Clause 5.2.5(f)\n(f) All information provided to NTESMO and the relevant Network\nService Provider(s) under paragraph (d) must be treated as\n","sortOrder":24},{"sectionNumber":"15","sectionType":"section","heading":"Clause 5.2.7 modified","content":"15 Clause 5.2.7 modified\n(1) Clause 5.2.7(a)\nomit\nChapter 2\n(2) After clause 5.2.7(a)\nNote\nThe jurisdiction electricity legislation that is relevant to the classification of a\ndedicated connection asset is the Electricity Reform Act 2000 (NT) and the\nNational Electricity (Northern Territory) (National Uniform Legislation) Act 2015.\n","sortOrder":25},{"sectionNumber":"16","sectionType":"section","heading":"Clause 5.2A.2 modified","content":"16 Clause 5.2A.2 modified\n(1) Clause 5.2A.2(a)\nomit\nregistered\n\nRegulations 2016 24\nresponsible\n(2) Clause 5.2A.2(a), table heading\nomit\nRegistered\nResponsible\n(3) Clause 5.2A.2(b)\n(b) The intention of this rule 5.2A is that there is a responsible person\nfor each asset connecting the transmission network to the facilities\nof the Transmission Network User.\n17 Clause 5.2A.3 modified\n(1) Clause 5.2A.3(a), table\nChapter 6A\nChapter 6\n(2) Clause 5.2A.3(a), table, second row, after \"Chapter 5\"\nand economic regulation under Chapter 6\n(3) Clause 5.2A.3(c)\nomit\nrules 5.3, 5.4 and 5.5 will apply with such modifications as is\nappropriate to the nature of the service requested\nrules 5.3 and 5.4 will apply with such modifications as is appropriate\nto the nature of the service requested, together with (if required) the\n\nRegulations 2016 25\nprovisions of Chapter 6 in relation to any dispute as to terms and\nconditions of access (as if the prescribed transmission service or\nthe negotiated transmission service were a negotiated distribution\nservice)\n","sortOrder":26},{"sectionNumber":"18","sectionType":"section","heading":"Clause 5.2A.6 modified","content":"18 Clause 5.2A.6 modified\nClause 5.2A.6(a)\nomit\nthe negotiating principles\n","sortOrder":27},{"sectionNumber":"Part 6","sectionType":"part","heading":null,"content":"Chapter 6\n","sortOrder":28},{"sectionNumber":"19","sectionType":"section","heading":"Clause 5.2A.8 modified","content":"19 Clause 5.2A.8 modified\n(1) Clause 5.2A.8(d)\nomit\nChapter 2\nin accordance with jurisdictional electricity legislation\n(2) After clause 5.2A.8(d), note\nNote\nThe jurisdiction electricity legislation that is relevant to the classification of a\ndedicated connection asset is the Electricity Reform Act 2000 (NT) and the\nNational Electricity (Northern Territory) (National Uniform Legislation) Act 2015.\n","sortOrder":29},{"sectionNumber":"20","sectionType":"section","heading":"Clause 5.3.1 modified","content":"20 Clause 5.3.1 modified\n(1) Clause 5.3.1(b)\n(b) The following persons wishing to establish a connection to a\nnetwork must follow the procedures in this rule 5.3:\n(1) a Registered Participant;\n(2) a person intending to become a Registered Participant;\n\nRegulations 2016 26\n(3) a person who is covered by an exemption from the\nrequirement to hold a licence for operating in the electricity\nsupply industry for a generating plant connecting to a\ntransmission network or a load connecting to a transmission\nnetwork;\n(4) a person seeking to establish a connection to a distribution\nnetwork for a load above the relevant materiality threshold.\n(2) Clause 5.3.1(d)\nomit\nAEMO\n","sortOrder":30},{"sectionNumber":"21","sectionType":"section","heading":"Clause 5.3.1A modified","content":"21 Clause 5.3.1A modified\n(1) Clause 5.3.1A(a)\nomit\n(2) Clause 5.3.1A(c)(2)\n(2) person who is required to apply to the Utilities Commission for\nan exemption from the requirement to hold a licence for\noperating in the electricity supply industry as a Generator in\nrespect of an embedded generating unit;\n(3) Clause 5.3.1A(c)(3)\nomit\n(c).\n(c); or\n(4) After clause 5.3.1A(3)\n(4) non-registered embedded generator above the relevant\nmateriality threshold for the relevant local electricity system, or\npart of a local electricity system,\n\nRegulations 2016 27\n","sortOrder":31},{"sectionNumber":"22","sectionType":"section","heading":"Clause 5.3.2 modified","content":"22 Clause 5.3.2 modified\n(1) Clause 5.3.2(f)\nomit\nschedule 5.1, 5.2, 5.3 or 5.3a\n(2) After clause 5.3.2(f), note\nNote\npurposes of paragraph (f) will be requirements that correspond to the matters set\nout in schedules 5.1, 5.2, and 5.3 in the Rules applying in other participating\njurisdictions. The application of paragraph (f) will be revisited as part of the\n","sortOrder":32},{"sectionNumber":"23","sectionType":"section","heading":"Clause 5.3.3 modified","content":"23 Clause 5.3.3 modified\n(1) After clause 5.3.3, heading\nNote\nParagraphs (b2), (b3) and (b4) of this clause have no effect in this jurisdiction\nUniform Legislation) (Modification) Regulations 2016). The application of these\n(2) Clause 5.3.3(b1)(3), (4), (5) and (6)\n(3) the access arrangements specified in the jurisdictional\n(3) Clause 5.3.3(b5)\n(b5) For a connection point for a proposed new connection of a\ngenerating system or market network service facility, within the time\napplicable under paragraph (b1), the Network Service Provider\nmust provide the Connection Applicant with written details of the\nminimum three phase fault level at the connection point.\n\nRegulations 2016 28\n(4) Clause 5.3.3(c)(3)\nomit\nschedule 5.5\n(5) Clause 5.3.3(c)(4)\nomit\nrules 6.21 and 6A.28\nrule 6.21\n(6) Clause 5.3.3(c)(5)(i)\nomit\nAEMO and\n(7) After clause 5.3.3(c), note\nNote\nThe type of information that will apply under jurisdictional electricity legislation for\nthe purposes of paragraph (c)(3) will correspond to the type of information set out\nin schedule 5.5 in the Rules applying in other participating jurisdictions. The\napplication of paragraph (c)(3) will be revisited as part of the phased\n","sortOrder":33},{"sectionNumber":"24","sectionType":"section","heading":"Clause 5.3.4 modified","content":"24 Clause 5.3.4 modified\n(1) After clause 5.3.4, heading\nNote\nParagraphs (e) and (g) of this clause have no effect in this jurisdiction (see\n\nRegulations 2016 29\n(2) Clause 5.3.4(b1)(d)\n","sortOrder":34},{"sectionNumber":"25","sectionType":"section","heading":"Clause 5.3.4A modified","content":"25 Clause 5.3.4A modified\nAfter clause 5.3.4A, heading\nNote\nClause 5.3.4A has no effect in this jurisdiction (see regulation 5A of the National\n","sortOrder":35},{"sectionNumber":"25A","sectionType":"section","heading":"Clause 5.3.4B modified","content":"25A Clause 5.3.4B modified\nAfter clause 5.3.4B, heading\nNote\nClause 5.3.4B has no effect in this jurisdiction (see regulation 5A of the National\n","sortOrder":36},{"sectionNumber":"25B","sectionType":"section","heading":"Clause 5.3.5 modified","content":"25B Clause 5.3.5 modified\n(1) After clause 5.3.5, heading\nNote\nParagraph (e) of this clause has no effect in this jurisdiction (see regulation 5A of\n(2) Clause 5.3.5(a)\n(a) The Network Service Provider to whom the application to connect is\nsubmitted must proceed to prepare an offer to connect in response\nin accordance with technical standards set out in jurisdictional\n\nRegulations 2016 30\n(3) Clause 5.3.5(d) and (g)\nAEMO\n","sortOrder":37},{"sectionNumber":"25C","sectionType":"section","heading":"Clause 5.3.6 modified","content":"25C Clause 5.3.6 modified\n(1) After clause 5.3.6, heading\nNote\nParagraph (a2)(3) of this clause has no effect in this jurisdiction (see\nLegislation) (Modification) Regulations 2016). The application of paragraphs (a1)\nand (a2)(3) will be revisited as part of the phased implementation of the Rules in\n(2) Clause 5.3.6(a1)\n(a1) The Network Service Provider may amend the time period referred\nto in paragraph (a)(1) to allow for any additional time taken in\nexcess of the period allowed in the preliminary program for the\nnegotiation of access standards, where allowed under jurisdictional\n(3) Clause 5.3.6(b)(1)\n(1) each technical requirement identified by the Network Service\nProvider under clause 5.3.3(b1); and\n(4) Clause 5.3.6(b1)\nomit\nthe applicable minimum access standards\nallowed under jurisdictional electricity legislation\n\nRegulations 2016 31\n(5) Clause 5.3.6(b2)(3)\nomit\nthe automatic access standard or the negotiated access standard\nas determined in accordance with clause 5.3.4A\nthe access standards determined in accordance with jurisdictional\n(6) Clause 5.3.6(c)\n(c) The offer to connect must be fair and reasonable and must be\nconsistent with the safe and reliable operation of the power system\nin accordance with the Rules and any relevant jurisdictional\nelectricity legislation. Without limitation, unless the parties otherwise\nagree, to be fair and reasonable an offer to connect must offer\nconnection and network services consistent with any relevant\njurisdictional electricity legislation and must not impose conditions\non the Connection Applicant which are more onerous than those\ncontemplated in relevant jurisdictional electricity legislation.\nNote\nNote\nout in schedules 5.1, 5.2 and 5.3 in the Rules applying in other participating\njurisdictions. The application of paragraph (c) will be revisited as part of the\n(7) Clause 5.3.6(g)\n(g) An offer to connect must define the basis for determining the\ntransmission service charges in accordance with Chapter 6,\nincluding the prudential requirements set out in that Chapter, as if\nthe transmission service charges were distribution service charges.\n\nRegulations 2016 32\n","sortOrder":38},{"sectionNumber":"25D","sectionType":"section","heading":"Clause 5.3.7 modified","content":"25D Clause 5.3.7 modified\n(1) After clause 5.3.7, heading\nNote\nParagraphs (c) and (g)(2)(i), (5) and (6) of this clause have no effect in this\n(2) Clause 5.3.7(b)\nomit\nschedules 5.2, 5.3 and 5.3a\naccordance with jurisdictional electricity legislation\n(3) After clause 5.3.7(b)\nNote\nout in schedules 5.2 and 5.3 in the Rules applying in other participating\njurisdictions. The application of paragraph (b) will be revisited as part of the\n(4) Clause 5.3.7(d)\nomit\nor any system strength connection works\n(5) Clause 5.3.7(g) and (h)\nAEMO\n\nRegulations 2016 33\n(6) Clause 5.3.7(h)\nomit\nschedule 7.4\nschedule 7A.4\n","sortOrder":39},{"sectionNumber":"25E","sectionType":"section","heading":"Clause 5.3.8 modified","content":"25E Clause 5.3.8 modified\n(1) After clause 5.3.8, heading\nNote\nParagraph (b)(1) and (2)(iv) of this clause has no effect in this jurisdiction (see\n(2) Clause 5.3.8(b) and (f)\nAEMO\n(3) Clause 5.3.8(b)(2)(iii)\nomit\nor system strength connection works\n","sortOrder":40},{"sectionNumber":"25F","sectionType":"section","heading":"Clause 5.3.9 modified","content":"25F Clause 5.3.9 modified\n(1) After clause 5.3.9, heading\nNote\nParagraphs (a)(2), (b)(4), (c), (c1) and (f) of this clause have no effect in this\n\nRegulations 2016 34\n(2) Clause 5.3.9(a)\n(a) This clause 5.3.9 applies where a Generator proposes to alter a\nconnected generating system or a generating system where that\nalteration would affect performance standards in an existing\nconnection agreement and that alteration:\n(1) will affect the performance of the generating system relative to\nany of the technical requirements set out in jurisdictional\nelectricity legislation within the constraints allowed under\njurisdictional electricity legislation; or\n(2) will, in AEMO's reasonable opinion, have an adverse system\nstrength impact; or\n(3) will, in NTESMO's reasonable opinion, adversely affect\nnetwork capability, power system security, quality or reliability\nof supply, inter-regional power transfer capability or the use of\na network by another Network User.\nNote\npurposes of paragraph (a)(1) will be requirements that correspond to the matters\nset out in clauses S5.2.5 to 5.2.8 in the Rules applying in other participating\njurisdictions. The application of paragraph (a)(1) will be revisited as part of the\n(3) Clause 5.3.9(b)\nomit\nAEMO\n(4) Clause 5.3.9(b)(2)\nomit\nin accordance with the Power System Model Guidelines, Power\nSystem Design Data Sheet and Power Setting Data Sheet\n\nRegulations 2016 35\n(5) Clause 5.3.9(d)\n(d) Without limiting paragraph (a), a proposed alteration to the following\nequipment is deemed to affect the performance of the generating\nsystem relative to technical requirements, thereby necessitating a\nsubmission under subparagraph (b)(3), unless NTESMO and the\nNetwork Service Provider otherwise agree:\n(1) machinery windings;\n(2) power converter;\n(3) reactive compensation plant;\n(4) excitation control system;\n(5) voltage control system;\n(6) governor control system;\n(7) power control system;\n(8) protection system;\n(9) auxiliary supplies;\n(10) remote control and monitoring system.\n(6) Clause 5.3.9(e)\nomit\nother Network Service Providers and AEMO\nand other Network Service Providers\n(7) Clause 5.3.9(g) and (h)\nAEMO\n\nRegulations 2016 36\n","sortOrder":41},{"sectionNumber":"25G","sectionType":"section","heading":"Clause 5.3.10 modified","content":"25G Clause 5.3.10 modified\n(1) After clause 5.3.10, heading\nNote\nParagraphs (b)(3) and (c) of this clause have no effect in this jurisdiction (see\n(2) Clause 5.3.10(a) and (b)\n(a) A person to whom clause 5.3.9 applies must not commission\naltered generating plant until the Network Service Provider has\nadvised the Generator that it is satisfied in accordance with\nparagraph (b).\nNote\n(b) In relation to altered generating plant, the Network Service Provider\nmust be satisfied that:\n(1) the relevant person has complied with clause 5.3.9;\n(2) each amended performance standard that has been submitted\nto the Network Service Provider meets the relevant technical\nrequirements under jurisdictional electricity legislation; and\n(3) any system strength remediation scheme satisfies\nclause 5.3.4B.\n(3) Clause 5.3.10(c)\nomit\nAEMO\n\nRegulations 2016 37\n","sortOrder":42},{"sectionNumber":"25H","sectionType":"section","heading":"Clause 5.3.11 modified","content":"25H Clause 5.3.11 modified\n(1) Clause 5.3.11(a) and (b)\nAEMO\n(2) After clause 5.3.11(a)\n(a1) A request from a Network Service Provider to change normal\nvoltage must be assessed in accordance with the Rules\nconsultation procedures.\n(3) After clause 5.3.11(b)\nNote\nNTESMO's reasonable costs in assessing requests under this clause will be\n","sortOrder":43},{"sectionNumber":"25I","sectionType":"section","heading":"Clause 5.3A.1 modified","content":"25I Clause 5.3A.1 modified\n(1) Clause 5.3A.1(c)(1)(ii)\n(ii) person who is required to apply to the Utilities\nCommission for an exemption from the requirement to\nhold a licence for operating in the electricity industry as a\nGenerator in respect of an embedded generating unit;\n(2) Clause 5.3A.1(c)(1)(iii)\nomit\nclause 5A.A.2(c),\nclause 5A.A.2(c); or\n\nRegulations 2016 38\n(3) After clause 5.3A.1(c)(1)(iii)\n(iv) non-registered embedded generator above the relevant\nmateriality threshold for the local electricity system (or\npart of the local electricity system),\n","sortOrder":44},{"sectionNumber":"25J","sectionType":"section","heading":"Clause 5.3A.3 modified","content":"25J Clause 5.3A.3 modified\n(1) After clause 5.3A.3, heading\nNote\nParagraph (b)(5) and (6)(xi) of this clause has no effect in this jurisdiction (see\n(2) Clause 5.3A.3(b)(1)(vi)\n(vi) the process for negotiating any access standards, where\nallowed under jurisdictional electricity legislation and a\nsummary of the factors the Distribution Network Service\nProvider takes into account when considering proposed\nchanges to access standards; and\n(3) Clause 5.3A.3(b)(6)(x)\nomit\nrequirements; and\n(4) After clause 5.3A.3(b)(6)(xi)\n(xii) other technical matters relevant to any access standard\nunder jurisdictional electricity legislation; and\n\nRegulations 2016 39\n","sortOrder":45},{"sectionNumber":"25K","sectionType":"section","heading":"Clause 5.3A.4 modified","content":"25K Clause 5.3A.4 modified\nAfter clause 5.3A.4, heading\nNote\nParagraph (e)(2)(ii) of this clause has no effect in this jurisdiction (see\nLegislation) (Modification) Regulations 2016). The application of this paragraph\n","sortOrder":46},{"sectionNumber":"25L","sectionType":"section","heading":"Clause 5.3A.8 modified","content":"25L Clause 5.3A.8 modified\nAfter clause 5.3A.8, heading\nNote\nParagraph (h) of this clause has no effect in this jurisdiction (see regulation 5A of\n","sortOrder":47},{"sectionNumber":"25M","sectionType":"section","heading":"Clause 5.3A.9 modified","content":"25M Clause 5.3A.9 modified\n(1) After clause 5.3A.9, heading\nNote\nParagraphs (e), (f) and (h) of this clause have no effect in this jurisdiction (see\n(2) Clause 5.3A.9(a)\nomit\nclause 5.3.4A and clause 5.3.4B\nand clause 5.3.4A\n\nRegulations 2016 40\n","sortOrder":48},{"sectionNumber":"25N","sectionType":"section","heading":"Clause 5.3A.10 modified","content":"25N Clause 5.3A.10 modified\n(1) After clause 5.3A.10, heading\nNote\nParagraph (f) of this clause has no effect in this jurisdiction (see regulation 5A of\n(2) Clause 5.3A.10(a)\n(a) The Distribution Network Service Provider to whom the application\nto connect is submitted under clause 5.3A.9(a) in accordance with\nthe technical requirements set out under jurisdictional electricity\nlegislation must proceed to prepare an offer to connect in response.\n(3) Clause 5.3A.10(b) and (e)\nAEMO\n","sortOrder":49},{"sectionNumber":"25O","sectionType":"section","heading":"Clause 5.3A.12 modified","content":"25O Clause 5.3A.12 modified\nAfter clause 5.3A.12, heading\nNote\nThis clause 5.3A.12 has no effect in this jurisdiction (see regulation 5A of the\n(Modification) Regulations 2016). The application of this clause will be revisited\n\nRegulations 2016 41\n","sortOrder":50},{"sectionNumber":"25P","sectionType":"section","heading":"Rule 5.3AA modified","content":"25P Rule 5.3AA modified\n(1) After rule 5.3AA, heading\nNote\nParagraphs (h), (i) and, (j) of this rule have no effect in this jurisdiction (see\n(2) Rule 5.3AA(f)(4)(ii)(B)\nomit\nduring a trading interval\n","sortOrder":51},{"sectionNumber":"25Q","sectionType":"section","heading":"Clause 5.4.3 modified","content":"25Q Clause 5.4.3 modified\nAfter clause 5.4.3, heading\nNote\nParagraph (c) of this clause has no effect in this jurisdiction (see regulation 5A of\n","sortOrder":52},{"sectionNumber":"25R","sectionType":"section","heading":"Clause 5.4.5 modified","content":"25R Clause 5.4.5 modified\nAfter clause 5.4.5, heading\nNote\nParagraph (e)(4) of this clause has no effect in this jurisdiction (see regulation 5A\n","sortOrder":53},{"sectionNumber":"25S","sectionType":"section","heading":"Clause 5.5.1 modified","content":"25S Clause 5.5.1 modified\nClause 5.5.1(c)\n(b1) Despite paragraph (b), for this jurisdiction, this rule 5.5 only applies\nto any dispute which may arise between a Dedicated Connection\nAsset Service Provider for a large dedicated connection asset (a\n\nRegulations 2016 42\nprovider) and a person seeking large DCA services (an applicant)\nas to terms and conditions of access, for the provision of large DCA\nservices (a large DCA services access dispute).\n(c) For the purposes of large DCA services, the terms and conditions\nof access are the price of, and the other terms and conditions for,\nthe provision of those large DCA services, as determined under the\naccess policy.\n","sortOrder":54},{"sectionNumber":"25T","sectionType":"section","heading":"Clause 5.6.1 modified","content":"25T Clause 5.6.1 modified\n(1) Clause 5.6.1(a)\nomit\nTasmania; and\nTasmania and the Northern Territory;\n(2) Clause 5.6.1(b)\nomit\nTasmania.\nTasmania; and\n(3) After clause 5.6.1(b)\n(c) 1 July 2019 in the case of installations located in the Northern\nTerritory.\n","sortOrder":55},{"sectionNumber":"25U","sectionType":"section","heading":"Clause 5.6.2 modified","content":"25U Clause 5.6.2 modified\nClause 5.6.2(a)(1)\nomit\nAEMO\n\nRegulations 2016 43\n","sortOrder":56},{"sectionNumber":"25V","sectionType":"section","heading":"Clause 5.7.1 modified","content":"25V Clause 5.7.1 modified\n(1) Clause 5.7.1(d)\n(d) Neither a Registered Participant nor NTESMO may carry out an\ninspection under this rule 5.7 within 6 months of any previous\ninspection except for the purpose of verifying the performance of\ncorrective action claimed to have been carried out in respect of a\nnon-conformance observed and documented on the previous\ninspection or (in the case of NTESMO) for the purpose of reviewing\nan operating incident in accordance with any requirements under\nNote\npurposes of paragraph (d) will be requirements that correspond to the matters set\nout in clause 4.8.15 in the Rules applying in other participating jurisdictions. The\napplication of paragraph (d) will be revisited as part of the phased implementation\n(2) Clause 5.7.1(h)\n(h) NTESMO or any of its representatives may, in accordance with this\nrule 5.7, inspect a facility of a Registered Participant and the\noperation and maintenance of that facility in order to:\n(1) assess compliance by the relevant Registered Participant with\nits operational obligations under jurisdictional electricity\nlegislation;\n(2) investigate any possible past or potential threat to power\nsystem security; or\n(3) conduct any periodic familiarisation or training associated with\nthe operational requirements of the facility.\nNote\nThe operational obligations that will apply under jurisdictional electricity\nlegislation for the purposes of paragraph (h)(1) will be operational obligations that\ncorrespond to those in Chapters 3 and 4 of the Rules applying in other\nparticipating jurisdictions. The application of paragraph (h)(1) be revisited as part\nof the phased implementation of the Rules in this jurisdiction.\n\nRegulations 2016 44\n(3) Clause 5.7.1(l)\nAEMO\n","sortOrder":57},{"sectionNumber":"25W","sectionType":"section","heading":"Clause 5.7.2 modified","content":"25W Clause 5.7.2 modified\n(1) Clause 5.7.2(b) and (i)\nAEMO\n(2) Clause 5.7.2(g)\nomit\nA Transmission Provider must give AEMO\nA Network Service Provider must give NTESMO\n","sortOrder":58},{"sectionNumber":"25X","sectionType":"section","heading":"Clause 5.7.3 modified","content":"25X Clause 5.7.3 modified\n(1) After clause 5.7.3, heading\nNote\nThe application of paragraphs (a)(1), (c), (d) and (f)(1) of this clause will be\n\nRegulations 2016 45\n(2) Clause 5.7.3(a)\n(a) Each Generator must, in accordance with the time frames specified\nby NTESMO, provide evidence to any relevant Network Service\nProvider with which that Generator has a connection agreement\nand to NTESMO, that its generating system complies with:\n(1) the applicable technical requirements under jurisdictional\n(2) the relevant connection agreement including the performance\nstandards.\nNote\nNote\npurposes of paragraph (a)(1) will be requirements that correspond to the matters\nset out in clause S5.2.5 as applying in other participating jurisdictions.\n(3) Clause 5.7.3(c)\nomit\nof clause S5.2.5\n(4) Clause 5.7.3(c)(1) and (2)\nAEMO\n\nRegulations 2016 46\n(5) After clause 5.7.3(c), note\nNote\nout in clause S5.2.5 as applying in other participating jurisdictions.\n(6) Clause 5.7.3(d), (e) and (g)\nAEMO\n(7) Clause 5.7.3(d)\nomit\nof clause S5.2.5\n(8) After clause 5.7.3(d), note\nNote\npurposes of paragraph (d) will be requirements that correspond to the matters set\nout in clause S5.2.5 as applying in other participating jurisdictions.\n(9) Clause 5.7.3(f)\n(f) If NTESMO:\n(1) is satisfied that a generating system is not complying with the\nrelevant performance standards for that system in respect of\none or more of the technical requirements set out in\njurisdictional electricity legislation and the relevant connection\nagreement; and\n\nRegulations 2016 47\n(2) holds the reasonable opinion that the performance of the\ngenerating system is or will impede NTESMO's ability to carry\nout its role in relation to power system security,\nNTESMO may direct the relevant Generator to operate the\ngenerating system at a particular generated output or in a particular\nmode until the relevant Generator submits evidence reasonably\nsatisfactory to NTESMO that the generating system is complying\nwith the relevant performance standard.\nNote\npurposes of paragraph (f)(1) will be requirements that correspond to the matters\nset out in clause S5.2.4, S5.2.5, S5.2.6, S5.2.7 or S5.2.8 as applying in other\nparticipating jurisdictions.\n","sortOrder":59},{"sectionNumber":"25Y","sectionType":"section","heading":"Clause 5.7.3A modified","content":"25Y Clause 5.7.3A modified\nAfter clause 5.7.3A, heading\nNote\nThis clause has no effect in this jurisdiction (see regulation 5A of the National\n","sortOrder":60},{"sectionNumber":"25Z","sectionType":"section","heading":"Clause 5.7.4 modified","content":"25Z Clause 5.7.4 modified\n(1) After clause 5.7.4, heading\nNote\nThe application of paragraphs (a1) and (a2)(3) of this clause will be revisited as\npart of the phased implementation of the Rules in this jurisdiction.\n(2) Clause 5.7.4(a1)\nomit\ntheir performance requirements under schedule 5.1\nany performance requirements under jurisdictional electricity\n\nRegulations 2016 48\n(3) After clause 5.7.4(a1), note\nNote\npurposes of paragraph (a1) will be requirements that correspond to the matters\nset out in Schedule 5.1 as applying in other participating jurisdictions.\n(4) Clause 5.7.4(a2)(3)\nomit\nof schedule 5.3\n(5) After clause 5.7.4(a2)\nNote\npurposes of paragraph (a2)(3) will be requirements that correspond to the\nmatters set out in Schedule 5.1 as applying in other participating jurisdictions.\n(6) Clause 5.7.4(a3)\nomit\nAEMO\n25ZA Clause 5.7.5 modified\n(1) After clause 5.7.5, heading\nNote\nParagraph (a)(2) of this clause has no effect in this jurisdiction (see regulation 5A\n\nRegulations 2016 49\n(2) Clause 5.7.5(d) and (e)\n(3) Clause 5.7.5(e), (f), (g), (h) and (i)\nAEMO\n25ZB Clause 5.7.6 modified\n(1) After clause 5.7.6, heading\nNote\nThe application of this clause will be revisited as part of the phased\n(2) Clause 5.7.6(a)\nomit\nto determine analytic parameters for modelling purposes or\n(3) Clause 5.7.6(b)\n(b) If NTESMO reasonably considers that available information,\nincluding results from a previous test of a generating unit or\ngenerating system, are inadequate, NTESMO may direct a Network\nService Provider to require a Generator to conduct a test under\nparagraph (a), and NTESMO may witness such a test.\n(4) Clause 5.7.6(d), after \"that are due to take place,\"\nas instructed or approved by NTESMO,\n\nRegulations 2016 50\n(5) Clause 5.7.6(f1)\nomit\n, including model source code provided to AEMO under\nclause S5.2.4(b)(6)\n(6) Clause 5.7.6(h)\n(h) A Generator must provide the test records obtained from a test\nunder paragraph (a) to the Network Service Provider.\n(7) Clause 5.7.6(i)\nomit\nomit\nAEMO\n25ZC Clause 5.8.2 modified\nClause 5.8.2\nomit\nAEMO\n25ZD Clause 5.8.3 modified\n(1) After clause 5.8.3, heading\nNote\nThe application of this clause will be revisited as part of the phased\n\nRegulations 2016 51\n(2) Clause 5.8.3(b)(1) and (2) and (d)\nAEMO\n25ZE Clause 5.8.4 modified\nClause 5.8.4(a), (c), (d) and (e)\nAEMO\n25ZF Clause 5.8.5 modified\nClause 5.8.5(a) and (e)\nAEMO\n25ZG Clause 5.9.2 modified\nClause 5.9.2(b)\nomit\nAEMO\n\nRegulations 2016 52\n25ZH Clause 5.9.3 modified\n(1) Clause 5.9.3(a) and (c)\nAEMO\n(2) Clause 5.9.3(b)\n(b) In all cases of disconnection by a Network Service Provider at\nNTESMO's direction during an emergency in accordance with\nclause 5.9.5, NTESMO must undertake a review under any relevant\njurisdictional electricity legislation and NTESMO must then provide\na report to the Registered Participant, the AEMC and the AER\nadvising of the circumstances requiring such action.\nNote\nout in clause 4.8.15 in the Rules applying in other participating jurisdictions. The\napplication of paragraph (b) will be revisited as part of the phased implementation\n(3) Clause 5.9.3(d)\n(d) A Registered Participant's facilities or market load may be\ndisconnected from the network under an emergency frequency\ncontrol arrangement if this is permitted under jurisdictional\n25ZI Clause 5.9.4 modified\nClause 5.9.4(a), (b) and (d)\nAEMO\n\nRegulations 2016 53\n25ZJ Clause 5.9.4A modified\nClause 5.9.4A\nomit\nAEMO\n25ZK Clause 5.9.5 modified\n(1) Clause 5.9.5(a) and (b)\nAEMO\n(2) Clause 5.9.5(a)(2)\nomit\n25ZL Clause 5.9.6 modified\n(1) Clause 5.9.6(a) and (c)\nAEMO\n\nRegulations 2016 54\n(2) Clause 5.9.6(a)(4)\n(4) NTESMO determines that the requirements under\njurisdictional electricity legislation for reconnection following\ndisconnection under an emergency frequency control\narrangement are satisfied.\n(3) Clause 5.9.6(b)\n(b) In carrying out its obligations under clause 5.9.6(a), NTESMO must,\nto the extent practicable, arrange for the implementation of an\nequitable sharing of the reconnection of facilities across the\nrelevant local electricity system up to the power transfer capability\nof the network and, in performing these obligations, both NTESMO\nand the relevant Network Service Provider must, to the extent\npracticable, give priority to reconnection of sensitive loads.\n25ZM Clause 5.10.1 modified\nClause 5.10.1(j2), note\nomit\n25ZN Clause 5.10.2 modified\nClause 5.10.2, definition reliability corrective action\nreliability corrective action means investment by a Transmission\nNetwork Service Provider or a Distribution Network Service\nProvider in respect of its transmission network or distribution\nnetwork for the purpose of meeting the service standards linked to\nthe technical requirements of jurisdictional electricity legislation or in\napplicable regulatory instruments and which may consist of network\noptions or non-network options.\nNote\nIn the definition of reliability corrective action, the reference to the technical\nrequirements of jurisdictional electricity legislation will be requirements that\ncorrespond to the matters set out in Schedule 5.1 in the Rules applying in other\nparticipating jurisdictions. This definition will be revisited as part of the phased\n\nRegulations 2016 55\n25ZO Clause 5.11.1 modified\nClause 5.11.1(d)\nomit\nAEMO\n25ZP Clause 5.11.2 modified\n(1) After clause 5.11.2, heading\nNote\nThe application of paragraph (b) of this clause will be revisited as part of the\n(2) Clause 5.11.2(b)\n(b) if the analysis required by paragraph (a) indicates that any relevant\ntechnical limits of the transmission or distribution systems will be\nexceeded, either in normal conditions or following the contingencies\nspecified in jurisdictional electricity legislation, notify any affected\nRegistered Participants and NTESMO of these limitations; and\nNote\nThe contingencies in jurisdictional electricity legislation referred to in\nparagraph (b) will be contingencies that correspond to the matters set out in\nSchedule 5.1 in the Rules applying in other participating jurisdictions. The\nspecification of contingencies will be revisited as part of the phased\n(3) Clause 5.11.2(c)\nomit\nAEMO\n\nRegulations 2016 56\n25ZQ Clause 5.12.1 modified\nClause 5.12.1(b)(3)\nomit\n25ZR Clause 5.12.2 modified\n(1) After clause 5.12.2, heading\nNote\nParagraph (c)(6), (6A) and (8)(ii) of this clause has no effect in this jurisdiction\nUniform Legislation) (Modification) Regulations 2016). The application of these\nprovisions, the rest of paragraph (c)(8), and paragraph (c)(9) and (10), will be\n(2) Clause 5.12.2(a) and (b)\n(a) By 31 December each year all Transmission Network Service\nProviders must publish a Transmission Annual Planning Report\nsetting out the results of the annual planning review conducted in\naccordance with clause 5.12.1.\n(b) A Network Service Provider must publish its Transmission Annual\nPlanning Report in the same document as its Distribution Annual\nPlanning Report.\n(3) Clause 5.12.2(c)(9)\nomit\nclause S5.1.8\n(4) Clause 5.12.2(c)(10)\nomit\nclause S5.1.10\n\nRegulations 2016 57\n(5) After clause 5.12.2(c)\nNote\nThe emergency controls in jurisdictional electricity legislation referred to in\nsubparagraph (9) will be emergency controls that correspond to clause S5.1.8 in\nthe Rules applying in other participating jurisdictions. The facilities in jurisdictional\nelectricity legislation referred to in subparagraph (10) will be facilities that\ncorrespond to clause S5.1.10 in the Rules applying in other participating\njurisdictions.\n25ZS Clause 5.13.1 modified\nClause 5.13.1(g)\nomit\n25ZT Clause 5.13.2 modified\nClause 5.13.2(b), note\nNote\nUnder clause 5.12.2(b), a Network Service Provider may publish its Transmission\nAnnual Planning Report in the same document as its Distribution Annual\nPlanning Report under this clause 5.13.2.\n25ZU Clause 5.13.3 modified\nAfter clause 5.13.3(d)\n(e) For the application of these Rules in this jurisdiction:\n(1) a system limitation template developed and published by the\nAER and in operation immediately before 1 July 2019 is taken\nto have been developed and published by the AER on\n1 July 2019; and\nparagraphs (a) and (c) in developing and publishing the\nsystem limitation template.\n\nRegulations 2016 58\n25ZV Rule 5.13A modified\nRule 5.13A(a), definition ten year zone substation report\nomit\nthe commencement of this rule 5.13A\n25ZW Clause 5.14.1 modified\nClause 5.14.1(c), after \"dual function assets\"\nor transmission assets that are regulated under Chapter 6\n25ZX Clause 5.14B.1 modified\nClause 5.14B.1, at the end\nNote\noperation in the Northern Territory, in circumstances set out in that section. The\nTAPR Guidelines made and published by the AER under this clause constitute\nNorthern Territory, the TAPR Guidelines are taken to be valid and to have effect\nfrom 1 July 2019.\n25ZY Clause 5.15.1 modified\nClause 5.15.1\nomit\n25ZZ Clause 5.15.2 modified\nClause 5.15.2(b)(4)\nomit\nintra-regional or inter-regional trading of electricity\n\nRegulations 2016 59\ntrading of electricity within a local electricity system\n25ZZA Clause 5.16.1 modified\n(1) Clause 5.16.1(b)\nomit\nor the provision of inertia network services required under\nclause 5.20B.4 or the provision of system strength services\nrequired under clause 5.20C.3\n(2) Clause 5.16.1(c)(4)(vii)\nomit\nancillary services\nancillary services\n25ZZB Clause 5.16.2 modified\nAfter clause 5.16.2(a)\nNote\noperation in the Northern Territory, in circumstances set out in that section.\nGuidelines developed and published by the AER under paragraph (a) constitute\nNorthern Territory, these guidelines are taken to be valid and to have effect from\n25ZZC Clause 5.16.3 modified\nAfter clause 5.16.3, heading\nNote\nParagraph (a)(8) to (11) of this clause has no effect in this jurisdiction (see\n\nRegulations 2016 60\n25ZZD Clause 5.16.4 modified\n(1) After clause 5.16.4, heading\nNote\nParagraph (b)(4) of this clause has no effect in this jurisdiction (see regulation 5A\n(2) Clause 5.16.4(a), (c), (d)(1), (e), (f), (g), (j), (o)(1), (p), (q), (r), (s),\n(t), (u), (w)(1) and (x)\nAEMO\n25ZZE Clause 5.16.5 modified\nClause 5.16.5(a)\nomit\nAEMO\n25ZZF Clause 5.17.1 modified\nClause 5.17.1(b), (c)(4)(vi) and (c)(9)(v)\nlocal electricity system\n\nRegulations 2016 61\n25ZZG Clause 5.17.2 modified\n(1) After clause 5.17.2(a)\nNote\noperation in the Northern Territory, in circumstances set out in that section.\nGuidelines developed and published by the AER under paragraph (a) constitute\nNorthern Territory, these guidelines are taken to be valid and to have effect from\n(2) Clause 5.17.2(b)(2)(iii)\nomit\nlocal electricity system\n25ZZH Clause 5.17.3 modified\nAfter clause 5.17.3, heading\nNote\nParagraph (a)(7) of this clause has no effect in this jurisdiction (see regulation 5A\n25ZZI Clause 5.17.4 modified\n(1) After clause 5.17.4, heading\nNote\nThe application of paragraph (e)(4)(iv) of this clause will be revisited as part of\nthe phased implementation of the Rules in this jurisdiction.\n\nRegulations 2016 62\n(2) Clause 5.17.4(a)(1), (h) and (k)(1)\nAEMO\n(3) Clause 5.17.4(e)(4)(iv)\nomit\nclause 4.6.1\n(4) After clause 5.17.4(e)(4)\nNote\nThe power system fault levels in jurisdictional electricity legislation referred to in\nsubparagraph (4)(iv) will be power system fault levels that correspond to\nclause 4.6.1 in the Rules applying in other participating jurisdictions.\n25ZZJ Clause 5.17.5 modified\nClause 5.17.5(a)\nomit\nAEMO\n25ZZK Rule 5.18 modified\nAfter rule 5.18, heading\nNote\nThe application of paragraph (c) of this rule will be revisited as part of the phased\n\nRegulations 2016 63\n25ZZL Rule 5.18A modified\nRule 5.18A, heading\nomit\nLarge generator connections\nGenerator connections\n25ZZM Clause 5.18A.1 modified\nClause 5.18A.1(a), definition large generator connection\nlarge generator connection means generating units that are\nowned, operated or controlled by a Generator, are connected to the\nTransmission Network Service Provider's network, and are above\nthe relevant materiality threshold.\n25ZZN Clause 5.18A.2 modified\n(1) Clause 5.18A.2, heading\nRegister of generator connections\n(2) Clause 5.18A.2(a)\n(a) A Transmission Network Service Provider must establish, maintain\nand publish, on its website, a register of information regarding\nGenerator connections on its network (a connections register),\nincluding but not limited to the following information in respect of\neach Generator connection:\n(1) location of the connection point for the Generator connection;\n(2) person who is licensed by the Utilities Commission as a\nGenerator in respect of the Generator connection at that\nconnection point;\n(3) technology of the generating units (for example, hydro, open\ncycle gas turbine, and steam sub-critical);\n\nRegulations 2016 64\n(4) aggregate nameplate rating capacity of all connected\ngenerating units;\n(5) date of cessation of a person's licence as Generator in respect\nof the Generator connection, or date of cessation of an\nexemption to hold such a licence applying in relation to a\nperson, where relevant; and\n(6) in the case of a large generator connection, the impact\nassessment of that large generator connection, prepared in\naccordance with clause 5.18A.3 (if any).\n(3) Clause 5.18A.2(c)\n(c) The Transmission Network Service Provider must:\n(1) include in the first connections register the details contained in\nsubparagraphs (a)(1) to (5), for all Generator connections on\nits network with a commissioning date after 1 July 2019; and\n(2) by the TAPR date each year, update the connections register\nto include:\n(i) the details contained in subparagraphs (a)(1) to (6) for\nall new Generator connections on its network; and\n(ii) updated information for all Generator connections\ncontained in the connections register where the\ninformation listed in subparagraphs (a)(1)-(5) has\nchanged.\n25ZZO Clause 5.18A.3 modified\n(1) After clause 5.18A.3, heading\nNote\nParagraph (d)(1) of this clause has no effect in this jurisdiction (see regulation 5A\n\nRegulations 2016 65\n(2) Clause 5.18A.3(a)\n(a) Following the commissioning date of a new large generator\nconnection on a Transmission Network Service Provider's network,\nthe Transmission Network Service Provider must:\n(1) determine whether that large generator connection is likely to\nhave a material impact on its transmission network; and\n(2) if the Transmission Network Service Provider determines that\nlarge generator connection is likely to have a material impact\non its transmission network, prepare an assessment of the\nimpact of that large generator connection on its network by the\nassessment date (impact assessment)\n(a1) If the Transmission Network Service Provider determines that that\nlarge generator connection is not likely to have a material impact on\nits transmission network, the Transmission Network Service\nProvider must outline the reasons for determining such impacts to\nbe immaterial.\n25ZZP Clause 5.18B.1 modified\nClause 5.18B.1(a), definition completed embedded generation\nprojects\ncompleted embedded generation projects means all embedded\ngenerating units owned, operated or controlled by a Generator that\nare connected to the Distribution Network Service Provider's\n25ZZQ Rule 5.20 modified\nAfter rule 5.20, heading\nNote\n\nRegulations 2016 66\n25ZZR Rules 5.20A, 5.20B and 5.20C modified\nAfter rules 5.20A, 5.20B and 5.20C, headings\nNote\nRegulations 2016). The application of this rule will be revisited as part of the\n25ZZS Rules 5.21 and 5.22 modified\nAfter rules 5.21 and 5.22, headings\nNote\n25ZZT Schedules 5.1a to 5.3a modified\nAfter schedules 5.1a, 5.1, 5,2, 5.3 and 5.3a, headings\nNote\nThis schedule has no effect in this jurisdiction (see regulation 5A of the National\nRegulations 2016). The application of this schedule will be revisited as part of\nthe phased implementation of the Rules in this jurisdiction.\n25ZZU Schedule 5.4A modified\n(1) After schedule 5.4A, heading and note\nNote\nParagraphs (a)(9), (i1) and (o)(3) of this schedule have no effect in this\n\nRegulations 2016 67\n(2) Schedule 5.4A(c)\n(c) information relevant to each technical requirement of the proposed\nplant under jurisdictional electricity legislation and the normal\nvoltage level, if it is expected to change from the nominal voltage\nlevel;\n25ZZV Schedule 5.4B modified\n(1) After schedule 5.4B, heading\nNote\nParagraphs (e) and (e1)(2) of this schedule have no effect in this jurisdiction (see\nLegislation) (Modification) Regulations 2016). The application of paragraphs (b),\n(e) and (e1) of this schedule will be revisited as part of the phased\n(2) Schedule 5.4B(b)\n(b) written details of each technical requirement relevant to the\nproposed plant under jurisdictional electricity legislation;\n(3) Schedule 5.4B(g)\nomit\nrules 6.21 and 6A.28\nrule 6.21\n25ZZW Schedules 5.5, 5.5.3, 5.5.4 and 5.5.5 modified\nAfter Schedules 5.5, 5.5.3, 5.5.4 and 5.5.5, headings\nNote\nThis schedule has no effect in this jurisdiction (see regulation 5A of the National\n\nRegulations 2016 68\n25ZZX Schedule 5.6 modified\n(1) After schedule 5.6, heading\nNote\nParagraphs (c2) and (c3) of this schedule have no effect in this jurisdiction (see\nLegislation) (Modification) Regulations 2016). The application of paragraphs (c),\n(c1) and (c3) of this schedule will be revisited as part of the phased\n(2) Schedule 5.6, Part A(c1)\n(c1) details of each access standard agreed between the Network\nService Provider and the Registered Participant and all related\nconditions of agreement resulting from the application of the access\nprovisions contained in jurisdictional electricity legislation;\nNote\nThe access provisions in jurisdictional electricity legislation referred to in\nparagraph (c1) will be access provisions that correspond to schedules 5.1, 5.2\nor 5.3 in the Rules applying in other participating jurisdictions.\n25ZZY Schedule 5.8 modified\n(1) After schedule 5.8, heading and note\nNote\nThe application of paragraph (m) of this schedule will be revisited as part of the\n(2) Schedule 5.8(m)\n(m) information on the Distribution Network Service Provider's\ninvestments in metering or information technology and\ncommunication systems which occurred in the preceding year, and\nplanned investments in metering or information technology and\ncommunication systems related to management of network assets\nin the forward planning period; and\n\nRegulations 2016 69\n25ZZZ Schedule 5.9 modified\nAfter schedule 5.9, heading and note\nNote\nParagraph (h) of this schedule has no effect in this jurisdiction (see regulation 5A\n(Modification) Regulations 2016). The application of paragraph (h) of this\nschedule will be revisited as part of the phased implementation of the Rules in\n25ZZZA Schedule 5.11 modified\n(1) After schedule 5.11, heading\nThe following provisions apply to the operation of this schedule:\n(a) principles (1), (4), (8), (9) and (10) have no effect in this\n(b) principles (2), (3), (5), (6) and (7) only have effect for the\npurposes of schedule 12;\n(c) principles (11), (12) and (13) only have effect for the purposes\nof Chapter 6, in relation to negotiated transmission services.\n(2) Schedule 5.11, paragraph 3\n3 If the negotiated transmission service is the provision of a\nshared transmission service that exceeds the network\nperformance requirements (if any) which that shared\ntransmission service is required to meet under any\njurisdictional electricity legislation, then the differential\nbetween the price for that service and the price for the shared\ntransmission service which meets (but does not exceed) the\nnetwork performance requirements under any jurisdictional\nelectricity legislation should reflect the increase in the\nTransmission Network Service Provider's incremental cost of\nproviding that service.\n(3) Schedule 5.11, paragraph 8, after \"principles (1) to (7)\"\n(other than principles (1) and (4))\n\nRegulations 2016 70\n25ZZZB Schedule 5.12 modified\nSchedule 5.12, paragraph 1, after \"schedule 5.11\"\n(other than principle 4)\n","sortOrder":61},{"sectionNumber":"26","sectionType":"section","heading":"Clause 5A.A.1 modified","content":"26 Clause 5A.A.1 modified\nClause 5A.A.1, definition confidential information\nAEMO\n","sortOrder":62},{"sectionNumber":"27","sectionType":"section","heading":"Clause 5A.A.2 modified","content":"27 Clause 5A.A.2 modified\nClause 5A.A.2(a)\nomit\nan Intending Participant unless the Registered Participant or\nIntending Participant\na person intending to become a Registered Participant unless the\nRegistered Participant or person intending to become a Registered\nParticipant\n","sortOrder":63},{"sectionNumber":"28","sectionType":"section","heading":"Clause 5A.A.3 modified","content":"28 Clause 5A.A.3 modified\nAfter clause 5A.A.3, heading\nNote\nClause 5A.A.3 has no effect in this jurisdiction (see regulation 5A of the National\nRegulations). The application of clause 5A.A.3 will be revisited as part of the\n\nRegulations 2016 71\n","sortOrder":64},{"sectionNumber":"30","sectionType":"section","heading":"Clause 5A.B.3 modified","content":"30 Clause 5A.B.3 modified\nAfter clause 5A.B.3(b)\n(ba) For the purposes of paragraph (b)(1), the AER must regard the\n","sortOrder":65},{"sectionNumber":"31","sectionType":"section","heading":"Clause 5A.B.5 modified","content":"31 Clause 5A.B.5 modified\nAfter clause 5A.B.5(b)\n(ba) For the purposes of paragraph (b), the AER must regard the\n","sortOrder":66},{"sectionNumber":"33","sectionType":"section","heading":"Clause 5A.C.1 modified","content":"33 Clause 5A.C.1 modified\nAfter clause 5A.C.1, heading\nNote\nClause 5A.C.1(c) and (d) has no effect in this jurisdiction until the National\nEnergy Retail Law is applied as a law of this jurisdiction (see regulation 5A of the\n","sortOrder":67},{"sectionNumber":"34","sectionType":"section","heading":"Clause 5A.D.1A modified","content":"34 Clause 5A.D.1A modified\n(1) Clause 5A.D.1A\nrelevant materiality threshold has the same meaning as in\nclause 5.1.3.\n(2) Clause 5A.D.1A, definition completed non-registered embedded\ngeneration projects, after \"Distribution Network Service Provider's\nnetwork\"\nand that are below the relevant materiality threshold\n\nRegulations 2016 72\n","sortOrder":68},{"sectionNumber":"38","sectionType":"section","heading":"Clause 5A.E.3 modified","content":"38 Clause 5A.E.3 modified\nAfter clause 5A.E.3(g)\n(ga) For the application of these Rules in this jurisdiction:\n(1) the connection charge guidelines that are in force in the other\nparticipating jurisdictions on 1 July 2017 are taken:\n(i) to be the connection charge guidelines in force in this\n1 July 2017; and\nparagraphs (e), (f) and (g) in developing and publishing the\nconnection charge guidelines.\n","sortOrder":69},{"sectionNumber":"39","sectionType":"section","heading":"Clause 5A.E.4 modified","content":"39 Clause 5A.E.4 modified\nAfter clause 5A.E.4, heading\nNote\nThe note to clause 5A.E.4(c) has no effect in this jurisdiction until the National\nEnergy Retail Law is applied as a law of this jurisdiction. The remaining\nprovisions of clause 5A.E.4 have no effect in this jurisdiction until 1 July 2019\nUniform Legislation) (Modification) Regulations).\n","sortOrder":70},{"sectionNumber":"41","sectionType":"section","heading":"Clause 5A.F.5 modified","content":"41 Clause 5A.F.5 modified\nAfter clause 5A.F.5, heading\nNote\nClause 5A.F.5(b)(2) has no effect in this jurisdiction until the National Energy\nRetail Law is applied as a law of this jurisdiction (see regulation 5A of the\n\nRegulations 2016 73\n","sortOrder":71},{"sectionNumber":"42","sectionType":"section","heading":"Rules 6.0 and 6.0A inserted","content":"42 Rules 6.0 and 6.0A inserted\nAfter Chapter 6, Part A, heading\n6.0 Operation of Chapter 6 in this jurisdiction\n(a) This rule applies if a Distribution Network Service Provider owns,\ncontrols or operates more than one distribution system in this\n(b) Despite any other provision of this Chapter:\n(1) for all of those distribution systems there must be, in respect\nof a particular regulatory control period, only one:\n(i) draft distribution determination and final distribution\ndetermination;\n(ii) framework and approach paper;\n(iii) building block proposal and building block determination;\n(iv) regulatory proposal;\n(v) proposed and final tariff structure statement; and\n(vi) regulatory asset base value; and\n(2) all of those distribution systems must be treated as a single\ndistribution system for the purposes of clause 6.5.1 and\nschedule 6.2.\n6.0A Interpretation\n(a) This rule applies in relation to the following:\n(1) the provisions of this Chapter;\n(2) the provisions of Chapters 11 and 11A, to the extent the\nprovisions operate in relation to this Chapter;\n(3) an instrument made under or for the purposes of this Chapter;\nand\n(4) the definitions in Chapter 10, to the extent the definitions are\nmentioned in a provision or instrument mentioned in\nsubparagraph (1), (2) or (3).\n\nRegulations 2016 74\n(b) Unless the context or subject matter otherwise indicates or\nrequires:\n(1) a prescribed transmission service will be taken to be a direct\ncontrol service under a provision or instrument mentioned in\nparagraph (a); and\n(2) a negotiated transmission service will be taken to be a\nnegotiated distribution service under a provision or instrument\nmentioned in paragraph (a).\n(c) Unless the context or subject matter otherwise indicates or\nrequires, in a provision or instrument mentioned in paragraph (a):\n(1) a reference to a \"distribution network\" must be regarded as\nincluding a reference to a \"transmission network\";\n(2) a reference to a \"distribution system\" must be regarded as\nincluding a reference to a \"transmission system\";\n(3) a reference to a \"Distribution Network User\" must be regarded\nas including a reference to a \"Transmission Network User;\n(4) a reference to a \"Distribution Network Service Provider\" must\nbe regarded as including a reference to a \"Transmission\nNetwork Service Provider\";\n(5) a reference to a \"distribution service\" must be regarded as\nincluding a reference to a \"transmission service\";\n(6) a reference to an \"embedded generating unit\" must be\nregarded as a reference to a \"generating unit\";\n(7) a reference to an \"Embedded Generator\" must be regarded as\na reference to a \"Generator\"; and\n(8) a reference to a \"Distribution Customer\" must be regarded as\nincluding a reference to a \"Transmission Customer\".\n","sortOrder":72},{"sectionNumber":"43","sectionType":"section","heading":"Clause 6.1.3 modified","content":"43 Clause 6.1.3 modified\n(1) Clause 6.1.3(a)(2)\nomit\nChapters 4, 5, this Chapter 6 and Chapter 7A of the Rules\nChapters 5, 6 and 7A of the Rules and under jurisdictional\n\nRegulations 2016 75\n(2) After clause 6.1.3(a)\nThe terms and conditions of access in jurisdiction electricity legislation will be\nterms and conditions that correspond to matters set out in Chapter 4 of the Rules\napplying in other participating jurisdictions. The application of paragraph (a) will\nbe revisited as part of the phased implementation of the Rules in this jurisdiction.\n","sortOrder":73},{"sectionNumber":"44","sectionType":"section","heading":"Clause 6.2.1 modified","content":"44 Clause 6.2.1 modified\nClause 6.2.1, note\nomit\nChapter 5A\nChapters 5 and 5A\n(3) Clause 6.2.5(d)(3)\n(2A) for a distribution determination for a Distribution Network\nService Provider in this jurisdiction that will apply during the\n1st regulatory control period – the regulatory arrangements in\nthe 2014 NT Network Price Determination); and\n(3) for a distribution determination for a Distribution Network\nService Provider in this jurisdiction that will apply after the\n1st regulatory control period – the regulatory arrangements (if\nany) applicable to the relevant service immediately before the\ncommencement of the distribution determination; and\n(4) Clause 6.2.5(d), at the end\nThe modifications to this paragraph expire on 1 July 2024.\n\nRegulations 2016 76\n","sortOrder":74},{"sectionNumber":"47","sectionType":"section","heading":"Clause 6.4.1 modified","content":"47 Clause 6.4.1 modified\nAfter clause 6.4.1(c)\n(1) the post-tax revenue model that is in force in the other\nparticipating jurisdictions on 1 July 2016 is taken:\n(i) to be the post-tax revenue model in force in this\n(ii) to have been prepared and published by the AER on\nparagraphs (a) and (c) in preparing and publishing the post-\ntax revenue model.\n","sortOrder":75},{"sectionNumber":"49","sectionType":"section","heading":"Clause 6.4.4 modified","content":"49 Clause 6.4.4 modified\nAfter clause 6.4.4(e)\n(1) the Shared Asset Guidelines that are in force in the other\n(i) to be the Shared Asset Guidelines in force in this\nparagraph (d) in making and publishing the Shared Asset\nGuidelines.\n\nRegulations 2016 77\n","sortOrder":76},{"sectionNumber":"50","sectionType":"section","heading":"Clause 6.4.5 modified","content":"50 Clause 6.4.5 modified\nAfter clause 6.4.5(b)\n(ba) For the application of these Rules in this jurisdiction:\n(1) the Expenditure Forecast Assessment Guidelines that are in\nforce in the other participating jurisdictions on 1 July 2016 are\ntaken:\n(i) to be the Expenditure Forecast Assessment Guidelines\nin force in this jurisdiction (subject to any amendment or\nparagraph (a) in developing and publishing the Expenditure\nForecast Assessment Guidelines.\n","sortOrder":77},{"sectionNumber":"51","sectionType":"section","heading":"Rule 6.4A modified","content":"51 Rule 6.4A modified\nAfter rule 6.4A(c)\n(1) the Capital Expenditure Incentive Guidelines that are in force\nin the other participating jurisdictions on 1 July 2016 are taken:\n(i) to be the Capital Expenditure Incentive Guidelines in\nforce in this jurisdiction (subject to any amendment or\nparagraph (b) in making and publishing the Capital\nExpenditure Incentive Guidelines.\n\nRegulations 2016 78\n","sortOrder":78},{"sectionNumber":"52","sectionType":"section","heading":"Clause 6.5.1 modified","content":"52 Clause 6.5.1 modified\nAfter clause 6.5.1(d)\n(1) the roll forward model that is in force in the other participating\njurisdictions on 1 July 2016 is taken:\n(i) to be the roll forward model in force in this jurisdiction\n(subject to any amendment or replacement under these\nRules); and\nparagraphs (b), (d) and (e) in developing and publishing the\nroll forward model.\n","sortOrder":79},{"sectionNumber":"53","sectionType":"section","heading":"Clause 6.5.2 modified","content":"53 Clause 6.5.2 modified\nAfter clause 6.5.2(q)\n(qa) For the application of these Rules in this jurisdiction:\n(1) the Rate of Return Guidelines that are in force in the other\n(i) to be the Rate of Return Guidelines in force in this\nparagraphs (m) and (n) in making and publishing the Rate of\nReturn Guidelines; and\n(3) despite paragraph (p)(1), the AER need only review the Rate\nof Return Guidelines when it is required to review the\nGuidelines in the other participating jurisdictions.\n\nRegulations 2016 79\n","sortOrder":80},{"sectionNumber":"54","sectionType":"section","heading":"Clause 6.5.8 modified","content":"54 Clause 6.5.8 modified\nAfter clause 6.5.8(d)\n(1) the efficiency benefit sharing scheme that is in force in the\nother participating jurisdictions on 1 July 2016 is taken:\n(i) to be the efficiency benefit sharing scheme in force in\nthis jurisdiction (subject to any amendment or\nparagraphs (a) and (c) in developing and publishing the\nefficiency benefit sharing scheme.\n","sortOrder":81},{"sectionNumber":"55","sectionType":"section","heading":"Clause 6.5.8A modified","content":"55 Clause 6.5.8A modified\nAfter clause 6.5.8A(e)\n(1) the capital expenditure sharing scheme that is in force in the\nother participating jurisdictions on 1 July 2016 is taken:\n(i) to be the capital expenditure sharing scheme in force in\nthis jurisdiction (subject to any amendment or\n(ii) to have been developed by the AER on 1 July 2016; and\nparagraphs (b), (c) and (d) in developing the capital\nexpenditure sharing scheme.\n\nRegulations 2016 80\n","sortOrder":82},{"sectionNumber":"56","sectionType":"section","heading":"Clause 6.6.1 modified","content":"56 Clause 6.6.1 modified\nAfter clause 6.6.1, heading\nClause 6.6.1(a1)(4), (c)(6)(iii), (l) and (m) have no effect in this jurisdiction until\nthe National Energy Retail Law is applied as a law of this jurisdiction (see\n","sortOrder":83},{"sectionNumber":"57","sectionType":"section","heading":"Clause 6.6.1 modified (expires when NERL applied)","content":"57 Clause 6.6.1 modified (expires when NERL applied)\nBefore clause 6.6.1(a1)(1)\n(1AA) a local event prescribed by the National Electricity\n(Northern Territory) (National Uniform Legislation)\n(Modification) Regulations;\nNotes:\n1 See Part 3 of the National Electricity (Northern Territory) (National Uniform\nLegislation) (Modification) Regulations for modifications to the operation of\nthis clause 6.6.1 in relation to a local event.\n2 Subparagraph (1AA) expires when the National Energy Retail Law is applied\nas a law of this jurisdiction.\n","sortOrder":84},{"sectionNumber":"60","sectionType":"section","heading":"Clause 6.6.2 modified","content":"60 Clause 6.6.2 modified\nAfter clause 6.6.2(c)\n(1) the service target performance incentive scheme that is in\nforce in the other participating jurisdictions on 1 July 2016 is\ntaken:\n(i) to be the service target performance incentive scheme in\nforce in this jurisdiction (subject to any amendment or\nparagraphs (a) and (b) in developing and publishing the\nservice target performance incentive scheme.\n\nRegulations 2016 81\n","sortOrder":85},{"sectionNumber":"61","sectionType":"section","heading":"Clause 6.6.3 modified","content":"61 Clause 6.6.3 modified\nClause 6.6.3(c)(3)\nomit\nin the market\nvia a transmission or distribution system in this jurisdiction\n","sortOrder":86},{"sectionNumber":"62","sectionType":"section","heading":"Clause 6.6.4 modified","content":"62 Clause 6.6.4 modified\nAfter clause 6.6.4(a)\n(ab) For the purposes of paragraph (a), the AER must regard the\n","sortOrder":87},{"sectionNumber":"63","sectionType":"section","heading":"Clause 6.6A.1 modified","content":"63 Clause 6.6A.1 modified\nClause 6.6A.1(b)(2)(iii)\nomit\n$30\n$15\n","sortOrder":88},{"sectionNumber":"63A","sectionType":"section","heading":"Clause 6.7.1 modified","content":"63A Clause 6.7.1 modified\n(1) Clause 6.7.1(3)\n(3) if the negotiated distribution service is the provision of a\nshared distribution service that exceeds the network\nperformance requirements (if any) which that shared\ndistribution service is required to meet under any jurisdictional\nelectricity legislation, then the differential between the price for\nthat service and the price for the shared distribution service\nwhich meets (but does not exceed) the network performance\nrequirements under any jurisdictional electricity legislation\nshould reflect the increase in the Distribution Network Service\n\nRegulations 2016 82\nProvider's incremental cost of providing that service;\n(2) Clause 6.7.1(4)\nomit\nschedules 5.1a and 5.1\n(3) After clause 6.7.1(4)\nThe performance requirements in jurisdiction electricity legislation will be\nperformance requirements that correspond to matters set out in schedules 5.1a\nand 5.1 of the Rules applying in other participating jurisdictions.\n(4) Clause 6.7.1(8)(A)\nomit\nnegotiated distribution services which would have been negotiated\ndistribution services regardless of the operation of clause 6.24.2(c)\ndistribution services\n(5) After clause 6.7.1(11)\n(12) in relation to negotiated transmission services that are taken\nto be negotiated distribution services, principles (11), (12) and\n(13) in schedule 5.11 that apply for the purposes of this\nChapter.\n","sortOrder":89},{"sectionNumber":"63B","sectionType":"section","heading":"Clause 6.7.2 modified","content":"63B Clause 6.7.2 modified\n(1) Clause 6.7.2(b)(1)\nomit\n\nRegulations 2016 83\n(2) Clause 6.7.2(b)(2)\n(2) rules 5.3 and 5.3A, when negotiating for the provision of\nconnection services and the associated connection service\ncharges in respect of the provision of negotiated transmission\nservices that are taken to be negotiated distribution services;\n(3) Clause 6.7.2(b)(3)\nomit\n","sortOrder":90},{"sectionNumber":"63C","sectionType":"section","heading":"Clause 6.7.5 modified","content":"63C Clause 6.7.5 modified\n(1) Clause 6.7.5(d)(1)\nomit\n(2) Clause 6.7.5(d)(2)\n(2) rules 5.3 and 5.3A, insofar as the negotiating framework\napplies to negotiated transmission services that are taken to\nbe negotiated distribution services,\n","sortOrder":91},{"sectionNumber":"68","sectionType":"section","heading":"Rule 6.14A modified","content":"68 Rule 6.14A modified\nAfter rule 6.14A(d)\n(1) the Distribution Confidentiality Guidelines that are in force in\nthe other participating jurisdictions on 1 July 2016 are taken:\n(i) to be the Distribution Confidentiality Guidelines in force\nin this jurisdiction (subject to any amendment or\n\nRegulations 2016 84\nparagraphs (a) and (b) in making and publishing the\nDistribution Confidentiality Guidelines.\n","sortOrder":92},{"sectionNumber":"69","sectionType":"section","heading":"Clause 6.15.3 modified","content":"69 Clause 6.15.3 modified\nAfter clause 6.15.3(e)\n(1) the Cost Allocation Guidelines that are in force in the other\n(i) to be the Cost Allocation Guidelines in force in this\nparagraphs (a), (b) and (e) in making and publishing the Cost\nAllocation Guidelines.\n","sortOrder":93},{"sectionNumber":"70","sectionType":"section","heading":"Clause 6.15.4 modified","content":"70 Clause 6.15.4 modified\nClause 6.15.4(a)\n(a) Each Distribution Network Service Provider in this jurisdiction must\nsubmit to the AER for its approval a document setting out its\nproposed Cost Allocation Method within 6 months of being required\nto do so by the AER.\n\nRegulations 2016 85\n","sortOrder":94},{"sectionNumber":"72","sectionType":"section","heading":"Clause 6.17.1B inserted","content":"72 Clause 6.17.1B inserted\nBefore clause 6.17.2\n6.17.1B Application of Distribution Ring-Fencing Guidelines in this\njurisdiction\nDespite clause 6.17.1, in this jurisdiction:\n(a) the following provisions of the Distribution Ring-Fencing\nGuidelines have no effect:\n(1) clause 1.1.1, all words from \"For the avoidance\" to\n\"DNSPs.\";\n(2) clause 1.4, definition non-distribution services; and\n(3) clauses 3.1, 4.2.1, 4.2.2 and 4.2.3; and\n(b) a reference in the Distribution Ring-Fencing Guidelines to\n\"non-distribution services\" must be regarded as a reference\nto \"other services\"; and\n(c) a reference in clause 3.2.1(a) of the Distribution Ring-Fencing\nGuidelines and the note to that paragraph to \"affiliated\nentities\" must be regarded as a reference to \"related\nelectricity service providers\"; and\n(d) a reference in clause 6.2.1(b)(iv) of the Distribution Ring-\nFencing Guidelines to \"affiliated entity\" must be regarded as\na reference to \"related electricity service provider\".\nThis clause, and the operation of the Distribution Ring-Fencing Guidelines in this\njurisdiction, will be revisited in the event of the introduction of contestable\nservices (including contestable metering services) in this jurisdiction.\n","sortOrder":95},{"sectionNumber":"74","sectionType":"section","heading":"Clause 6.18.9 modified","content":"74 Clause 6.18.9 modified\nAfter clause 6.18.9, heading\nClause 6.18.9(a)(3) has no effect in this jurisdiction until 1 July 2019 (see\n\nRegulations 2016 86\n","sortOrder":96},{"sectionNumber":"75","sectionType":"section","heading":"Chapter 6, Parts M and N modified","content":"75 Chapter 6, Parts M and N modified\nAfter Chapter 6, Parts M and N headings\nThis Part has no effect in this jurisdiction. The application of this Part will be\n","sortOrder":97},{"sectionNumber":"75A","sectionType":"section","heading":"Rule 6.20.1 modified","content":"75A Rule 6.20.1 modified\n(1) Clause 6.20.1(a)(2)\nomit\na metrology procedure or, in the absence of a metrology procedure\nallowing such a determination to be made, by meter\nschedule 7A.7\n(2) Clause 6.20.1(b)\nomit\n(other than a Market Customer) incurs distribution service charges,\nthe Distribution Network Service Provider must bill the Market\nCustomer\n(other than a Distribution Customer who is financially responsible\nfor its own connection point) incurs distribution service charges, the\nDistribution Network Service Provider must bill the retailer\n(3) Clause 6.20.1(c)\nomit\nMarket Customer\nretailer\n\nRegulations 2016 87\n(4) Clause 6.20.1(e)(1)\nomit\nthat are Market Generators\nother than Embedded Generators whose sent out generation is not\npurchased in its entirety by a Retailer or Customer located at the\nsame connection point\n(5) Clause 6.20.1(e)(2)\nomit\nMarket Customer\nRetailer\n(6) Clause 6.20.1(e)(4)\nomit\n(7) Clause 6.20.1(e)(4)\nomit\nMarket Customers\nMarket Loads, Retailers\n(8) Clause 6.20.1(e)(5)\nomit\na metrology procedure\nschedule 7A.7\n\nRegulations 2016 88\n(9) Clause 6.20.1(e)(5)\nomit\n(10) Clause 6.20.1(e)(5)\nomit\nMarket Customers\nMarket Loads, retailers\n(11) Clause 6.20.1(f)(1)\nomit\nthat are not Market Generators\nwhose sent out generation is not purchased in its entirety by a\nRetailer or Customer located at the same connection point\n(12) Clause 6.20.1(f) and (g)\nomit\nLocal Retailer\nRetailer\n","sortOrder":98},{"sectionNumber":"75B","sectionType":"section","heading":"Rule 6.21.3 modified","content":"75B Rule 6.21.3 modified\nClause 6.21.3(a)\nomit\n\nRegulations 2016 89\n","sortOrder":99},{"sectionNumber":"75C","sectionType":"section","heading":"Rule 6.22.2 modified","content":"75C Rule 6.22.2 modified\n(1) Clause 6.22.2(a)(2)\nomit\nChapters 4, 5, this Chapter 6 and Chapter 7 and any other\napplicable regulatory instrument\nChapter 5, this Chapter 6, Chapter 7A and any other applicable\nregulatory instrument including but not limited to jurisdictional\n(2) Clause 6.22.2(a)(3)\n(3) in relation to all terms and conditions of access (including\nprice) the decisions of the AER where those decisions relate\nto those terms and conditions under Chapter 5, this\nChapter 6, Chapter 7A and jurisdictional electricity legislation\nand are made under Chapter 5, this Chapter 6 and\nChapter 7A.\n(3) Clause 6.22.2(b)(2)\nomit\nAEMO\n(4) Clause 6.22.2(c)(2)\nomit\nChapters 4, 5, this Chapter 6 and Chapter 7 of the Rules\nChapter 5, this Chapter 6, Chapter 7A and jurisdictional electricity\n\nRegulations 2016 90\n(5) Clause 6.22.2(c)(3)\n(3) in relation to all terms and conditions of access (including\nprice) the decisions of the AER where those decisions relate\nto those terms and conditions under Chapter 5, this\nChapter 6, Chapter 7A and jurisdictional electricity legislation\nand are made under Chapter 5, this Chapter 6 and Chapter 7;\n(6) Clause 6.22.2(d)(2)\nomit\nAEMO\n(7) Clause 6.22.2, at the end\nThe terms and conditions of access in jurisdiction electricity legislation referred to\nin paragraphs (a)(2) and (3) and (c)(2) and (3) will be terms and conditions that\ncorrespond to matters set out in Chapter 4 of the Rules applying in other\nparticipating jurisdictions. The application of those paragraphs will be revisited\n","sortOrder":100},{"sectionNumber":"77","sectionType":"section","heading":"Clause S6.1.1 modified","content":"77 Clause S6.1.1 modified\n(1) Clause S6.1.1(6) and (7)\n(5A) in the case of a building block proposal for a distribution\njurisdiction that will apply during the 1st regulatory control period:\n(i) capital expenditure for each of the past years of the 2009-14\nNT regulatory control period and 2014-19 NT regulatory\ncontrol period, and the expected capital expenditure for each\nof the last 2 years of the 2014-19 NT regulatory control period,\ncategorised in the same way as for the capital expenditure\nforecast and separately identifying for each such year:\n\nRegulations 2016 91\n(A) margins paid or expected to be paid by the Distribution\n(B) expenditure that should have been treated as operating\nexpenditure in accordance with the policy submitted\nunder paragraph (8) for that year; and\ncapital expenditure from capital expenditure in the 2009-14 NT\nregulatory control period and 2014-19 NT regulatory control\nperiod;\n(5B) in the case of a building block proposal for a distribution\njurisdiction that will apply during the 2nd regulatory control period:\n(i) capital expenditure for each of the past years of the 2014-19\nNT regulatory control period and each of the past regulatory\nyears of the 1st regulatory control period, and the expected\ncapital expenditure for each of the last 2 regulatory years of\nthe 1st regulatory control period, categorised in the same way\nas for the capital expenditure forecast and separately\nidentifying for each such year:\n(A) margins paid or expected to be paid by the Distribution\n(B) expenditure that should have been treated as operating\nexpenditure in accordance with the policy submitted\nunder paragraph (8) for that year; and\ncapital expenditure from capital expenditure in the 2014–19\nNT regulatory control period and 1st regulatory control period;\n(6) in the case of a building block proposal for a distribution\ncapital expenditure for each of the past regulatory years of the\nprevious and current regulatory control period, and the expected\ncapital expenditure for each of the last 2 regulatory years of the\ncurrent regulatory control period, categorised in the same way as\nfor the capital expenditure forecast and separately identifying for\neach such regulatory year:\n\nRegulations 2016 92\n(i) margins paid or expected to be paid by the Distribution\n(ii) expenditure that should have been treated as operating\nexpenditure in accordance with the policy submitted under\nparagraph (8) for that regulatory year;\n(7) in the case of a building block proposal for a distribution\nan explanation of any significant variations in the forecast capital\nexpenditure from historical capital expenditure; and\n(2) Clause S6.1.1, at the end\nThe modifications to this clause expire on 1 July 2029.\n","sortOrder":101},{"sectionNumber":"78","sectionType":"section","heading":"Clause S6.1.2 modified","content":"78 Clause S6.1.2 modified\nClause S6.1.2(7) and (8)\n(6A) in the case of a building block proposal for a distribution\njurisdiction that will apply during the 1st regulatory control period:\n(i) operating expenditure for each of the past years of the\n2009-14 NT regulatory control period and 2014-19 NT\nregulatory control period, and the expected operating\nexpenditure for each of the last 2 years of the 2014-19 NT\nregulatory control period, categorised in the same way as for\nthe operating expenditure forecast; and\noperating expenditure from operating expenditure in the\n2009-14 NT regulatory control period and 2014-19 NT\nregulatory control period;\n(6B) in the case of a building block proposal for a distribution\njurisdiction that will apply during the 2nd regulatory control period:\n(i) operating expenditure for each of the past years of the\n2014-19 NT regulatory control period and each of the past\n\nRegulations 2016 93\nregulatory years of the 1st regulatory control period, and the\nexpected operating expenditure for each of the last\n2 regulatory years of the 1st regulatory control period,\ncategorised in the same way as for the operating expenditure\nforecast; and\noperating expenditure from operating expenditure in the\n2014-19 NT regulatory control period and the 1st regulatory\ncontrol period;\n(7) in the case of a building block proposal for a distribution\noperating expenditure for each of the past regulatory years of the\nprevious and current regulatory control period, and the expected\noperating expenditure for each of the last 2 regulatory years of the\ncurrent regulatory control period, categorised in the same way as\nfor the operating expenditure forecast;\n(8) in the case of a building block proposal for a distribution\nan explanation of any significant variations in the forecast operating\nexpenditure from historical operating expenditure.\nThe modifications to this clause expire on 1 July 2029.\n","sortOrder":102},{"sectionNumber":"79","sectionType":"section","heading":"Clause S6.2.1 modified","content":"79 Clause S6.2.1 modified\n(2) Clause S6.2.1(a), at the end\nHowever, this clause does not apply to the establishment of the\nvalue of the regulatory asset base for a distribution system in this\njurisdiction as at the beginning of the 1st regulatory control period.\nSee clause S6.2.3A for the establishment of the value of the regulatory asset\nbase for a distribution system in this jurisdiction as at the beginning of the 1st\nregulatory control period. Also see rule 6.0(b)(2) for the treatment of distribution\nsystems in this jurisdiction for the purposes of this schedule.\n(3) Clause S6.2.1(b)\nomit\nS6.2.2 and S6.2.3\n\nRegulations 2016 94\nS6.2.3 and S6.2.3A\n","sortOrder":103},{"sectionNumber":"80","sectionType":"section","heading":"Clause S6.2.1 modified","content":"80 Clause S6.2.1 modified\nAfter clause S6.2.1(e)(3)\n(3A) However, in calculating the value of the regulatory asset base\nfor a distribution system in this jurisdiction as at the beginning\nof the first regulatory year of the 2nd regulatory control period,\nthe previous value of the regulatory asset base must be\nadjusted for the difference between:\n(i) the estimated capital expenditure for any part of the\n2014-19 NT regulatory control period or 1st regulatory\ncontrol period where that estimated capital expenditure\nhas been included in that value; and\n(ii) the actual capital expenditure for that part of the 2014-19\nNT regulatory control period or 1st regulatory control\nThis adjustment must also remove any benefit or penalty\nassociated with any difference between the estimated and\nactual capital expenditure.\nThis subparagraph expires on 1 July 2029.\n","sortOrder":104},{"sectionNumber":"82","sectionType":"section","heading":"Clause S6.2.2A modified","content":"82 Clause S6.2.2A modified\nAfter clause S6.2.2A(a1)\n(a2) However, for a decision on the regulatory asset base for a\ndistribution system in this jurisdiction as at the commencement of\nthe 2nd regulatory control period, review period means only the\nprevious control period (excluding the last 2 regulatory years of that\nprevious control period).\nThis paragraph expires on 1 July 2029.\n\nRegulations 2016 95\n","sortOrder":105},{"sectionNumber":"83","sectionType":"section","heading":"Clause S6.2.2B modified","content":"83 Clause S6.2.2B modified\nAfter clause S6.2.2B, heading\nClause S6.2.2B(b) and (c) has no effect in this jurisdiction until 1 July 2019 (see\n","sortOrder":106},{"sectionNumber":"84","sectionType":"section","heading":"Clause S6.2.3A inserted","content":"84 Clause S6.2.3A inserted\nAfter clause S6.2.3\nS6.2.3A Establishment of opening regulatory asset base for\ndistribution system in this jurisdiction for 1st regulatory\ncontrol period\n(a) Application of this clause\nThis clause applies to the establishment of the value of the\nregulatory asset base for a distribution system in this jurisdiction as\nat the beginning of the 1st regulatory control period.\n(b) Roll forward model to comply with this clause\nThe values to be used for completing the roll forward model must\nbe established in accordance with this clause.\n(c) Previous value of regulatory asset base for distribution system\nin this jurisdiction\nFor paragraph (d), the previous value of the regulatory asset base\nfor all distribution systems in this jurisdiction that are owned,\ncontrolled or operated by the Distribution Network Service Provider\nmentioned in the table below is as set out in the table:\nJurisdiction Distribution Network\nService Provider\nRegulatory Asset Base ($m)\nNorthern\nTerritory\nPower and Water\nCorporation\nABN 15 947 352 360\n860.65 (as at 1 July 2014 in\nJuly 2014 dollars)\n\nRegulations 2016 96\n(d) Method of adjustment of value of regulatory asset base\nThe value of the regulatory asset base for the distribution systems\nmentioned in paragraph (c) as at the beginning of the first\nregulatory year of the 1st regulatory control period must be\ncalculated by adjusting the previous value (the previous value) of\nthe regulatory asset base for the distribution systems as specified in\nparagraph (c) as follows:\n(1) The previous value of the regulatory asset base must be:\n(i) increased by the amount of all capital expenditure\nincurred during the 2014-19 NT regulatory control period\n(the previous control period), including any capital\nexpenditure determined for that period under\nclause 3.2.4(d)(i)(A) of Part B of the 2014 NT Network\nPrice Determination where the Determination has been\namended under clause 3.2.4(d)(iii) of the Determination\n(regardless of whether such capital expenditure is above\nor below the forecast capital expenditure for the period\nthat is adopted for the purposes of the Determination (if\nany) for that period); and\n(ii) reduced by the amount of any capital expenditure that\nhas been recovered by way of a pass through under\nclause 3.1 of Part B of the 2014 NT Network Price\nDetermination where the amount of that capital\nexpenditure would otherwise have been included in the\nvalue of the regulatory asset base.\n(2) The previous value of the regulatory asset base must be\nincreased by the amount of the estimated capital expenditure\napproved by the Utilities Commission or AER for any part of\nthe previous control period for which actual capital expenditure\nis not available.\n(3) The previous value of the regulatory asset base must be\nadjusted for the difference between:\n(i) the estimated capital expenditure for any part of the\n2009-14 NT regulatory control period or 2014-19 NT\nregulatory control period where that estimated capital\nexpenditure has been included in that value; and\n(ii) the actual capital expenditure for that part of the 2009-14\nNT regulatory control period or 2014-19 NT regulatory\ncontrol period.\n\nRegulations 2016 97\nThis adjustment must also remove any benefit or penalty\nassociated with any difference between the estimated and\nactual capital expenditure.\n(4) The previous value of the regulatory asset base must only be\nincreased by estimated or actual capital expenditure to the\nextent that all such capital expenditure is properly allocated to\nthe provision of NT equivalent services in accordance with the\nCost Allocation Methodology (as amended, varied or\nsubstituted from time to time) that is the subject of the Utilities\nCommission's final decision referred to in Chapter 5 of Part A\nof the 2014 NT Network Price Determination.\n(5) The previous value of the regulatory asset base must be\nreduced by the amount of depreciation of the regulatory asset\nbase during the previous control period, calculated in\naccordance with the 2014 NT Network Price Determination.\n(6) The previous value of the regulatory asset base must be\nreduced by the disposal value of any asset where that asset\nhas been disposed of during the previous control period.\n(7) The previous value of the regulatory asset base must be\nreduced by the value of an asset where the asset was\npreviously used to provide NT equivalent services but, as a\nresult of the classification of the asset under Part B, the asset\nis not to be used to provide standard control services for the\n1st regulatory control period.\n(8) The previous value of the regulatory asset base may be\nincreased by the value of an asset to which this subparagraph\napplies to the extent that:\n(i) the AER considers the asset to be reasonably required\nto achieve one or more of the capital expenditure\nobjectives; and\n(ii) the value of the asset has not been otherwise recovered.\nThis subparagraph applies to an asset that:\n(iii) was not used to provide NT equivalent services in the\nprevious control period but, as a result of a change to\nthe classification of a particular service under Part B, is\nto be used to provide standard control services for the\n1st regulatory control period; or\n(iv) was never previously used to provide NT equivalent\nservices but is to be used to provide standard control\nservices for the 1st regulatory control period.\n\nRegulations 2016 98\n(e) An increase or reduction in the value of the regulatory asset base\nunder paragraph (d)(7) or (8) is to be based on the portion of the\nvalue of the asset properly allocated, or formerly properly allocated,\nto NT equivalent services in accordance with the principles and\npolicies set out in the Cost Allocation Methodology (as amended,\nvaried or substituted from time to time) that is the subject of the\nUtilities Commission's final decision referred to in Chapter 5 of\nPart A of the 2014 NT Network Price Determination. The value of\nthe relevant asset is taken to be its value as shown in\nindependently audited and published accounts.\n","sortOrder":107},{"sectionNumber":"85","sectionType":"section","heading":"Chapters 6A and 6B modified","content":"85 Chapters 6A and 6B modified\nAfter Chapters 6A and 6B, headings\nThis Chapter has no effect in this jurisdiction (see regulation 5A of the National\nRegulations). The application of this Chapter will be revisited as part of the\n","sortOrder":108},{"sectionNumber":"86","sectionType":"section","heading":"Chapter 7 modified","content":"86 Chapter 7 modified\nAfter Chapter 7, heading\nThis Chapter has no effect in this jurisdiction but will take effect at a later date.\n","sortOrder":109},{"sectionNumber":"Part 7A","sectionType":"part","heading":"applies in this jurisdiction from 1 July 2019 in substitution for this","content":"Chapter 7A applies in this jurisdiction from 1 July 2019 in substitution for this\nChapter.\nCriteria for assessing when the transition to this Chapter will take effect will be\nconsidered as part of the phased implementation of the Rules in this jurisdiction.\n87 Chapter 7A inserted\nAfter Chapter 7\nChapter 7A Metering\nNote\nChapter 7A applies in substitution for Chapter 7 (which establishes the metering\nframework that applies in the other participating jurisdictions). Chapter 7A\noperates as a transitional framework until Chapter 7 takes effect in this\nCriteria for assessing when the transition to Chapter 7 will take effect will be\nconsidered as part of the phased implementation of the Rules in this jurisdiction.\n\nRegulations 2016 99\nThe application of requirements in Chapter 7A relating to market and institutional\narrangements will also be considered as part of the phased implementation of the\nPart A Introduction\n7A.1 Introduction to the Metering Chapter\n7A.1.1 Purpose and application\nThis Chapter provides the framework for metering for local\nelectricity systems by establishing the requirements for metering\ninstallations at connection points on transmission networks or\ndistribution networks.\n7A.1.2 Contents\nThis Chapter sets out provisions relating to:\n(a) roles and responsibilities of financially responsible\nparticipants, Metering Coordinators, NTESMO and the Utilities\nCommission relating to metering;\n(b) the appointment of, and the qualifications and requirements\napplying to, Metering Providers and Metering Data Providers;\n(c) the appointment of Metering Coordinators;\n(d) metering installation requirements;\n(e) metering data services and the metering database;\n(f) metering register requirements, the disclosure of NMI\ninformation, and the provision of metering data to retail\ncustomers;\n(g) security of, and rights to access, metering installations,\nservices provided by metering installations, energy data held\nin metering installations and metering data from metering\ninstallations; and\n(h) relevant metering procedures.\n7A.1.3 Definitions\nIn this Chapter:\nactual meter reading means the collection of energy data from a\nmetering installation by local access or remote acquisition.\n\nRegulations 2016 100\ndata stream means a stream of metering data associated with a\nconnection point, as represented by a NMI. A NMI may have\nmultiple data streams (for example, from one or more meters, or\none or more channels or registers that comprise a single meter).\nEach data stream is identified by a unique suffix associated with the\nNMI to which it belongs.\nfinancially responsible participant means a person who is\nfinancially responsible for a connection point.\nMDFF Specification means:\n(a) the Metering Data File Format Specification published by\nNTESMO in a communication guideline under clause S7A.1.3;\nor\n(b) if no Metering Data File Format Specification is published by\nNTESMO – the Metering Data File Format Specification NEM\n12 and NEM 13, published by AEMO, with an effective date of\n1 May 2022 (version 2.5).\nMetering Data File Format means metering data that is in a form\nthat complies with the MDFF Specification.\nmetering provision services means the provision, installation and\nmaintenance of metering installations.\nprepayment device means a metering installation that requires a\nprepayment for the supply of electricity prior to consumption.\nscheduled meter reading means an actual meter reading\nperformed in accordance with the usual reading cycle for the meter.\nspecial meter reading means an actual meter reading performed\noutside of the usual reading cycle for the meter.\nvending services means, for a metering installation at a\nconnection point that is a prepayment device, services that allow\nthe financially responsible participant to sell electricity that will flow\nthrough the prepayment device in the future for consumption, and\nto receive payment in advance for selling that electricity.\nNote\nThe following are examples of vending services:\n(a) services for prepayments made by credit card through a website or app, or\nover the telephone;\n(b) services for prepayments made in person by cash or credit card to purchase\na physical token or unique code that must be entered into a prepayment\ndevice.\n\nRegulations 2016 101\n7A.1.4 Inconsistency\n(a) If there is an inconsistency between substantive Chapter 7A and\nthe schedules to this Chapter, substantive Chapter 7A prevails to\nthe extent of the inconsistency.\n(b) In this clause:\nsubstantive Chapter 7A means this Chapter other than the\nschedules to this Chapter.\nNote\nTo the extent that there is an inconsistency between the Rules and the National\nMeasurement Act, the Act prevails to the extent of the inconsistency: see\nRule 1.7.1A.\nPart B Roles and Responsibilities\n7A.2 Role and responsibility of financially responsible\nparticipant\n(a) Before participating in a market in respect of a connection point,\nand for so long as the financially responsible participant continues\nto participate in a market, the financially responsible participant for\na connection point must ensure that:\n(1) a Metering Coordinator is appointed in respect of the\nconnection point in accordance with Part C of this Chapter;\n(2) the connection point has a metering installation and\ninformation about the metering installation is provided to\nNTESMO for inclusion on the metering register, where this is\nrequired by clause 7A.10.1;\n(3) a NMI has been obtained with respect to the connection point;\nand\n(4) if information about the metering installation is required to be\nprovided to NTESMO for inclusion on the metering register by\nclause 7A.10.1, the NMI is obtained prior to that information\nbeing provided to NTESMO.\nNote\n\nRegulations 2016 102\n(b) NTESMO may refuse to permit a financially responsible participant\nto participate in a market in respect of a connection point used for\nthe purposes of settlements if the financially responsible participant\nis not compliant with its obligation under paragraph (a) with respect\nto the connection point.\n(c) Where, following a request made by a financially responsible\nparticipant in accordance with clause 7A.6.14, the metering\ninstallation at a connection point is a prepayment device, the\nfinancially responsible participant is responsible for ensuring that an\narrangement for vending services is in place.\n7A.3 Role and responsibility of Metering Coordinator\n7A.3.1 Responsibility of the Metering Coordinator\nFor the term of its appointment in respect of a connection point, the\nMetering Coordinator is the person responsible for:\n(a) the provision, installation and maintenance of a metering\ninstallation at the connection point in accordance with Part D\nof this Chapter;\n(b) the collection of metering data with respect to the metering\ninstallation, the processing of that data, the retention of that\ndata in the metering data services database and the delivery\nof that data to the metering database and other persons in\naccordance with Part E of this Chapter; and\n(c) managing the security of and access to:\n(1) the metering installation;\n(2) services provided by the metering installation;\n(3) energy data held in the metering installation; and\n(4) metering data from the metering installation,\nin accordance with Part F of this Chapter.\n\nRegulations 2016 103\n7A.3.2 Role of the Metering Coordinator\nAppointment of a Metering Provider\n(a) The Metering Coordinator at a connection point, other than a\nconnection point with a type 7 metering installation, must appoint a\nperson who is accredited to provide metering provision services in\nthis jurisdiction to be the Metering Provider to provide metering\nprovision services for the connection point.\nNote\nAppointment of a Metering Data Provider\n(b) The Metering Coordinator at a connection point must appoint a\nperson who is accredited to provide metering data services in this\njurisdiction to be the Metering Data Provider to provide metering\ndata services for the connection point.\nNote\nMetering installations\n(c) The Metering Coordinator at a connection point, other than a\nconnection point with a type 7 metering installation, must ensure\n(1) the metering installation is provided, installed and maintained\nin accordance with the Rules;\n(2) the components, accuracy and testing of the metering\ninstallation comply with the requirements of the Rules;\n(3) the security control of the metering installation is provided in\naccordance with rule 7A.13;\n(4) if remote acquisition is used or is to be used – a\ncommunications interface is installed and maintained to\nfacilitate connection to the telecommunications network;\n(5) NTESMO is provided (when requested) with any information\nrequired for the purposes of Schedule 7A.1 for any new or\nreplacement metering installation or any altered metering\ninstallation; and\n\nRegulations 2016 104\n(6) the Metering Provider it appoints for the connection point\ncomplies with the obligations imposed on Metering Providers\nby this Chapter.\n(d) A Metering Coordinator must not prevent, hinder or otherwise\nimpede the Local Network Service Provider from locally accessing\na metering installation or connection point for the purposes of\nreconnecting or disconnecting the connection point.\nNote\nMetering data services\n(e) The Metering Coordinator at a connection point must:\n(1) ensure that the Metering Data Provider it appoints for the\nconnection point complies with the obligations imposed on\nMetering Data Providers by this Chapter;\n(2) ensure that metering data services are provided in accordance\nwith the Rules; and\n(3) arrange for the provision of relevant metering data to the\nMetering Data Provider if remote acquisition, if any, becomes\nunavailable.\nNote\nAccess to type 4 metering installations\n(f) The Metering Coordinator at a connection point with a type 4\n(1) must ensure that access to the metering installation, the\nservices provided by the metering installation and energy data\nheld in the metering installation is only granted to persons\nentitled to access the metering installation, or the services\nprovided by the metering installation or energy data held in the\nmetering installation, in accordance with this Chapter;\n(2) must not arrange a disconnection except:\n(i) on the request of the financially responsible participant\nor Local Network Service Provider;\n\nRegulations 2016 105\n(ii) where the disconnection is effected via remote access;\nand\n(iii) in accordance with jurisdictional electricity legislation;\n(3) must not arrange a reconnection except:\n(i) on the request of the financially responsible participant,\nLocal Network Service Provider or incoming retailer;\n(ii) where the reconnection is effected via remote access;\nand\n(iii) in accordance with jurisdictional electricity legislation;\nand\n(4) must not arrange a retailer planned interruption of the supply\nof electricity at the metering installation except:\n(i) on the request of the retailer; and\n(ii) in accordance with jurisdictional electricity legislation.\nNote\n7A.4 Qualification and requirements of Metering\nProviders and Metering Data Providers\n7A.4.1 Metering Providers\n(a) A Metering Provider must have an ISO 9000 series quality system\nin place.\nChapter:\nto provide metering provision services in this jurisdiction\n(including the services mentioned in the schedules in respect\nof which a Metering Provider requires accreditation); and\nMetering Provider for the connection point.\n\nRegulations 2016 106\n(c) For a connection point in respect of which a type 4, 4A, 5 or 6\nthis Chapter:\nto provide metering provision services in this jurisdiction\n(including the services mentioned in the schedules in respect\nof which a Metering Provider requires accreditation); and\nMetering Provider for the connection point.\n(d) A Metering Provider may, in providing metering provision services\nunder this Chapter, contract with another person to assist it in the\nprovision of those services, if that person meets all relevant safety\nand technical requirements in any applicable regulatory instruments\nor other relevant law.\n7A.4.2 Metering Data Providers\n(a) A Metering Data Provider must have an ISO 9000 series quality\nsystem in place.\nChapter:\nto provide metering data services in this jurisdiction (including\nthe services mentioned in the schedules in respect of which a\nMetering Data Provider requires accreditation); and\nMetering Data Provider for the connection point.\n(c) For a connection point in respect of which a type 4, 4A, 5, 6 or 7\nthis Chapter:\nto provide metering data services in this jurisdiction (including\nthe services mentioned in the schedules in respect of which a\nMetering Data Provider requires accreditation); and\nMetering Data Provider for the connection point.\n\nRegulations 2016 107\n(d) A Metering Data Provider may, in providing metering data services\nunder this Chapter, contract with another person to assist it in the\nprovision of those services, if that person meets all relevant safety\nand technical requirements in any applicable regulatory instrument\nor other relevant law.\nPart C Appointment of Metering Coordinator\n7A.5 Appointment of Metering Coordinator\nChapter, the financially responsible participant for the connection\npoint is taken to have appointed the Local Network Service Provider\nas the Metering Coordinator for the connection point.\n(c) For a connection point in respect of which a type 4, 4A, 5 or 6\nthis Chapter, the financially responsible participant for the\nconnection point is taken to have appointed the Local Network\nService Provider as the Metering Coordinator for the connection\n(d) For a connection point with a type 7 metering installation, the\nfinancially responsible participant for the connection point is taken\nto have appointed the Local Network Service Provider as the\nMetering Coordinator for the connection point.\nPart D Metering installation\n7A.6 Metering installation arrangement\n7A.6.1 Metering installation requirements\nthere is a metering installation at that connection point.\nNote\n(b) The Metering Coordinator at a connection point must ensure that\nenergy data held in the metering installation is based on units of\nwatthour (active energy) and where required varhour (reactive\nenergy).\n\nRegulations 2016 108\n(c) Installation and maintenance of a metering installation must be\ncarried out in a safe manner, and only by a Metering Provider\nappointed under clause 7A.3.2.\nNote\n7A.6.2 Metering installation components\n(a) A Metering Provider must, in accordance with the Rules, ensure\nthat a metering installation, other than a type 7 metering installation:\n(1) contains a device that has either a visible or an equivalently\naccessible display of the cumulative total energy measured by\nthat metering installation (at a minimum);\nNote\n(2) is accurate in accordance with clause 7A.6.6;\nNote\n(3) in the case of a type 1, 2, 3 or 4 metering installation – has\nelectronic data transfer facilities from the metering installation\nto the metering data services database;\nNote\n(4) includes a communications interface to meet the requirements\nof clause 7A.3.2(c)(4);\nNote\n\nRegulations 2016 109\n(5) is secure in accordance with rule 7A.9;\nNote\n(6) records energy data in a manner that enables metering data to\nbe collated in accordance with clause 7A.8.6;\nNote\n(7) is capable of separately recording energy data for energy\nflows in each direction where bi-directional active energy flows\noccur or could occur;\nNote\n(8) has a measurement element for active energy and, if required\nin accordance with schedule 7A.4, a measurement element for\nreactive energy, with both measurements to be recorded;\nNote\n(9) includes facilities for storing interval energy data for a period\nof at least 35 days if the metering installation is a type 1, 2, 3\nor 4 metering installation;\nNote\n(10) includes facilities for storing interval energy data for a period\nof at least 200 days or such other period as specified in\nschedule 7A.7 if the metering installation is a type 4A or 5\nmetering installation;\nNote\n\nRegulations 2016 110\n(11) in the case of a type 6 metering installation, includes facilities\ncapable of continuously recording the total accumulated\nenergy supplied through it by a visible display in accordance\nwith subparagraph (1), over a period of at least 12 months;\nand\nNote\n(12) is suitable for the range of operating conditions to which it will\nbe exposed (for example temperature or impulse levels) and\noperates within the defined limits for its components.\n(b) A metering installation may consist of combinations of:\n(1) a current transformer;\n(2) a voltage transformer;\n(3) secure and protected wiring from the current transformer and\nthe voltage transformer to the meter;\n(4) communications interface equipment such as a modem,\nisolation requirements, telephone service, radio transmitter\nand data link equipment;\n(5) auxiliary electricity supply to the meter;\n(6) an alarm circuit and monitoring facility;\n(7) a facility to keep the metering installation secure from\ninterference;\n(8) test links and fusing;\n(9) summation equipment; and\n(10) several metering points to derive the metering data for a\nconnection point.\n(c) The Local Network Service Provider or financially responsible\nparticipant may, with the agreement of the Metering Coordinator\n(which agreement must not be unreasonably withheld), arrange for\na metering installation to contain features which are in addition to,\nor which enhance, the features specified in paragraph (b).\n(d) The financially responsible participant for a connection point must:\n(1) apply to the Local Network Service Provider for a NMI; and\n\nRegulations 2016 111\n(2) provide the Metering Coordinator at the connection point with\nthe NMI for the metering installation within 5 business days of\nreceiving the NMI from the Local Network Service Provider.\n(e) The Local Network Service Provider must:\n(1) issue a unique NMI for each metering installation on its\nnetwork to the financially responsible participant; and\n(2) provide information about the NMI to NTESMO, where this is\nrequired for the purposes of clause 7A.10.1.\nNote\n(f) The Metering Coordinator must ensure that NTESMO is provided\nwith the relevant details of the metering installation as specified in\n","sortOrder":110},{"sectionNumber":"Sch 7A","sectionType":"schedule","heading":"1 within 10 business days of receiving the NMI under","content":"Schedule 7A.1 within 10 business days of receiving the NMI under\nparagraph (d)(2), where this is required for the purposes of\nclause 7A.10.1.\nNote\n(g) Where a metering installation is used for operational purposes in\naddition to metrological purposes, the Metering Coordinator must:\n(1) use reasonable endeavours to ensure that there will be no\ninfringement of the requirements of the Rules; and\n(2) co-ordinate with the persons who use the metering installation\nfor such other purposes.\n7A.6.3 Emergency management\nNote\nEmergency management will be considered as part of the phased\n7A.6.4 Network devices\nNote\nNetwork devices will be considered as part of the phased implementation of the\n\nRegulations 2016 112\n7A.6.5 Metering point\n(a) The Metering Coordinator at a connection point must ensure that:\n(1) the metering point is located as close as practicable to the\nconnection point, but is in a position that allows safe and\nunimpeded access to the metering installation by the Metering\nProvider, Metering Data Provider and any other person\nrequired or permitted to have access to the metering\ninstallation under the Rules or any other law; and\nNote\n(2) any instrument transformers required for a check metering\ninstallation are located in a position that achieves a\nmathematical correlation with the metering data.\nNote\n(b) The financially responsible participant, the Local Network Service\nProvider and NTESMO must use their best endeavours to agree to\nadjust the metering data which is recorded in the metering\ndatabase to allow for physical losses between the metering point\nand the relevant connection point where a meter is used to\nmeasure the flow of electricity in a power conductor.\n7A.6.6 Metering installation types and accuracy\n(a) The type of metering installation and the accuracy requirements for\na metering installation are to be determined in accordance with\nNote\nThis Chapter 7A makes provision for type 7 metering installations and imposes\nrequirements on type 7 metering installations, including obligations about\ncalculating metering data. Those obligations will only apply in this jurisdiction in\nthe event of a type 7 metering installation being available in this jurisdiction and\nafter a 12 month transitional period allowing all participants to achieve\ncompliance.\n(b) A check metering installation is not required to have the degree of\naccuracy required of a metering installation but the Metering\nCoordinator must ensure that it has mathematical correlation with\nthe metering installation and complies with the requirements of\n\nRegulations 2016 113\n(c) The Metering Coordinator at a connection point must ensure that\nthe accuracy of a type 6 metering installation is in accordance with\nregulations issued under the National Measurement Act or, in the\nabsence of any such regulations, with schedule 7A.7.\nNote\n7A.6.7 Functionality requirements for type 1, 2, 3 and 4 metering\n(a) This clause applies in respect of a type 1, 2, 3 or 4 metering\n(b) The Metering Coordinator at a connection point must ensure that\nthe metering installation complies with the functionality\nrequirements specified in schedule 7A.5.\n7A.6.8 Meter churn\n(a) A Metering Coordinator may arrange to alter a type 5 or 6 metering\ninstallation to make it capable of remote acquisition if:\n(1) the alteration is reasonably required to address operational\ndifficulties; or\n(2) the Metering Coordinator is the Local Network Service\nProvider and the alteration is reasonably required to enable\nthe Local Network Service Provider to meet its obligations to\nprovide a safe, reliable and secure network.\n(b) An alteration of a metering installation by a Metering Coordinator in\naccordance with paragraph (a) does not alter the classification of\nthat installation to a type 4 or 4A metering installation.\n(c) For paragraph (a)(1), operational difficulties arise if the metering\ninstallation is difficult or unsafe to access because:\n(1) it is on a remote property;\n(2) it is within a secure facility;\n(3) it is in close proximity to hazardous materials; or\n(4) accessing or arranging access to it otherwise poses a risk to\nthe safety and security of persons or property.\n\nRegulations 2016 114\n7A.6.9 Metering installation malfunctions\n(a) Unless an exemption is obtained by the Metering Coordinator from\nNTESMO under this clause 7A.6.9, the Metering Coordinator must,\nif a metering installation malfunction occurs in respect of a\nconnection point with a type 1, 2 or 3 metering installation, cause\nrepairs to be made to the metering installation as soon as\npracticable but no later than 2 business days after the Metering\nCoordinator had been notified of the metering installation\nmalfunction.\nNote\n(b) Unless an exemption is obtained by the Metering Coordinator from\nNTESMO under this clause 7A.6.9, if a metering installation\nmalfunction occurs, the Metering Coordinator must, in respect of a\nconnection point with:\n(1) a type 4 metering installation – cause repairs to be made to\nthe metering installation as soon as practicable but no later\nthan 10 business days after the Metering Coordinator has\nbeen notified of the metering installation malfunction; or\n(2) a metering installation other than the installations mentioned in\nparagraph (a) or subparagraph (1) – cause repairs to be made\nto the metering installation as soon as practicable but no later\nthan 10 business days after the Metering Coordinator has\nbeen notified of the metering installation malfunction.\n(c) NTESMO must establish, maintain and publish a procedure\napplicable to the provision of exemptions for the purposes of\nparagraphs (a) and (b).\n(d) If an exemption is provided by NTESMO under this clause 7A.6.9,\nthen the Metering Provider must provide NTESMO with a plan for\nthe rectification of the metering installation.\nNote\n(e) A Registered Participant, Metering Provider or Metering Data\nProvider who becomes aware of a metering installation malfunction\nthat cannot be rectified within the applicable timeframes as\nspecified in paragraphs (a) and (b) must notify the Metering\nCoordinator of the metering installation malfunction within 1\n\nRegulations 2016 115\nbusiness day.\nNote\n7A.6.10 Timeframes for meters to be installed – new connection\n(a) Subject to paragraph (b), where a new connection is requested at a\nretail customer's premises, the relevant retailer must arrange a\nmeter to be installed:\n(1) by a date agreed with the retail customer; or\n(2) failing agreement with the retail customer, on a date no later\nthan 6 business days from the date the retailer is informed that\nthe connection service (as defined in clause 5A.A.1) is\ncomplete.\n(b) The timeframe under paragraph (a)(1) or (2) (as applicable) will not\napply where:\npremises is not accessible or safe or ready for the meter to be\ninstalled, or the connection service (as defined in\nclause 5A.A.1) has not been completed; or\nretail customer.\nthat an exception under paragraph (b) ceases to apply, the retailer\nmust arrange for the meter to be installed:\n(1) by a new date agreed with the retail customer; or\n(2) failing agreement, on a date no later than 5 business days\nfrom the date that the exception ceases to apply.\n(d) A retailer must inform its retail customers of its obligations under\n\nRegulations 2016 116\n7A.6.11 Timeframes for meters to be installed – where a connection\nservice is not required\n(a) Subject to paragraph (b), if a retail customer has requested the\nretailer to install a meter at the customer's premises and a\nconnection service (as defined in clause 5A.A.1) is not required, the\nretailer must arrange for the meter to be installed:\n(1) by a date agreed with the retail customer; or\n(2) failing agreement with the retail customer, on a date no later\nthan 15 business days after the retailer received the request\nfrom the retail customer for the meter to be installed.\n(b) The timeframe under paragraph (a)(1) or (2) (as applicable) will not\napply where:\npremises is not accessible, safe, or ready for the meter to be\ninstalled; or\nretail customer.\nthat an exception under paragraph (b) ceases to apply, the retailer\nmust arrange for the meter to be installed:\n(1) by a new date agreed with the retail customer; or\n(2) failing agreement, on a date no later than 15 business days\nfrom the date that the exception ceases to apply.\n(d) For the avoidance of doubt, the timeframes for meters to be\ninstalled under this rule 7A.6.11 do not apply for a retailer initiated\ninstallation of a meter, or for a new connection.\n(e) A retailer must inform its retail customers of its obligations under\n\nRegulations 2016 117\n7A.6.12 Timeframes for meters to be installed – where a connection\nalteration is required\n(a) Subject to paragraph (b), if a retail customer has requested a meter\nto be installed at the customer's premises and a connection\nalteration is also required:\n(1) the retailer must arrange for the meter to be installed:\n(i) by a date agreed with the retail customer and the\nDistribution Network Service Provider where the\nDistribution Network Service Provider is providing the\nconnection alteration; or\n(ii) failing agreement, on a date no later than 15 business\ndays after the retailer received the request from the retail\ncustomer for the meter to be installed; and\n(2) where a Distribution Network Service Provider is providing the\nconnection alteration, the Distribution Network Service\nProvider must co-ordinate the connection alteration, with the\nretailer and other relevant parties, in order to allow the retailer\nto comply with its obligation under subparagraph (1).\n(b) The timeframe under paragraph (a)(1) (i) or (ii) (as applicable) will\nnot apply where:\npremises is not accessible, safe, or ready for the meter to be\ninstalled;\nretail customer;\n(4) the retail customer has not met the conditions that it is\nrequired to comply with under its connection contract; or\n(5) augmentation is required for the purposes of the connection\nalteration and has not yet been completed.\n\nRegulations 2016 118\nthat an exception under paragraph (b) ceases to apply:\n(1) the retailer must arrange for the meter to be installed:\n(i) by a new date agreed with the retail customer and the\nDistribution Network Service Provider where the\nDistribution Network Service Provider is providing the\nconnection alteration; or\n(ii) failing agreement, on a date no later than 15 business\ndays from the date that the exception ceases to apply;\nand\n(2) where a Distribution Network Service Provider is providing the\nconnection alteration, it must co-ordinate the connection\nalteration, with the retailer and other relevant parties, in order\nto allow the retailer to meet its obligation under\nsubparagraph (1).\n(d) If the retailer receives a request from a retail customer for a meter\nto be installed at the customer's premises where a connection\nalteration is also required, the retailer must inform the Distribution\nNetwork Service Provider of the request no later than the next\nbusiness day after receiving the request.\n(e) For the avoidance of doubt, the timeframes for meters to be\ninstalled under this rule 7A.6.12 do not apply for a retailer initiated\ninstallation of a meter, or for a new connection.\n(f) A retailer must inform its retail customers of its obligations under\n7A.6.13 Changing a metering installation\n(a) Subject to this clause, nothing in these Rules prevents the\nfinancially responsible participant (on its own behalf or, in the case\nof a retailer, on its own behalf or on behalf of a retail customer) or\nNetwork Service Provider in respect of a connection point from\nrequesting the Metering Coordinator to arrange for:\n(1) the alteration of the metering installation at that connection\npoint; or\n(2) the installation of a new metering installation at that\nconnection point.\n\nRegulations 2016 119\n(b) The incremental costs of the alteration of the metering installation\nor the installation of the new metering installation must be borne by\nthe person who requests the alteration of the metering installation\nor the installation of the new metering installation.\n(c) The Metering Coordinator at a connection point must ensure that\nchanges to parameters or settings within a metering installation are:\n(1) implemented by a Metering Provider; and\nNote\n(2) confirmed by the Metering Coordinator within 2 business days\nafter the alteration has been made; and\nNote\n(3) reported to NTESMO where required to enable NTESMO to\nrecord the changes in the metering register in accordance with\nclause 7A.10.2.\nNote\n7A.6.14 Prepayment metering\n(a) This clause applies if, in accordance with clause 7A.6.13, the\nfinancially responsible participant in respect of a connection point\nrequests the Metering Coordinator to arrange for:\n(1) the alteration of a metering installation so that it is a\nprepayment device; or\n(2) the installation of a new metering installation that is a\nprepayment device.\n(b) The Metering Coordinator must ensure that the Metering Provider:\n(1) alters the metering installation so that it is a prepayment\ndevice, if so requested; or\n(2) installs a new metering installation that is a prepayment\ndevice, if so requested.\n\nRegulations 2016 120\n7A.7 Maintenance, inspection, testing and auditing of\n7A.7.1 Maintenance\nThe Metering Coordinator for a connection point must ensure that\nany maintenance (including inspection and testing) of a metering\ninstallation at the connection point is carried out in a safe manner\nby an appropriately qualified person.\n7A.7.2 Responsibility for inspection and testing\n(a) The Metering Coordinator for a connection point must ensure that\nany inspection or testing of a metering installation at the connection\npoint is carried out in a safe manner by an appropriately qualified\nperson.\n(b) A person who arranges or carries out an inspection or testing of a\nmetering installation under this clause must do so in accordance\nwith:\n(1) this clause; and\n(2) the relevant inspection and testing requirements set out in\nschedule 7A.6.\nNote\n(c) A Registered Participant may request that the Metering Coordinator\nmake arrangements for the testing of a metering installation and, if\nthe request is reasonable, the Metering Coordinator:\n(1) must not refuse the request; and\n(2) must make arrangements for the testing.\n(d) The Registered Participant who requested the testing under\nparagraph (c) may make a request to the Metering Coordinator to\nwitness the tests.\n(e) The Metering Coordinator must not refuse a request received under\nparagraph (d) and must, no later than 5 business days prior to the\ntesting, advise:\n(1) the party making the request; and\n(2) the financially responsible participant,\n\nRegulations 2016 121\nof:\n(3) the location and time of the tests; and\n(4) the method of testing to be undertaken.\nNote\n(f) If the Metering Coordinator has arranged testing of a metering\ninstallation under this clause and schedule 7A.6, the Metering\nCoordinator must:\n(1) inform the financially responsible participant that testing has\nbeen undertaken in respect of the metering installation in\naccordance with this clause; and\n(2) make the test results available in accordance with\nparagraphs (g) and (h).\n(g) If the test results mentioned in paragraph (f) indicate deviation from\nthe technical requirements for the metering installation, the\nMetering Coordinator must ensure that the test results are provided\nas soon as practicable to the persons who receive the metering\ndata for the metering installation under clause 7A.8.4.\nNote\n(h) If the test results mentioned in paragraph (f) indicate compliance\nwith the technical requirements for the metering installation, the\nMetering Coordinator must ensure that the test results are provided\nas soon as practicable:\n(1) in circumstances where the tests were requested by a\nRegistered Participant, to the Registered Participant and\npersons who receive the metering data for the metering\ninstallation under clause 7A.8.4; or\n(2) to a Registered Participant if requested by that Registered\nParticipant, if the tests are not the result of a request for\ntesting.\nNote\n\nRegulations 2016 122\n(i) The Utilities Commission may check the test results recorded in the\nmetering register by arranging for audits of metering installations to\nsatisfy itself and NTESMO that the accuracy of each metering\ninstallation complies with the requirements of this Chapter 7A.\n(j) The Metering Coordinator must store the test results in accordance\nwith clause 7A.7.7 and provide a copy to the Utilities Commission\non request or as part of an audit.\n(k) The cost of any testing under paragraph (c) must be borne by:\n(1) if paragraph (g) applies – the Metering Coordinator; or\n(2) otherwise – the Registered Participant who requested the test.\n7A.7.3 Actions in event of non-compliance\n(a) If the accuracy of the metering installation does not comply with the\nrequirements of the Rules, the Metering Coordinator must:\n(1) advise NTESMO as soon as practicable of the errors detected\nand the possible duration of the existence of the errors;\n(2) arrange for the accuracy of the metering installation to be\nrestored within:\n(i) 10 business days; or\n(ii) if a timeframe is agreed with the financially responsible\nparticipant, in that timeframe; and\n(3) correct the metering data and provide the corrected metering\ndata to NTESMO.\nNote\n(b) NTESMO may make appropriate corrections to the metering data to\ntake account of errors referred to it under paragraph (a) for the\npurposes of settlements.\n7A.7.4 Audits of information held in metering installations\n(a) The Utilities Commission is responsible for auditing metering\n\nRegulations 2016 123\n(b) A Registered Participant or NTESMO may request the Utilities\nCommission to conduct an audit to determine the consistency\nbetween the data held in the metering database and the data held\nin the relevant metering installation.\n(c) If there are inconsistencies between data held in a metering\ninstallation and data held in the metering database, the Metering\nCoordinator and Registered Participants with a financial interest in\nthe metering installation or the energy measured by the metering\ninstallation must liaise together to determine the most appropriate\nway to resolve the discrepancy.\n(d) If there are inconsistencies between data held in a metering\ninstallation and data held in the metering database, the data held in\nthe metering installation is to be taken as prima facie evidence of\nthe connection point's energy data, except if the meter or\ncomponents of the metering installation are found to be non-\ncompliant with the Rules.\n(e) The cost of any audit conducted under paragraph (b) will be borne\nby:\n(1) if paragraph (c) applies, the Metering Coordinator; or\n(2) otherwise, the Registered Participant who requested the audit\nor NTESMO, as the case may be.\n7A.7.5 Appointment of external auditor\n(a) The Utilities Commission may, upon reasonable notice to the\nMetering Coordinator, appoint an independent auditor to audit\nmetering installations to confirm compliance with the Rules.\n(b) If the Utilities Commission appoints an independent auditor under\nparagraph (a):\n(1) the Utilities Commission will nominate the standards and\nrequirements and the auditor will report in accordance with\nthose standards and requirements; and\n(2) the Metering Coordinator must cooperate with any reasonable\nrequests made by the independent auditor in undertaking the\naudit.\n(c) The Utilities Commission will provide a copy of the auditor's report\nto:\n(1) the Metering Coordinator;\n(2) NTESMO; and\n\nRegulations 2016 124\n(3) the relevant financially responsible participant,\nas soon as reasonably possible after it has been completed.\n(d) The Metering Coordinator must ensure that the Utilities\nCommission (or its agents) have unrestricted access to metering\ninstallations for the purpose of carrying out external audits provided\nthat the Utilities Commission agrees to comply with the Metering\nCoordinator's reasonable security and safety requirements and has\nfirst given the Metering Coordinator at least 2 business days notice\nof its intention to carry out an audit.\n(e) A notice under paragraph (d) must include:\n(1) the name of the representative who will be conducting the\naudit on behalf of the Utilities Commission; and\n(2) the time when the audit will commence and the expected time\nwhen the audit will conclude.\n(f) The Metering Coordinator will be responsible for the costs of\nundertaking the audit.\n7A.7.6 Errors found in metering tests, inspections or audits\n(a) Subject to paragraph (c), if a metering installation test, inspection or\naudit, carried out in accordance with this rule, demonstrates errors\nin excess of those prescribed in schedule 7A.4, the Metering\nCoordinator must ensure the metering data is substituted in\naccordance with this clause and clause 7A.8.1 as appropriate.\n(b) If the Metering Coordinator is not aware of the time at which the\nerror arose:\n(1) the error is taken to have occurred at a time halfway between\nthe time of the most recent test or inspection which\ndemonstrated that the metering installation complied with the\nrelevant accuracy requirement and the time when the error\nwas detected; and\n(2) the time that the error was taken to occur is to be used by the\nMetering Data Provider in performing substitution of the\nmetering data.\n(c) If a test of a metering installation demonstrates an error of\nmeasurement of less than 1.5 times the error permitted by\nschedule 7A.4, no substitution of readings is required.\n\nRegulations 2016 125\n(d) The Metering Coordinator must arrange for a suitable substation of\nthe incorrect metering data to be undertaken in accordance with the\nsubstitution requirements of schedule 7A.7.\n7A.7.7 Retention of test records and documents\n(a) All records and documentation of tests prepared under or for this\nChapter must be retained in accordance with this clause.\n(b) The Metering Coordinator must ensure records and documentation\nare retained as follows:\n(1) for a period of at least 7 years:\n(i) sample testing of meters while the meters of the relevant\nstyle remain in service;\n(ii) the most recent sample test results of the meters\nmentioned in subparagraph (i) after the meters are no\nlonger in service;\n(iii) non-sample testing of meters while the meters remain in\nservice;\n(iv) the most recent non-sample test results after the meters\nare no longer in service;\n(v) the most recent sample test results of instrument\ntransformers after instrument transformers of the\nrelevant type are no longer in service;\n(vi) the most recent non-sample test results of instrument\ntransformers after they are no longer in service;\n(vii) tests of new metering equipment of the relevant style\nwhile the equipment remains in service; and\n(viii) tests of new metering equipment of the relevant style\nafter the equipment is no longer in service;\n(2) for a period of at least 10 years:\n(i) sample testing of instrument transformers while\ninstrument transformers of the relevant type remain in\nservice; and\n(ii) non-sample testing of instrument transformers while the\ninstrument transformers remain in service.\n\nRegulations 2016 126\n(c) In addition, the Metering Coordinator must ensure records of type\ntests and pattern approvals carried out or obtained in accordance\nwith clause S7A.4.5.1(f) are retained while metering equipment of\nthe relevant type remains in service and for at least 7 years after it\nis no longer in service.\nPart E Metering data\n7A.8 Metering data services\n7A.8.1 Metering data services\n(a) Metering Data Providers must provide metering data services,\nincluding the following, in accordance with the Rules:\n(1) collecting energy data by local access or remote acquisition;\n(2) the validation and substitution of metering data for types 1, 2,\n3 and 4 metering installations;\n(3) the validation, substitution and estimation of metering data for\ntypes 4A, 5 and 6 metering installations;\n(4) the calculation, estimation and substitution of metering data\nfor type 7 metering installations;\n(5) establishing and maintaining a metering data services\ndatabase associated with each metering installation and\nproviding access to the metering data services database in\naccordance with clause 7A.8.3;\n(6) the delivery of metering data and relevant NT NMI Data for a\nmetering installation in accordance with clause 7A.8.4;\n(7) the delivery to NTESMO of the following for settlements:\n(i) metering data;\n(ii) any metering register data requested by NTESMO;\n(8) the delivery to relevant financially responsible participants of\nmetering data for billing transactions;\n(9) ensuring the metering data and other data associated with the\nmetering installation is kept secure and disclosed only in\naccordance with the Rules;\n(10) maintaining the standard of accuracy of the time setting of the\nmetering installation in accordance with clause 7A.8.8;\n\nRegulations 2016 127\n(11) notifying the Metering Coordinator of any metering installation\nmalfunction in accordance with clause 7A.6.9;\n(12) management and storage of metering data in accordance with\nclause 7A.8.3; and\n(13) in respect of a metering installation that is a prepayment\ndevice, subject to paragraph (b), services required to support\nthe energisation and de-energisation of the metering\n(b) Metering Data Providers are not responsible:\n(1) for the provision of a prepayment device; or\n(2) in relation to a metering installation that is a prepayment\ndevice, unless there is an agreement with the financially\nresponsible participant to the contrary, for the provision of\nvending services.\nNote\nThe installation of prepayment devices is dealt with in clause 7A.6.14.\nThe provision of vending services for prepayment devices is dealt with in\nrule 7A.2.\n(c) Metering Data Providers may provide additional data services that\nexceed the minimum requirements of the Rules at the request of a\nrelevant financially responsible participant provided that:\n(1) the full cost of providing such additional data services is met\nby the financially responsible participant; and\n(2) the provision of additional data services does not affect the\nprovision of metering data services.\nNote\nFor example, vending services for a prepayment device could be an additional\nservice, if the financially responsible participant arranges for them to be provided\nby the Metering Data Provider, noting that in accordance with clause 7A.2(c) the\nfinancially responsible participant is responsible for ensuring that an arrangement\nfor vending services is in place.\n7A.8.2 Collection of energy data and estimation of metering data\n(a) A Metering Data Provider must, in accordance with this rule, collect\nenergy data from, and estimate metering data in respect of, a\nmetering installation at a connection point for which it has been\nappointed the Metering Data Provider.\n\nRegulations 2016 128\nScheduled meter reading\n(b) The Metering Data Provider must use reasonable endeavours to\nensure that energy data is collected from a metering installation by\nway of an actual meter reading at least once every 3 months or,\nwhere a greater frequency has been agreed with a financially\nresponsible participant, at that greater frequency.\n(c) Despite paragraph (b), the Metering Data Provider must ensure that\nenergy data is collected from a metering installation by way of an\nactual meter reading at least once every 12 months.\nSpecial meter reading\n(d) The Metering Data Provider must perform a special meter reading\n(including a final meter reading) at the request of a financially\nresponsible participant.\n(e) The Metering Data Provider may charge the financially responsible\nparticipant or retail customer (as the case may be) for the collection\nof energy data under paragraph (d) to the extent that its costs of\ncollection are higher than they would otherwise be.\nEstimated metering data\n(f) When energy data is not collected by the Metering Data Provider\nfrom a metering installation by way of an actual meter reading at\nthe applicable meter reading frequency under paragraph (b), the\nMetering Data Provider must estimate metering data for that\nmetering installation in accordance with schedule 7A.7.\n(g) Estimated metering data for the purposes of paragraph (f) must be\nprovided to the retailer within 10 business days of the scheduled\nmeter reading date under paragraph (b).\nAltering energy data\n(h) The energy data in a metering installation must not be altered\nexcept when the metering installation is reset to zero as part of a\nrepair or reprogramming.\n7A.8.3 Data management and storage\n(a) A Metering Data Provider must:\n(1) retain metering data for all relevant metering installations in\nthe metering data services database:\n(i) in electronic format for at least 13 months; and\n\nRegulations 2016 129\n(ii) following the retention under subsubparagraph (i), in an\naccessible format for at least 7 years;\n(2) archive, in an accessible format, for at least 7 years:\n(i) metering data in its original form as collected from the\n(ii) records of each substitution to metering data in respect\nof a metering installation;\n(3) enable the persons mentioned in clause 7A.13.5(c)(1) to (6) to\naccess or receive the metering data and NT NMI data in the\nmetering data services database; and\nNote\n(4) except for the persons mentioned in clause 7A.13.3(c)(1)\nto (6), ensure that no person has access to the metering data\nservices database.\nNote\n(b) A Metering Data Provider must maintain electronic data transfer\nfacilities in order to deliver metering data from the metering data\nservices database in accordance with schedule 7A.8 and\nclause 7A.8.4.\n(c) Check metering data, where available, and appropriately adjusted\nfor differences in metering installation accuracy, where applicable,\nmust be used by the Metering Data Provider to validate metering\ndata.\n(d) If the Metering Data Provider becomes aware that the metering\ndata that has been delivered into the metering database from a\nmetering data services database is incorrect, then the Metering\nData Provider must provide corrected metering data to the\nfinancially responsible participant and NTESMO within 1 business\nday of detection.\n(e) Metering data may only be altered by a Metering Data Provider,\nexcept in the preparation of settlements ready data, in which case\nNTESMO may alter the metering data in accordance with\nclause 7A.9.2(c).\n\nRegulations 2016 130\n(f) A Metering Data Provider may only alter metering data in the\nmetering data services database in accordance with schedule 7A.7.\n(g) A Metering Data Provider must arrange with the Metering\nCoordinator to obtain the relevant metering data if remote\nacquisition, if any, becomes unavailable.\n(h) A Metering Data Provider's rules and protocols for supplying\nmetering data services must be approved by NTESMO and\nNTESMO must not unreasonably withhold such approval.\n7A.8.4 Provision of metering data to certain persons\nA Metering Data Provider must give metering data and relevant NT\nNMI data to the persons mentioned in clause 7A.13.5(c)(1) to (6)\nand clause 9A.13.5(g)(1) as required by, and in accordance with,\nNote\n7A.8.5 Use of check metering data\nCheck metering data, if available and if it has been appropriately\nadjusted for differences in metering installation accuracy, must be\nused by Metering Data Providers or NTESMO, as the case may be,\nfor:\n(a) validation;\n(b) substitution; and\n(c) estimation,\nof metering data as required by clause 7A.8.1.\n7A.8.6 Periodic energy metering\n(a) Subject to paragraph (b), a Metering Data Provider must:\n(1) for type 1, 2, 3, 4, 4A and 5 metering installations, collate\nmetering data relating to:\n(i) the amount of active energy; and\n(ii) reactive energy (where relevant) passing through a\nconnection point,\n\nRegulations 2016 131\nin recording intervals within a metering data services\ndatabase; and\n(2) for type 6 metering installations, collate accumulated energy\ndata relating to an interval of up to 3 months.\n(b) However:\n(1) in relation to paragraph (a)(1):\n(i) for local electricity systems with a market administered\nby NTESMO – it may be agreed between NTESMO and\nthe financially responsible participant that metering data\nmay be recorded in sub-multiples of a recording interval\nwhere a metering installation is used for the purposes of\nsettlements; and\n(ii) for local electricity systems without a market\nadministered by NTESMO – it may be agreed between\nthe Metering Coordinator and the financially responsible\nparticipant that metering data may be recorded in sub-\nmultiples of a recording interval where a metering\ninstallation is used for the purposes of billing\ntransactions; and\n(2) in relation to paragraph (a)(2):\n(i) for local electricity systems with a market administered\nby NTESMO – it may be agreed between NTESMO and\nthe financially responsible participant that some other\nperiod will apply either on an ongoing basis or once-off\nbasis; and\n(ii) for local electricity systems without a market\nadministered by NTESMO – it may be agreed between\nthe Metering Coordinator and the financially responsible\nparticipant that some other period will apply either on an\nongoing basis or once-off basis.\n(c) A Metering Data Provider must, for type 7 metering installations,\nprepare estimated metering data relating to the amount of active\nenergy passing through a connection point in accordance with\nclause 7A.8.1(a)(4) in 3 months or, where a greater frequency has\nbeen agreed with a financially responsible participant, at that\ngreater frequency within a metering data services database.\n\nRegulations 2016 132\n7A.8.7 Verification of metering data\nMetering installations other than type 7 metering installations\n(a) A Metering Data Provider responsible for a metering installation,\nother than a type 7 metering installation, must ensure that the\nmetering data collected from the installation is validated in\naccordance with schedule 7A.7.\n(b) If validation under paragraph (a) demonstrates that there has been\na failure of the metering installation or that a measurement error\nexists:\n(1) the metering data must be substituted in accordance with\nschedule 7A.7;\n(2) the Metering Data Provider must provide the quality flag of the\nsubstituted metering data to the financially responsible\nparticipant for its record in accordance with clause S7A.7.8.4;\nand\n(3) for connection points associated with a retail customer – the\nMetering Data Provider must provide the substituted metering\ndata to the retailer so that the retailer can meet its billing\nobligations.\n(c) The Metering Data Provider:\n(1) must make a separate record of any substitution made under\nthis clause, including:\n(i) the reasons for the substitution;\n(ii) the methodology used for the substitution; and\n(iii) the substituted metering data; and\n(2) must maintain the record for at least 7 years and provide access to\nthe record at reasonable times to the relevant financially\nresponsible participant or retail customer (as the case may be).\nType 7 metering installations\nNote\nObligations relating to type 7 metering installations, including requirements for\ncalculating metering data under this clause, will only apply in this jurisdiction in\nthe event of a type 7 metering installation being available in this jurisdiction and\nafter a 12 month transitional period allowing all participants to achieve\ncompliance.\n\nRegulations 2016 133\n(d) A Metering Data Provider responsible for a type 7 metering\ninstallation must ensure that the metering data for that installation:\n(1) is calculated in accordance with the Network Service\nProvider's applicable procedure, which must be based on a\nmethodology in, or otherwise be consistent with,\n(2) is validated in accordance with schedule 7A.7.\n(e) If validation under paragraph (d)(2) demonstrates that there has\nbeen a failure of the metering installation or that a measurement\nerror exists, the Metering Data Provider must ensure the metering\ndata is substituted in accordance with schedule 7A.7.\n7A.8.8 Time settings\n(a) The Metering Provider must set the times of clocks of all metering\ninstallations with reference to Australian Central Standard Time to a\nstandard of accuracy in accordance with schedule 7A.4 relevant to\nthe load through the connection point when installing, testing and\nmaintaining metering installations.\n(b) NTESMO must ensure that the metering database clock is\nmaintained within ±1 second of Australian Central Standard Time.\n(c) The Metering Data Provider must ensure that the metering data\nservices database clock is maintained within ±1 second of\nAustralian Central Standard Time.\n(d) The Metering Data Provider must:\n(1) check the accuracy of the clock of the metering installation\nwith reference to Australian Central Standard Time to a\nstandard of accuracy in accordance with schedule 7A.4\nrelevant to the load through the connection point on each\noccasion that the metering installation is accessed;\n(2) reset the clock of the metering installation so that it is\nmaintained to the required standard of accuracy in accordance\nwith schedule 7A.4 relevant to the load through the connection\npoint if the clock error of a metering installation does not\nconform to the required standard of accuracy on any occasion\nthat the metering installation is accessed; and\n(3) notify the Metering Provider if the Metering Data Provider is\nunable to reset the clock of the metering installation in\naccordance with subparagraph (2).\n\nRegulations 2016 134\n7A.8.9 Metering data performance standards\n(a) Where required for the purposes of settlements, the Metering\nCoordinator must ensure that metering data is provided to\nNTESMO for all recording intervals where the metering installation\nhas the capability for remote acquisition of metering data, and that\nthe data is:\n(1) derived from a metering installation compliant with\n(2) provided within the timeframe for settlements required in\naccordance with jurisdictional electricity legislation;\n(3) actual or substituted in accordance with schedule 7A.7; and\n(4) provided in accordance with the performance standards\nNote\n(b) Where:\n(1) the metering installation is a type 4A metering installation, or\ndoes not have the capability for remote acquisition of metering\ndata; and\n(2) metering data is required for the purposes of settlements,\nthe Metering Coordinator must ensure that metering data is\nprovided to NTESMO and that the data is:\n(3) derived from a metering installation compliant with\n(4) provided within the timeframe required for settlements in\naccordance with jurisdictional electricity legislation;\n(5) actual, substituted or estimated in accordance with\n(6) provided in accordance with the performance standards\nNote\n\nRegulations 2016 135\n(c) The Metering Coordinator must ensure that, for all metering\ninstallations used for billing transactions, metering data is provided\nto the financially responsible participant for all recording intervals\nwhere the metering installation has the capability for remote\nacquisition of metering data, and that the data is:\n(1) derived from a metering installation compliant with\n(2) provided to the financially responsible participant every\n35 days for billing transactions unless it has been agreed\nbetween the Metering Coordinator and the financially\nresponsible participant that some other timeframe will apply;\n(3) actual or substituted in accordance with schedule 7A.7; and\n(4) provided in accordance with the performance standards\nNote\n(d) For type 6 metering installations, metering data relating to the\namount of active energy passing through a connection point must\nbe provided to the financially responsible participant:\n(1) every 3 months; or\n(2) where a greater frequency has been agreed with the\nfinancially responsible participant – at that greater frequency.\n7A.9 Metering data and data base\n7A.9.1 Metering database\n(a) NTESMO must create, maintain and administer a metering\ndatabase (either directly or under a contract for provision of the\ndatabase) containing information for each metering installation\nregistered with NTESMO.\n(b) The metering database must include metering data, settlements\nready data, and information for each metering installation registered\nwith NTESMO in accordance with this rule 7A.9.\n(c) NTESMO:\n(1) must enable the persons referred to in clause 7A.13.5(c)(1)\nto (4) and clause 7A.13.5(f)(1) to access or receive data in the\nmetering database; and\n\nRegulations 2016 136\n(2) except as specified in subparagraph (1), must ensure that no\nother person has access to the metering database.\n(d) For all types of metering installations, the metering database must\ncontain metering data that is:\n(1) retained in an electronic format for at least 13 months; and\n(2) following the retention under subparagraph (1), archived in an\naccessible format for an overall period of not less than\n7 years.\n(e) The settlements ready data held in the metering data base must be\nused by NTESMO for settlement purposes.\n(f) The settlements ready data held in the metering database may be\nused by Distribution Network Service Providers for the purpose of\ndetermining distribution service charges in accordance with\nclause 6.20.1.\n(g) NTESMO must retain settlements ready data for all metering\ninstallations for at least 7 years.\n(h) Despite anything to the contrary in this Rule, NTESMO may provide\nthe energy ombudsman with metering data relating to a Registered\nParticipant from a metering installation, the metering database, or\nthe metering register, if the energy ombudsman has received a\ncomplaint to which the data is relevant from a retail customer of the\nRegistered Participant.\n(i) NTESMO must notify the relevant Registered Participant of any\ninformation requested by the energy ombudsman under\nparagraph (h) and, if it is requested by that Registered Participant,\nsupply the Registered Participant with a copy of any information\nprovided to the energy ombudsman.\n7A.9.2 Data validation, substitution and estimation\n(a) If NTESMO in the preparation of settlements ready data detects\nmetering data that fails validation NTESMO must notify the\nMetering Data Provider within 1 business day of detection.\n(b) Where a Metering Data Provider receives notification under\nparagraph (a), the Metering Data Provider must use its best\nendeavours to provide corrected metering data to NTESMO within\n1 business day or advise NTESMO that this time limit cannot be\nachieved, and the reason for delay, in which case the parties must\nagree on a revised time limit by which the corrected metering data\nwill be provided.\n\nRegulations 2016 137\n(c) Where metering data fails validation by NTESMO in the preparation\nof settlements ready data and replacement metering data is not\navailable within the time required for settlements then NTESMO\nmust prepare a substitute value in accordance with\nschedule S7A.7.\n7A.9.3 Changes to energy data or to metering data\n(a) The Metering Coordinator must ensure that energy data held in a\nmetering installation is not altered except when the meter is reset to\nzero as part of a repair or reprogramming.\n(b) If an on-site test of a metering installation requires the injection of\ncurrent, the Metering Coordinator must ensure that:\n(1) the energy data stored in the metering installation is\ninspected;\n(2) if necessary following the inspection under subparagraph (1),\nalterations are made to the metering data, to ensure that the\nmetering data in the metering data services database and the\nmetering database is not materially different from the energy\nconsumed at that connection point during the period of the\ntest.\n(c) If a Metering Coordinator considers alterations are necessary under\nparagraph (b)(2), the Metering Coordinator must:\n(1) for local electricity systems with a market operated by\nNTESMO, notify NTESMO that alteration to the metering data\nis necessary; and\n(2) advise the financially responsible participant of the need to\nchange the metering data, and the Metering Coordinator must\narrange for the Metering Data Provider to:\n(i) alter the metering data for the connection point held in\nthe metering data services database in accordance with\nthe validation, substitution and estimation procedures in\n(ii) provide the altered metering data to the persons who\nreceive that metering data under clause 7.13.5(c).\n\nRegulations 2016 138\n(d) If a test referred to in paragraph (b) is based on actual connection\npoint loads, no alteration is required.\nNote\n7A.10 Register of metering information\n7A.10.1 Metering register\n(a) As part of the metering database, NTESMO must maintain a\nmetering register of all metering installations and check metering\ninstallations which provide metering data for settlements.\n(b) The metering register referred to in paragraph (a) must contain the\ninformation specified in Schedule 7A.1.\n7A.10.2 Metering installation registration process\n(a) For the purpose of maintaining the metering register, NTESMO\nmust establish, maintain and publish a registration process in\nrespect to the following (where metering data provided is used for\nsettlements):\n(1) new metering installations;\n(2) modifications to existing metering installations; and\n(3) decommissioning of metering installations.\n7A.10.3 Metering register discrepancy\n(a) If the information in the metering register indicates that the metering\ninstallation or the check metering installation does not comply with\nthe requirements of the Rules, NTESMO must advise affected\nRegistered Participants of the discrepancy.\n(b) The Metering Coordinator must arrange for the discrepancy to be\ncorrected within 2 business days of receipt of notification under\nparagraph (a) unless otherwise agreed by NTESMO.\nDiscrepancies between database and other data\n(c) If there is a discrepancy between energy data held in a metering\ninstallation and data held in the metering database:\n(1) the affected Metering Coordinator and NTESMO must liaise\ntogether to determine the most appropriate way to resolve the\ndiscrepancy; and\n\nRegulations 2016 139\n(2) for the purposes of this Chapter the energy data for the\nmetering point in the metering installation is to be taken to be\ncorrect, unless it is proven to be incorrect.\n(d) If there is a discrepancy between information held in a metering\nregister and the same category of information in any other\ndatabase, then for the purposes of this Chapter the information\nrecorded in the metering register is to be taken to be correct, unless\nit is proven to be incorrect.\nMetering Coordinators must keep the registry accurate\n(e) If a Metering Coordinator becomes aware of a change to, or an\ninaccuracy in, information in the metering register, then it must as\nsoon as practicable and no later than 2 business days after the day\nit becomes aware of the change or inaccuracy notify NTESMO and\nprovide details of the change to, or inaccuracy in, the information.\nNTESMO may amend metering register\n(f) If NTESMO is notified of an inaccuracy in information by a Metering\nCoordinator or other Registered Participant in relation to the\nconnection point it is financially responsible for, NTESMO must\nundertake investigations to the standard of good industry practice to\ndetermine whether the metering register should be updated.\n(g) If NTESMO determines that the metering register should be\nupdated as a result of an investigation conducted in accordance\nwith paragraph (a), NTESMO must update the registry to reflect the\nchange to, or correct the inaccuracy in, the information.\n(h) If information for a connection point is updated in the metering\nregister, NTESMO must, within 2 business days after the update,\nnotify the update to:\n(1) the financially responsible participant; and\n(2) if the financially responsible participant is a retailer and there\nwas a change in retailer, the previous retailer where that\nupdated information relates to a period or periods when the\nprevious retailer was the retailer for that connection point.\nNote\nIn paragraph (h)(2), references to \"previous retailer\" means a retailer who was\npreviously recorded in the metering register as the financially responsible\nparticipant for the connection point referred to in paragraph (h).\n\nRegulations 2016 140\n7A.11 Disclosure of information\n7A.11.1 Provision of data to retailers\nNMI and NMI checksum\n(a) A Distribution Network Service Provider must, at the request of a\nretailer, and within 1 business day of the date of the request,\nprovide the retailer with the NMI and NMI checksum for premises\nidentified in the request by reference to:\n(1) a unique meter identifier held by the Distribution Network\nService Provider;\n(2) a street address; or\n(3) the code used by Australia Post to provide a unique identifier\nfor postal addresses.\n(b) If a computer search by the Distribution Network Service Provider\ndoes not produce a unique match for the information provided by\nthe retailer, the Distribution Network Service Provider must provide\nthe retailer with any computer matches achieved up to a maximum\nof 99.\nNT NMI Data\n(c) A Distribution Network Service Provider must, at the request of a\nretailer, and within 2 business days of the date of the request,\nprovide the retailer with the NT NMI Data for premises identified in\nthe request by reference to the NMI for the premises.\n7A.12 Metering data provision to retail customers\nNote\nThe application of this rule will be revisited as part of the phased implementation\nPart F Security of metering installations and energy\ndata\n7A.13 Security of metering installations, energy data and\n7A.13.1 Confidentiality of data\n(a) Energy data, metering data, NT NMI data, information in the\nmetering register and passwords are confidential and must be\ntreated as confidential information in accordance with the Rules.\n\nRegulations 2016 141\n(b) For the purposes of clause 8.6.2(c), metering data from a metering\ninstallation at a retail customer's connection point is deemed to\nhave been provided by the retail customer.\n7A.13.2 Security of metering installations\nGeneral security\nthe metering installation is secure and that associated links, circuits\nand information storage and processing systems are protected by\nappropriate security mechanisms.\nNote\n(b) In respect of a connection point used for settlements, NTESMO\nmay override any of the security mechanisms fitted to a metering\ninstallation with prior notice to the Metering Coordinator.\nBroken seals\n(c) If a Network Service Provider, financially responsible participant,\nMetering Provider or Metering Data Provider becomes aware that a\nseal protecting metering equipment has been broken, it must notify\nthe Metering Coordinator within 5 business days.\n(d) If a broken seal has not been replaced by the person who notified\nthe Metering Coordinator under paragraph (c), the Metering\nCoordinator must ensure that the broken seal is replaced no later\nthan:\n(1) the first occasion on which the metering equipment is visited\nto take a reading; or\n(2) 100 days,\nafter receipt of notification that the seal has been broken.\n(e) The costs of replacing broken seals as required by paragraph (d)\nare to be borne by:\n(1) the financially responsible participant if the seal was broken by\na retail customer of the financially responsible participant;\n(2) a Registered Participant if the seal was broken by the\nRegistered Participant;\n\nRegulations 2016 142\n(3) the Metering Provider if the seal was broken by the Metering\nProvider;\n(4) the Metering Data Provider if the seal was broken by the\nMetering Data Provider; or\n(5) otherwise by the Metering Coordinator.\n(f) If it appears that, as a result of, or in connection with, the breaking\nof a seal mentioned in paragraph (c) the relevant metering\nequipment may no longer meet the relevant minimum standard, the\nMetering Coordinator must ensure that the metering equipment is\ntested in accordance with clause 7A.7.2.\n7A.13.3 Security controls for energy data\nenergy data held in the metering installation is protected from local\naccess and remote access by suitable password and security\ncontrols.\nNote\n(b) The Metering Provider must keep records of passwords secure.\nNote\n(c) The Metering Provider must allocate suitable passwords to the\nMetering Data Provider to enable the Metering Data Provider to\ncollect the energy data and maintain the clock of the metering\ninstallation in accordance with clause 7A.8.7.\n(d) The Metering Data Provider must keep all metering installation\npasswords secure and not make the passwords available to any\nother person.\nNote\n\nRegulations 2016 143\n7A.13.4 Additional security controls for type 4 metering installations\nIn respect of a type 4 metering installation:\n(a) the Metering Coordinator must ensure that access to energy\ndata held in the metering installation is given only:\n(1) to a person who is permitted to have access to it under\nthe Rules; and\n(2) for a purpose that is permitted under the Rules;\n(b) the Metering Coordinator must ensure that access to services\nprovided by the metering installation and metering data from\nthe metering installation is given only:\n(1) in respect of:\n(i) a remote disconnection service and the metering\ndata in connection with that service – to the Local\nNetwork Service Provider and the financially\nresponsible participant;\n(ii) a remote reconnection service and the metering\ndata in connection with that service – to the Local\nNetwork Service Provider, the financially\nresponsible participant and the incoming retailer;\n(iii) a remote on-demand meter reading service and the\nRegistered Participants with a financial interest in\nthe metering installation or the energy measured by\nthat metering installation and a person to whom a\nsubparagraph (3)(ii);\n(iv) a remote scheduled meter reading service and the\nRegistered Participants with a financial interest in\nthe metering installation or the energy measured by\nthat metering installation and a person to whom a\nsubparagraph (3)(ii);\n(v) a metering installation inquiry service and the\nthe Local Network Service Provider, the financially\nresponsible participant and a person to whom a\nsubparagraph (3)(ii); and\n\nRegulations 2016 144\n(vi) an advanced meter reconfiguration service and the\nthe Local Network Service Provider and the\nfinancially responsible participant;\n(2) to a person who is permitted to have access to it under\nthe Rules and for a purpose that is permitted under the\nRules; or\n(3) except as otherwise specified in subparagraph (1) or (2):\n(i) to the Local Network Service Provider, but only to\nthe extent that, in the Metering Coordinator's\nreasonable opinion, the access is reasonably\nrequired by the Local Network Service Provider to\nenable it to meet its obligations to provide a safe,\nreliable and secure network; or\n(ii) to a person and for a purpose to which the retail\ncustomer has given prior consent;\n(c) the Metering Coordinator must ensure that the services\nprovided by the metering installation are protected from local\naccess and remote access by suitable password and security\ncontrols in accordance with paragraph (e);\n(d) the Metering Provider must keep records of passwords\nsecure; and\n(e) the Metering Provider must:\n(1) forward a copy of a password allowing local access and\na copy of a password allowing remote access to the\nmetering installation, services provided by the metering\ninstallation and energy data held in the metering\ninstallation, to the Metering Coordinator, Metering Data\nProvider and NTESMO; and\n(2) ensure that no other person receives or has access to a\ncopy of a password allowing local access or remote\naccess to the metering installation, services provided by\nthe metering installation or energy data held in the\nNote\n\nRegulations 2016 145\n7A.13.5 Access to data\n(a) Access to energy data recorded by a metering installation must only\nbe given if passwords are allocated in accordance with\nclause 7A.13.3.\n(b) The Metering Coordinator must ensure that access to energy data\nfrom the metering installation is scheduled appropriately to ensure\nthat congestion does not occur.\n(c) Subject to this clause, the only persons entitled to access or receive\nmetering data, settlements ready data, NT NMI data or data from\nthe metering register for a metering installation are:\n(1) the financially responsible participant in respect of the\nconnection point for the metering installation and any other\nRegistered Participant with a financial interest in the metering\ninstallation or the energy measured by the metering\n(2) the Metering Coordinator appointed in respect of the\nconnection point for the metering installation;\n(3) the Metering Provider appointed with respect to the metering\n(4) the Metering Data Provider appointed with respect to the\nmetering installation;\n(5) NTESMO and its authorised agents;\n(6) the Local Network Service Provider associated with the\nconnection point; and\n(7) the AER and the Utilities Commission.\n(d) In addition to the persons mentioned in paragraph (c), the following\npersons may access or receive metering data in accordance with\nthe Rules:\n(1) a retail customer or customer authorised representative, upon\nrequest by that retail customer or its customer authorised\nrepresentative to the retailer or Distribution Network Service\nProvider in relation to that retail customer's metering\n(2) the energy ombudsman.\n\nRegulations 2016 146\n(e) A retailer or Distribution Network Service Provider must, upon\nrequest by a retail customer or its customer authorised\nrepresentative under paragraph (d)(1), provide information about\nthe retail customer's energy consumption for the previous 2 years.\n(f) Without limiting this clause:\n(1) a retailer is entitled to access or receive NT NMI data;\n(2) a customer authorised representative may receive metering\ndata; and\n(3) a retailer or a Distribution Network Service Provider may\naccess or receive metering data or provide metering data to a\ncustomer authorised representative,\nafter having first done whatever may be required, if relevant, under\nany applicable privacy legislation and clause 7A.9.5 including, if\nappropriate, making relevant disclosures or obtaining relevant\nconsents from retail customers.\n(g) For the avoidance of doubt and without limiting this clause:\n(1) a Metering Data Provider must provide relevant NT NMI data\nto a Distribution Network Service Provider to the extent that\nNT NMI data is required for the Distribution Network Service\nProvider to fulfil its obligations under this Chapter 7A of the\nRules; and\n(2) a Distribution Network Service Provider is authorised to, and\nmust provide, relevant NT NMI data to a Metering Data\nProvider to the extent that NT NMI data is required for the\nMetering Data Provider to fulfil its obligations under this\nChapter 7A of the Rules.\nSchedule 7A.1 Metering register\nS7A.1.1 General\nThe metering register forms part of the metering database and\nholds static metering information associated with metering\ninstallations defined by the Rules that determine the validity and\naccuracy of metering data.\nS7A.1.2 Metering register information\nMetering information to be contained in the metering register must\ninclude, but is not limited to, the following:\n(a) serial numbers;\n\nRegulations 2016 147\n(b) the metering installation identification name; and\n(c) the information required to assign loss factors.\nS7A.1.3 Communication guideline\n(a) NTESMO must develop, maintain and publish a communication\nguideline in accordance with the Rules consultation procedures.\n(b) A communication guideline must be in place at all times.\n(c) The communication guideline is intended to set out specific details\nas to how metering and energy data and other information\nexchange processes will be implemented.\n(d) The communication guideline must:\n(1) specify, or incorporate by reference, detailed technical\nspecifications (including file formats, protocols and\ntimeframes) as to how data and information communication is\nto be processed, and how the necessary information systems\nare to be designed and developed; and\n(2) be sufficient to enable a Registered Participant to design and\ncommission the information systems necessary for it to\nengage in communications with NTESMO for the purposes of\n(e) The communication guideline may include types of metering\ninformation that must be included in the metering register.\nSchedule 7A.2 Metering provider\nNote\nThe detail of this schedule will be considered as part of the phased\nSchedule 7A.3 Metering data provider\nNote\nThe detail of this schedule will be considered as part of the phased\nSchedule 7A.4 Types and accuracy of metering installations\nS7A.4.1 General requirements\nThis schedule sets out the minimum requirements for metering\n\nRegulations 2016 148\nS7A.4.2 Accuracy requirements for metering installations\nTable S7A.4.2.1 Overall accuracy requirements of metering\ninstallation components\nType\nVolume\nlimit per\nannum per\nconnection\npoint\nMaximum\nallowable overall\nerror (±%) at full\nload (Item 6)\nMinimum\nacceptable\nclass or\nstandard of\ncomponents\nclock error\n(seconds) in\nreference to\nACST\nactive reactive\n1 greater\nthan\n0.5 1.0 0.2CT/VT/meter\nWh\n0.5 meter varh\n±5\n2 100 to\n1.0 2.0 0.5CT/VT/meter\nWh\n1.0 meter varh\n±7\n3 0.75 to less\nthan\n100 GWh\n1.5 3.0 0.5CT/VT\n1.0 meter Wh\n2.0 meter varh\n±10\n4 less than\n750 MWh\n(Item 2)\n1.5 n/a Either 0.5 CT and\n1.0 meter Wh; or\nwhole current\n7A.6.2(a)(9) and\n7A.8.9(a)\n±20\n4A less than x\nMWh\n(Item 3)\n1.5 3.0 Either 0.5 CT and\n1.0 meter Wh;\nor whole current\n7A.6.2(a)(10) and\n7A.8.9(b)\n±20\n\nRegulations 2016 149\nType\nVolume\nlimit per\nannum per\nconnection\npoint\nMaximum\nallowable overall\nerror (±%) at full\nload (Item 6)\nMinimum\nacceptable\nclass or\nstandard of\ncomponents\nclock error\n(seconds) in\nreference to\nACST\nactive reactive\n5 less than x\nMWh\n(Item 3)\n1.5 n/a Either 0.5 CT and\n1.0 meter Wh; or\nwhole current\n7A.6.2(a)(10) and\n7A.8.9(b).\n‘±/-20'\n6 less than y\nMWh\n(Item 4)\n2.0 n/a CT or whole\ncurrent general\npurpose meter\nWh recording\naccumulated\nenergy data only.\nProcesses used\nto convert the\naccumulated\ninto recording\ninterval metering\ndata and\nestimated\nwhere necessary\nare included in\nschedule 7A.7.\n7 volume limit\nnot\nspecified\n(Item 5)\n(Item 6) n/a No meter. The\nmetering data is\ncalculated\ndetermined in\naccordance with\nschedule 7A.7.\nn/a\n\nRegulations 2016 150\nItem 1: (a) For a type 3, 4, 4A, 5 and 6 metering installation, whole\ncurrent meters may be used if the meters meet the\nrequirements of the relevant Australian Standards and\nInternational Standards identified in schedule 7A.7.\n(b) The metering installation types referred to in paragraph (a)\n(including any transitional arrangements) specified by the\nNational Measurement Institute under the National\nMeasurement Act.\nItem 2: High voltage customers that require a voltage transformer and\nwhose annual consumption is below 750 MWh, must meet the\nrelevant accuracy requirements of Type 3 metering for active\nenergy only.\nItem 3: In relation to a type 4A and type 5 metering installation, the value\nof ‘x' in this jurisdiction is 0 MWh per annum.\nItem 4: The following requirements apply in relation to a type 6 metering\n(1) the value of ‘y' in this jurisdiction is 750 MWh per annum;\n(2) devices within the metering installation may record\naccumulated energy data in predetermined daily time periods\nwhere such time periods are specified in schedule 7A.7.\nItem 5: (a) A type 7 metering installation classification applies where a\nmetering installation does not require a meter to measure the\nflow of electricity in a power conductor and accordingly there\nis a requirement to determine by other means the metering\ndata that is deemed to correspond to the flow of electricity in\nthe power conductor.\n(b) The condition referred to in paragraph (a) will only be allowed\nfor a connection point if:\n(1) the operation of an unmetered device at the\nconnection point results in a type of\nunmetered load that is authorised under the\nterms of a local instrument; and\n(2) NTESMO in consultation with Metering\nCoordinator determines:\n(i) that the load pattern is predictable;\n(ii) that, for the purposes of settlements, the\nload pattern can be reasonably\ncalculated by a relevant method set out\nin schedule S7A.7; and\n\nRegulations 2016 151\n(iii) that it would not be cost effective to\nmeter the connection point taking into\naccount:\n(A) the small magnitude of the load;\n(B) the connection arrangements; and\n(C) the geographical and physical\nlocation.\nNote\nThe effect of paragraph (b) is that if a type of\nunmetered load is authorised under a local\ninstrument, a connection point with that type of\nunmetered load may be used for the purposes of\nsettlements, and be eligible for a type 7 metering\ninstallation, if NTESMO makes a determination\nunder (b)(2) in relation to that connection point.\nThe National Electricity (Northern Territory) (National\nUniform Legislation) (Modification) Regulations 2016\nare an example of a local instrument.\n(c) A connection point that meets the condition for classification\nas a type 7 metering installation does not prevent that\nconnection point from being subject to metering in the future.\nItem 6: The maximum allowable overall error (±%) at different loads and\npower factors is set out in Tables S7A.4.2.2 to S7A.4.2.6.\nTable S7A.4.2.2 Type 1 installation – Annual energy throughput greater\nthan 1 000GWh\n%\nLoad\n10 1.0% 1.0% 2.0% n/a n/a 1.4%\n50 0.5% 0.5% 1.0% 0.7% 1.4% 1.0%\n100 0.5% 0.5% 1.0% n/a n/a 1.0%\n\nRegulations 2016 152\nTable S7A.4.2.3 Type 2 installation – Annual energy throughput between 100 and\n%\nLoad\n10 2.0% 2.0% 4.0% n/a n/a 2.8%\n50 1.0% 1.0% 2.0% 1.5% 3.0% 2.0%\n100 1.0% 1.0% 2.0% n/a n/a 2.0%\nTable S7A.4.2.4 Type 3 installation – Annual energy throughput from\n0.75 GWh to less than 100 GWh and Type 4A installation – annual energy\nthroughput less than 0.75 GWh\n%\nLoad\n10 2.5% 2.5% 5.0% n/a n/a 4.0%\n50 1.5% 1.5% 3.0% 2.5% 5.0% 3.0%\n100 1.5% 1.5% 3.0% n/a n/a 3.0%\nTable S7A.4.2.5 Type 4 or 5 installation – annual energy throughput less\nthan 0.75GWh\n% Rated Load Power Factor\nUnity 0.866 lagging 0.5 lagging\nActive Active Active\n10 2.5% 2.5% n/a\n50 1.5% 1.5% 2.5%\n100 1.5% 1.5% n/a\n\nRegulations 2016 153\nTable S7A.4.2.6 Type 6 installation – annual energy throughput less than\n0.75 GWh\n% Rated Load Power Factor\nUnity 0.866 lagging 0.5 lagging\nActive Active Active\n10 3.0% n/a n/a\n50 2.0% n/a 3.0%\n100 2.0% n/a n/a\nNotes to Tables S7A4.2.2 to S7A4.2.6\nAll measurements in Tables S7A4.2.2 to S7A4.2.6 are to be referred to 24\ndegrees Celsius.\n(a) The method for calculating the overall error is the vector sum of the errors of\neach component part (that is, a + b + c) where:\na = the error of the voltage transformer and wiring;\nb = the error of the current transformer and wiring; and\nc = the error of the meter.\n(b) If compensation is carried out then the resultant metering data error must be\nas close as practicable to zero.\nS7A.4.3 Check metering\n(a) Where a check metering installation is in place, it is to be applied in\naccordance with the following Table:\nMetering Installation Type in\naccordance with Table S7A.4.2.1\nCheck Metering Requirements\n1 Check metering installation\n2 Partial check metering\n3 No requirement\n4, 4A, 5 and 6 No requirement\n(b) Where a check metering installation is not in place, and a financially\nresponsible participant requests the installation of a check metering\ninstallation at a connection point, the Metering Coordinator at the\nconnection point must arrange for the installation of a check\nmetering installation that complies with the requirements of this\nschedule.\n\nRegulations 2016 154\n(c) A check metering installation involves either:\n(1) the provision of a separate metering installation using\nseparate current transformer cores and separately fused\nvoltage transformer secondary circuits, preferably from\nseparate secondary windings; or\n(2) if NTESMO, in its absolute discretion, considers it appropriate,\nin the case of a metering installation located at the facility at\none end of the two-terminal link, a metering installation located\nat the facility at the other end of a two-terminal link.\n(d) Where the check metering installation duplicates the metering\ninstallation and accuracy level, the average of the 2 validated data\nsets will be used to determine the energy measurement.\n(e) Partial check metering involves the use of other metering data or\noperational data available in 30 min electronic format as part of a\nvalidation process in accordance with Schedule 7A.7.\n(f) Check metering installations may be supplied from secondary\ncircuits used for other purposes and may have a lower level of\naccuracy than the metering installation, but must not exceed twice\nthe level prescribed for the metering installation.\n(g) The physical arrangement of partial check metering will be\ndetermined by the Metering Coordinator.\nS7A.4.4 Resolution and accuracy of displayed or captured data\nProgrammable settings available within a metering installation of\nany peripheral device, which may affect the resolution of displayed\nor stored data, must:\n(a) meet the requirements of the relevant Australian Standards\nand International Standards specified in schedule 7A.7; and\n(b) comply with any applicable specifications or guidelines\n(including any transitional arrangements) specified by the\nNational Measurement Institute under the National\nMeasurement Act.\n\nRegulations 2016 155\nS7A.4.5 General design standards\nS7A.4.5.1 Design requirements\nWithout limiting the scope of detailed design, the following\nrequirements must be incorporated in the design of each metering\n(a) for metering installations greater than 1 000 GWh pa per\nconnection point, the current transformer core and secondary\nwiring associated with the meter(s) must not be used for any\nother purpose;\n(b) for metering installations less than 1 000 GWh pa per\nconnection point, the current transformer core and secondary\nwiring associated with the meter(s) may be used for other\npurposes (for example, local metering or protection) provided\nthe Metering Coordinator is able to demonstrate that the\naccuracy of the metering installation is not compromised and\nsuitable procedures/measures are in place to protect the\nsecurity of the metering installation;\n(c) where a voltage transformer is required, if separate secondary\nwindings are not provided, then the voltage supply to each\nmetering installation must be separately fused and located in\nan accessible position as near as practical to the voltage\ntransformer secondary winding;\n(d) secondary wiring must be by the most direct route and the\nnumber of terminations and links must be kept to a minimum;\n(e) the incidence and magnitude of burden changes on any\nsecondary winding supplying the metering installation must be\nkept to a minimum;\n(f) meters must:\n(1) meet the requirements of relevant Australian Standards\nand International Standards (if any) specified in\n(2) have a valid pattern approval issued under the authority\nof the National Measurement Institute or, until relevant\npattern approvals exist, a valid type test certificate;\n(g) new instrument transformers must:\n(1) meet the requirements of relevant Australian Standards\nand International Standards (if any) specified in\n\nRegulations 2016 156\n(2) have a valid pattern approval issued under the authority\nof the National Measurement Institute or, until relevant\npattern approvals exist, a valid type test certificate;\n(h) suitable isolation facilities are to be provided to facilitate\ntesting and calibration of the metering installation;\n(i) suitable drawings and supporting information, detailing the\nmetering installation, must be available for maintenance\npurposes.\nS7A.4.5.2 Design guidelines\nIn addition to the design requirements specified in clause S7A.5.1,\nthe following guidelines should be considered for each metering\n(a) the provision of separate secondary windings for each\nmetering installation where a voltage transformer is required;\n(b) a voltage changeover where more than one voltage\ntransformer is available.\nSchedule 7A.5 Metering functionality requirements for type 1,\n2, 3 and 4 metering requirements\nS7A.5.1 Introduction\nS7A.5.1.1 Purpose\nThis schedule specifies the meter functionality requirements for\ntype 1, 2, 3 and 4 metering installations in this jurisdiction.\nS7A.5.1.2 Definitions\ncommunications network means all communications equipment,\nprocesses and arrangements that lie between the meter and the\nNMS.\nend user customer means the customer or retail customer who\nconsumes electricity at the point of use.\nexport means the delivery of energy from the network to an end-\nuse customer.\nimport means the delivery of energy from an end-use customer\ninto a distribution network.\n\nRegulations 2016 157\nlocal disconnection means the operation of the supply contactor\nto effect a disconnection of supply performed locally at the meter by\nalternative electronic means.\nmetering system means the installed metering installation,\ncommunications network or infrastructure, and any other systems\nrequired under this schedule.\nNMS (Network Management System) means the component of a\nmetering system that manages the communications network.\nremote disconnection means the utilisation of the communication\nsystem to disconnect the end-use customer's supply at the meter\nby the operation of a contactor.\nsupply contactor means the contactor in the meter that, when\nopened, causes the supply to be disconnected and, when closed,\nallows the supply to become connected.\ntotal accumulated energy means the total or accumulated amount\nof energy measured and recorded per channel of a meter since the\ninstallation of the meter or the resetting of the value.\nS7A.5.2 Functionality Requirements for Meters in Type 1, 2,\nand 3 metering installations\nS7A.5.2.1 Application\nClause S7A.5.2 applies to meters in type 1, 2 and 3 metering\nS7A.5.2.2 Applicable meter configurations\n(a) The configuration for a meter must be:\n(1) three phase Low Voltage CT connect (excluding supply\ncontactor); or\n(2) three phase CT/VT.\n(b) Meters must meet the relevant requirements of AS 62052.11,\nAS 62053.22 and AS 62053.21, and any pattern approval\nrequirements of the National Measurement Institute.\n\nRegulations 2016 158\nS7A.5.2.3 Metrology\nMeters must comply with the following requirements:\n(a) three phase meters must be four quadrant meters and must\nbe able to separately record active energy and reactive\nenergy, import and export in recording intervals;\n(b) meters must record total accumulated energy for each\nrecorded channel of interval data;\n(c) the resolution for collection of interval energy data must be at\nleast 0.1 kWh for active energy and 0.1 kVArh for reactive\nenergy;\n(d) meters must have a minimum storage of 35 days per channel\nof interval energy data;\n(e) all channels of interval energy data must be able to be read\nlocally as well as remotely read;\n(f) it must be possible to remotely and locally select or configure\nwhether import interval energy data is recorded or not;\n(g) it must be possible to remotely and locally select or configure\nwhether reactive energy interval energy data is recorded from\nthree phase meters or not.\nS7A.5.3 Functionality Requirements for Meters in Type 4\nS7A.5.3.1 Application\nClause S7A.5.3 applies to meters in type 4 metering installations.\nS7A.5.3.2 Applicable meter configurations\n(a) The configuration for a meter must be:\n(1) single phase, single element;\n(2) single phase, two element;\n(3) three phase direct connect; or\n(4) three phase CT connect (excluding supply contactor).\n(b) Meters must meet the relevant requirements of AS 62052.11,\nAS 62053.22 and AS 62053.21, and any pattern approval\nrequirements of the National Measurement Institute.\n\nRegulations 2016 159\nS7A.5.3.3 Metrology\nMeters must comply with the following requirements:\n(a) single phase meters must be two quadrant meters and must\nbe able to separately record active energy for import and\nexport in recording intervals;\n(b) three phase meters must be four quadrant meters and must\nbe able to separately record active energy and reactive\nenergy, import and export in recording intervals;\n(c) meters must record total accumulated energy data for each\nrecorded channel of interval energy data;\n(d) the resolution for collection of interval energy data must be at\nleast 0.1 kWh for active energy and 0.1 kVArh for reactive\nenergy;\n(e) the resolution of energy consumption displayed on a meter's\ndisplay must be at least 0.1 kWh and 0.1 kVArh for direct\nconnected meters;\n(f) meters must have a minimum storage of 200 days per channel\nof interval energy data;\n(g) all channels of interval energy data must be able to be read\nlocally as well as by remote acquisition;\n(h) the values that must be recorded for import and export are the\nactual values at the connection point for direct connect\nmeters;\n(i) it must be possible to remotely and locally select or configure\nwhether import interval energy data is recorded or not;\n(j) it must be possible to remotely and locally select or configure\nwhether reactive energy interval energy data is recorded from\nthree phase meters or not.\nExport is when energy is exported from the network to a customer and import is\nwhen the customer delivers energy into the network. See clause S7A5.1.2.\n\nRegulations 2016 160\nS7A.5.3.4 Remote and local reading of meters\n(a) If a meter is remotely read:\n(1) the meter's total accumulated energy data per collected\nchannel must be able to be collected once every 24 hours;\nand\n(2) the interval energy data per collected channel must be able to\nbe collected once every 24 hours.\n(b) If a meter is locally read, the meter's total accumulated energy per\ncollected channel and the interval energy data per collected\nchannel must be able to be collected.\n(c) For individual reads of meters, it must be possible to select up to 35\ndays of interval energy data to be collected per channel.\nS7A.5.3.5 Supply disconnection and reconnection\nS7A.5.3.5.1 General requirements\n(a) Meters excluding CT connected meters must have a supply\ncontactor.\n(b) Meters must support both local and remote disconnect, and local\nand remote reconnection of end-use customer supply via the supply\ncontactor. When a meter performs a disconnection operation, all\noutgoing circuits from the meter must be disconnected.\n(c) To confirm the current state of a meter, the meter must support\n\"on-demand\" remote polling of the meter to determine whether the\nsupply contactor is open or closed.\n(d) A meter must provide clear local visual indication of the status\n(open/closed) of the supply contactor.\nS7A.5.3.5.2 Disconnection\n(a) A meter must support both local and remote end-use customer\nsupply disconnection functionality.\nLocal disconnection\nThe circumstances in which local disconnection may occur include where:\n(a) a technician is already on-site performing works and it is most efficient for the\ntechnician to perform the disconnection; or\n(b) a meter that is capable of remote reading is installed; however the\ncommunications infrastructure has not been rolled out or has failed.\n\nRegulations 2016 161\n(b) Local disconnection via the meter must only be able to be\nperformed by an authorised technician. Unauthorised persons must\nbe physically prevented from operating the supply contactor to\ndisconnect supply.\n(c) A meter must support the following:\n(1) opening of the supply contactor performed locally;\n(3) event logging of the local disconnection at that meter.\nRemote disconnection\n(d) A meter must support the following:\n(1) opening of the supply contactor performed remotely;\n(3) event logging of the remote disconnection at that meter.\nS7A.5.3.5.3 Reconnection\n(a) A meter must support both local and remote end-use customer\nsupply reconnection functionality.\nLocal reconnection\n(b) Reconnection via the meter must only be able to be performed\nlocally by an authorised technician. Unauthorised persons must be\nphysically prevented from operating the supply contactor to\nreconnect supply.\n(c) A meter must support the following:\n(1) closing of the supply contactor performed locally;\n(3) event logging of local reconnection at that meter.\n\nRegulations 2016 162\nRemote reconnection\n(d) A meter must support the following:\n(1) closing of the supply contactor performed remotely;\nsupply contactor from the meter to the NMS; and\n(3) event logging of remote reconnection.\nS7A.5.3.6 Time clock synchronisation\nDate and time within meters must be maintained within 20 seconds\nof Australian Central Standard Time.\nS7A.5.3.7 Quality of Supply and other event recording\n(a) A meter must support the recording of Quality of Supply (QoS)\nevents and other events that occur at each meter as detailed as\nfollows:\nID Events\n1 Import energy detected\n2 Supply contactor opened – local\n3 Supply contactor opened – remote\n4 Supply contactor closed – local\n5 Supply contactor closed – remote\n6 Undervoltage event\n7 Overvoltage event\n8 Tamper detected\n9 Whenever there is a change of meter settings\nlocally\nUndervoltage and overvoltage recording\n(b) A meter must support the recording of undervoltage and\novervoltage events. The thresholds shall be remotely and locally\nsettable for undervoltage in the range of at least -5% to -20% in 1%\nsteps and for overvoltage in the range of at least +5% to +20% in\n1% steps.\n\nRegulations 2016 163\nTamper detection\n(c) A meter must support the detection and recording of an attempt to\ntamper with the meter as an event.\nS7A.5.3.8 Tamper detection\nA meter must support the detection and recording as an event\nattempts to tamper with the meter.\nS7A.5.3.9 Communications and data security\nAll device elements must contain the necessary security to prevent\nunauthorised access or modification of data.\nS7A.5.3.10 Remote firmware upgrades\nMeters must have the capability for their firmware to be remotely\nupgraded. It must be possible to remotely change firmware without\nimpacting the metrology functions of the meter.\nS7A.5.3.11 Remote arming\nMeters must have the capability to be remotely armed.\nSchedule 7A.6 Inspection and testing requirements\nS7A.6.1 General\n(a) The Metering Coordinator must ensure that equipment comprised in\na purchased metering installation has been tested to the required\nclass accuracy with less than the uncertainties set out in\nTable S7A.6.1.1.\n(b) The Metering Coordinator must ensure appropriate test certificates\nof the tests referred to in paragraph (a) are retained.\n(c) The Metering Coordinator (or any other person arranging for\ntesting) must ensure that testing of the metering installation is\ncarried out:\n(1) in accordance with:\n(i) clause 7A.7.2 and this schedule; or\n(ii) an asset management strategy that defines an\nalternative testing practice (other than time based)\ndetermined by the Metering Coordinator and approved\nby NTESMO;\n\nRegulations 2016 164\n(2) in accordance with a test plan that has been registered with\nNTESMO;\n(3) to the same requirements as for new equipment where\nequipment is to be recycled for use in another site; and\n(4) so as to include all data storage and processing components\n(d) The testing intervals may be increased if the equipment\ntype/experience proves favourable.\n(e) The maximum allowable level of testing uncertainty (±) for all\nmetering equipment must be in accordance with Table S7A.6.1.1.\nTable S7A.6.1.1 Maximum allowable level of testing uncertainty (±)\nDescription Metering Equipment Class\nClass 0.2 Class 0.5 Class 1.0 General\nPurpose\nClass 2.0\nIn Laboratory\nCTs\nphase\n0.05%\n0.07 crad\n0.1%\nVTs\n0.05%\n0.05 crad\n0.1%\n0.1 crad\nWh\n0.05/cosφ% 0.1/cosφ% 0.2/cosφ% 0.2/cosφ% n/a\nvarh\nn/a 0.2/sinφ% 0.3/sinφ% n/a 0.4/sinφ\n%\nIn Field CTs\n0.1%\n0.2%\n0.3 crad\nIn Field\nCTs\n0.1%\n0.2%\n0.3 crad\nVTs\n0.1% 0.2% n/a n/a n/a\n\nRegulations 2016 165\nDescription Metering Equipment Class\nClass 0.2 Class 0.5 Class 1.0 General\nPurpose\nClass 2.0\nPhase 0.1 crad 0.2 crad\nWh\n0.1/cosφ% 0.2/cosφ% 0.3/cosφ% 0.3/cosφ% n/a\nvarh\nn/a 0.3/sinφ% 0.4/sinφ% n/a 0.5/sinφ\n%\nWhere cosφ is the power factor at the test point under evaluation.\nTable S7A.6.1.2 Maximum Period Between Tests\nUnless the Metering Coordinator has developed an approved asset\nmanagement strategy that defines practices that meet the intent of\nthis schedule, the maximum period between tests must be in\naccordance with Table S7A.6.1.2.\nDescription Metering Installation Type\nType 1 Type 2 Type 3 Type 4 & 4A Types 5\n& 6\nCT 10\n10 years 10 years 10 years 10 years\nVT 10\n10 years 10 years n/a\nBurden tests When meters are tested or when changes are made\nCT\nmeter\n(electronic)\n5 years 5 years 5 years 5 years 5 years\nCT\nmeter\n(induction)\n2.5\n2.5 years 5 years 5 years 5 years\nWhole\ncurrent meter\nThe testing and inspection requirements must be in\naccordance with an approved asset management strategy.\nGuidelines for the development of an asset management\nstrategy are set out in Schedule 7A.7\n\nRegulations 2016 166\nTable S7A.6.1.3 Period between inspections\nUnless the Metering Coordinator has developed an approved asset\nmanagement strategy that meets the intent of this schedule and is\napproved by NTESMO, the maximum period between inspections\nmust be in accordance with Table S7A.6.1.3.\nDescription Metering Installation Type\nType 1 Type 2 Type 3 Type 4, 4A, 5\n& 6\nequipment\ninspection\n2.5 years 12 months\n(2.5 years if\ncheck\nmetering\ninstalled)\n> 10 GWh:\n2 years\n2≤ GWh ≤ 10:\n3 years\n<2 GWh: when\nmeter is tested.\nWhen meter\nis tested.\nS7A.6.2 Technical guidelines\n(a) Current transformer and voltage transformer tests are primary\ninjection tests, or other approved testing procedures as approved\nby NTESMO.\n(b) The calculations of accuracy based on test results are to include all\nreference standard errors.\n(c) An \"estimate of testing uncertainties\" must be calculated in\naccordance with the ISO \"Guide to the Expression of Uncertainty\nfor Measurement\".\n(d) Where operational metering is associated with settlements metering\nthen a shorter period between inspections is recommended (but is\nnot mandatory).\n(e) For sinφ and cosφ, refer to the ISO \"Guide to the Expression of\nUncertainty in Measurement\", where cosφ is the power factor.\n(f) A typical inspection may include:\n(1) check the seals;\n(2) compare the pulse counts;\n(3) compare the direct readings of meters;\n(4) verify meter parameters and physical connections; and\n\nRegulations 2016 167\n(5) current transformer ratios by comparison.\nSchedule 7A.7 Metrology procedure\nPart A\nS7A.7.1 Introduction\nS7A.7.1.1 General\n(a) This schedule applies to NTESMO, Registered Participants,\nMetering Coordinators, Metering Providers, Metering Data\nProviders and the Utilities Commission in relation to connection\npoints in this jurisdiction.\n(b) This schedule provides information on the application of metering\ninstallations to connection points and sets out provisions for\nmetering installations and metering data services.\n(c) For service provision at connection points where:\n(1) the Metering Provider and the Metering Data Provider are part\nof the same company; and\n(2) metering installation, provision or maintenance work is\nperformed using internal processes and procedures,\nthose internal processes and procedures will be taken to be\ncompliant with this schedule if the metering work satisfies the\nperformance and quality outcomes of this schedule.\nS7A.7.1.2 Definitions\naccumulation meter means a meter where the energy data\nrecorded in the meter represents a period in excess of a recording\ninterval.\nestimated reading means:\n(a) an estimate of a meter reading where an actual meter reading\nhas not occurred; or\n(b) a substitute of a meter reading used for the purposes of\ntransferring a retail customer to a new Retailer where an\nactual meter reading has not occurred.\nfinal reading means the last actual meter reading for a retail\ncustomer when they vacate an address or change retailer or the\n\nRegulations 2016 168\nlast actual meter reading taken before all or any part of a metering\ninstallation is removed or modified and where the modification\naffects the energy data in the metering installation.\nILAC means International Laboratory Accreditation Cooperation.\ninventory table means a table of devices for unmetered loads\nassociated with each NMI as described in clauses S7A.7.14.2(c)\nand S7A.7.14.3(c).\nload table means a table of unmetered device loads as described\nin clause S7A.7.14.1.\non/off table means a table recording the switching status (On = 1,\nOff = 0) for each recording interval for the unmetered loads\nassociated with a NMI as described in Part B of this schedule.\nphysical inventory means a physical count of devices.\npublic holiday means a day that is a public holiday, as defined in\nsection 17 of the Interpretation Act 1978 (NT), that is observed in\nthe City of Darwin, other than a public holiday that is part of a day.\nroutine testing, for the purposes of this schedule, includes the\nongoing and regular maintenance testing, compliance testing and\nin-service testing of metering installation components initiated by\nthe Metering Coordinator or Metering Provider to fulfil their\nobligations in accordance with schedule 7A.6.\nSample Test Plan means a statement of the sample size or sizes\nto be taken, the frequency of sample testing and the required\naccuracy.\nscheduled reading date means the date of the next scheduled\nmeter reading.\nunmetered means a load or a connection point at which a meter is\nnot necessary under schedule 7A.6.\nS7A.7.1.3 Relevant retailer\nIn this schedule, a reference to the relevant retailer is a reference to\nPower Retail Corporation (trading as Jacana Energy) ABN 65 889\n840 667.\n\nRegulations 2016 169\nPart B\nS7A.7.2 Purpose and scope\nS7A.7.2.1 Purpose\nThe purpose of this Part is to set out:\n(a) the obligations of the Metering Coordinator, in relation to\nmetering installations that are referred to in the Rules;\n(b) the obligations of Metering Providers in relation to the\nprovision, installation, routine testing and maintenance of a\n(c) the obligations of Metering Data Providers in relation to the\nprovision of metering data services.\nS7A.7.2.2 Scope\nThis schedule provides information on the application of metering\ninstallations to connection points. In particular, this schedule sets\nout provisions for metering installations and metering data services\nrelating to:\n(a) Metering Providers, which include:\n(1) the type of metering installation permitted for the\nmeasurement of active energy;\n(2) the provision, installation, testing, inspection and\nmaintenance of metering installations;\n(3) the components of each type of metering installation;\nand\n(4) storage of, and access rights to, energy data in the\n(b) Metering Data Providers, which include:\n(1) the collection or calculation, processing and delivery of\nmetering data; and\n(2) storage of metering data in the metering data services\ndatabase and rights of access to metering data.\n\nRegulations 2016 170\nS7A.7.3 Metering provision\nS7A.7.3.1 Responsibility for metering provision\n(a) Metering Coordinators must use Metering Providers to provide,\ninstall, test and maintain the relevant components, characteristics\nand service requirements of the metering installation as specified in\n(b) Metering Coordinators are responsible for the design of a metering\ninstallation and warrant that the design complies with the\ncomponents, characteristics and service requirements specified in\n(c) Metering Coordinators must ensure the components have been\nselected, installed, tested and commissioned by the Metering\nProviders so that the metering installation satisfies the relevant\naccuracy and performance requirements in the Rules.\nS7A.7.3.2 Metering installation components\n(a) Meters used in type 1, 2, 3, 4, 4A, 5 and 6 metering installations\n(including transitional arrangements) specified by the National\nMeasurement Institute, under the National Measurement Act, and\nmust also meet the relevant requirements of Australian Standards\nand International Standards:\n(1) for type 1, 2, 3, 4, 4A, and 5 (including type 3 and 4 whole\ncurrent) metering installation measurement elements:\nAS 62052.11, AS 62053.21 and AS 62053.22; and\n(2) for type 6 metering installation measurement elements:\nAS 1284.1, AS 62053.21 and AS 62052.11.\n(b) Current transformers for type 1, 2, 3, 4, 4A, 5 and 6 metering\ninstallations must meet the relevant requirements of AS 60044.1\nand must also comply with any applicable specifications or\nguidelines (including transitional arrangements) specified by the\nNational Measurement Institute under the National Measurement\nAct.\n(c) Voltage transformers for type 1, 2, 3, 4, 4A, 5 and 6 metering\ninstallations must meet the relevant requirements of AS 60044.2,\nAS 60044.3, AS 60044.5 and AS 1243 and must also comply with\nany applicable specifications or guidelines (including transitional\narrangements) specified by the National Measurement Institute\nunder the National Measurement Act.\n\nRegulations 2016 171\n(d) New current transformers and voltage transformers must comply\nwith current Australian Standards.\n(e) In-service current transformers and voltage transformers must\ncomply with the Australian Standard that applied at the time of\n(f) Unless otherwise permitted by the Rules, the Metering Coordinator\nmust ensure that new meters and related equipment used at a\nconnection point have a valid pattern approval issued under the\nauthority of the National Measurement Institute or, until relevant\npattern approvals exist, a valid type test certificate issued by a\nNATA accredited laboratory or a body recognised by NATA under\nthe ILAC mutual recognition scheme. Relevant approval certificates\nmust be provided to the Utilities Commission on request.\n(g) A visible display must be provided to display, at a minimum, the\ncumulative total energy for each register measured by that metering\n(h) Any programmable settings available within the metering\ninstallation, or any peripheral device, which may affect the\nresolution of displayed or stored data, must meet the relevant\nrequirements of AS 62052.11, AS 62053.21 and AS 62053.22 and\n(including transitional arrangements) specified by the National\nMeasurement Institute under the National Measurement Act.\nS7A.7.3.3 Use of optical ports and pulse outputs\n(a) Where requested by a financially responsible participant, the\nMetering Coordinator must provide pulse output facilities\nrepresenting the quantity of electricity measured in accordance with\nthe relevant Australian Standard for that meter within a reasonable\ntime of receiving the request.\n(b) For type 1, 2, 3, 4, 4A and 5 metering installations with a pulse\noutput, the measurement element pulse output must provide a\nnumber of energy pulses in each integrating period commensurate\nwith the accuracy class of the metering installation when operating\nat the top of the range of measurement of the metering installation\nbut may be set at a lower rate where the anticipated operating\nrange is significantly lower than the top of the range of\nmeasurement of the metering installation.\n\nRegulations 2016 172\n(c) A type 4A or 5 metering installation must have an optical port that\nmeets the AS 1284.10.2 or AS 62056.21 or a computer serial port\nto facilitate downloading of 90 days of interval energy data for each\nmeter associated with the metering installation in 35 seconds or\nless.\nS7A.7.3.4 Load control equipment\nWhere the metering installation includes equipment for load control\nor the measurement of reactive energy, the installation and\noperation of that equipment will be governed by an instrument other\nthan the Rules, for example, a ‘use of system' agreement between\nthe Local Network Service Provider and the financially responsible\nparticipant.\nS7A.7.3.5 Data storage requirements for meters\nNote\nNo specific requirements are included under this heading for this jurisdiction at\nthis stage. The clause may be used as part of the phased implementation of the\nS7A.7.3.6 Metering installation clock\n(a) A type 4A, 5 or 6 metering installation clock is to be reset to within ±\n20 seconds of Australian Central Standard Time on each occasion\nthat the metering installation is accessed in the circumstances\nreferred to in paragraphs (b) and (c), and the maximum drift in the\ntype 4A or 5 metering installation clock permitted between\nsuccessive meter readings is ± 300 seconds.\n(b) A Metering Provider must reset a type 4A, 5 or 6 metering\ninstallation clock when inspecting, maintaining or commissioning\nthe metering installation.\n(c) A Metering Data Provider must reset a type 4A, or 5 metering\ninstallation clock when interval metering data is collected from the\n(d) For type 6 metering installations with different time of day rates, the\nmetering installation must meet AS 62054.11, AS 62054.21 and\nAS 62052.21, or have the switching between the different rates\ncontrolled by a frequency injection relay or time clock operated by\nthe Local Network Service Provider.\n\nRegulations 2016 173\nS7A.7.3.7 Interval meters\nWhere a metering installation records interval energy data the\ninterval periods must be based on recording intervals or parts of a\nrecording interval in accordance with the following requirements:\n(a) the end of each interval for a 15-minute interval period must\nbe on the hour, on the half-hour and on each quarter of an\nhour (ACST);\n(b) the end of each interval for a 30-minute interval period must\nbe on the hour and on the half-hour (ACST);\n(c) for other sub-multiple intervals –where agreed with NTESMO\n(in respect of a metering installation that is used for the\npurposes of settlements), the Local Network Service Provider\nand the relevant financially responsible participant, provided\nthat the ends of the intervals correspond each and every exact\nhour (ACST) and half-hour (ACST).\nS7A.7.3.8 Alarm settings\n(a) Where an interval meter supports alarm functionality, the Metering\nProvider is required to enable the following alarms:\n(1) power failure/meter loss of supply for instrument transformer\nconnected metering installations only;\n(2) voltage transformer or phase failure;\n(3) pulse overflow;\n(4) cyclic redundancy check error; and\n(5) time tolerance.\n(b) Where there are alarm sensitivity settings, these must be set at\nappropriate levels to ensure meaningful alarm outputs (for example,\nfor contestable supplies a voltage drop of -15% is nominally\nappropriate).\nS7A.7.3.9 Summation metering\n(a) If summation metering is achieved by paralleling current\ntransformer secondary circuits, the overall metering system must\nmeet the minimum standards for a new metering installation under\nall load combinations of the individual current transformer\nsecondaries.\n\nRegulations 2016 174\n(b) If summation metering is achieved by the arithmetic sum of data\nregisters or the accumulation of pulses, each individual metering\npoint must meet the minimum standards for a new metering\ninstallation and the Metering Coordinator must on request\ndemonstrate that the summation techniques reliably and accurately\ntransfer data.\n(c) Current transformer secondaries can only be paralleled using\nappropriate arrangements of links; this must not be done at the\nmeter terminals.\n(d) For type 2 metering installations only – direct summation, in which\nsecondary wiring from a multiple number of feeders are connected\ndirectly into the terminals of a meter, or summation current\ntransformers, are permitted provided that the overall errors of the\ninstallation are considered.\nS7A.7.3.10\nNote\nS7A.7.3.11 Routine testing and inspection of metering installations\n(a) Unless a Metering Coordinator has an Asset Management Strategy\napproved by NTESMO, metering installations must be tested and\ninspected in accordance with rule 7A.7 and schedule 7A.6.\nParagraphs (b) to (f) provide guidelines that:\n(1) the Metering Coordinator will need to take into consideration\nwhen seeking approval of an Asset Management Strategy;\nand\n(2) NTESMO will need to take into consideration in approving a\nproposed Asset Management Strategy.\n(b) An acceptable alternative testing practice or test plan for in-service\nmeter performance must demonstrate compliance with Australian\nStandard \"AS 1284.13: Electricity Metering in-service compliance\ntesting\".\n(c) Unless the Metering Coordinator has developed an alternative\naccuracy assessment method for type 5 and 6 metering\ninstallations that meets the intent of Tables S7A.4.2.5 and\nS7A.4.2.6 and is approved by NTESMO, the overall metering\ninstallation error is calculated by the vector sum of the errors of\neach metering installation component, being a + b + c where:\n\nRegulations 2016 175\na = error of VT and wiring\nb = error of CT and wiring\nc = error of meter.\n(d) Where the Metering Coordinator is not testing and inspecting\nmetering installations in accordance with rule 7A.7 and\nschedule 7A.6 (that is, not time-based), the Metering Coordinator\nmust include in its Asset Management Strategy an alternative\ninspection practice that meets the requirements of schedule 7A.6.\n(e) The Metering Coordinator must provide a copy of the Asset\nManagement Strategy to each relevant Metering Provider.\n(f) For those meters for which new or amended pattern approval has\nbeen received from the National Measurement Institute or, in the\nabsence of pattern approval, new or amended type testing has\nbeen undertaken by a NATA accredited laboratory or a body\nrecognised by NATA under the ILAC mutual recognition scheme,\nthe Metering Coordinator must ensure that the Sample Test Plan\nstipulates that this population of meter is tested at least once in the\nfirst three years of being placed in service.\nS7A.7.3.12 Requests for testing type 1 – 6 metering installations\n(a) If requested by a Registered Participant with a financial interest in\nthe metering installation or the energy measured by the metering\ninstallation, the Metering Coordinator must make arrangements for\nthe testing of the metering installation in accordance with\nclause 7A.7.2 of the Rules.\n(b) If requested by a Registered Participant with a financial interest in\nthe metering installation, the Utilities Commission must make\narrangements in accordance with clause 7A.7.4 of the Rules to\ndetermine the consistency of metering data held in the metering\ndata services database and the energy data held in the type 1, 2, 3,\n4, 4A, 5 and 6 metering installation.\n(c) Where the Registered Participant requests a metering installation\ntest in accordance with paragraphs (a) and (b):\n(1) the Metering Coordinator or the Utilities Commission (as\napplicable) must use reasonable endeavours to conduct the\ntest within 15 business days of the request;\n(2) if the requirement under subparagraph (1) would prevent the\nRegistered Participant's customer witnessing the test, then the\nMetering Coordinator or the Utilities Commission may agree to\na mutually convenient time to conduct the test; and\n\nRegulations 2016 176\n(3) the Metering Coordinator or the Utilities Commission (as\napplicable) must, if requested, provide an estimate of costs\nassociated with the test prior to any test being undertaken.\nS7A.7.4 Installation of meters and de-commissioning\nS7A.7.4.1 General installation requirements\nThe Metering Coordinator must use reasonable endeavours to\nensure that, at the time of installation, a metering installation is:\n(a) protected against damage;\n(b) installed in such a way that it allows safe and unimpeded\naccess to the retail customer or any person whose obligation it\nis to test, adjust, maintain, repair, or replace the metering\ninstallation, or to collect metering data from the metering\ninstallation; and\n(c) available to the retail customer or any person whose obligation\nit is to test, adjust, maintain, repair, or replace the metering\ninstallation, or to collect metering data from the metering\ninstallation via safe, convenient and unhindered access when\nit is not located at the site.\nS7A.7.4.2 Type 4A, 5 and 6 metering installations\nThe Metering Coordinator must ensure that when each type 4A, 5\nor 6 metering installation is installed at a connection point, it is\nchecked such that it has the optical port, communications port and\nvisual display located so that the optical port, communications port,\nor visual display can be readily accessed for meter reading.\nS7A.7.4.3 Preliminary de-commissioning and removal of metering\nequipment requirements\n(a) Before de-commissioning all or any part of an existing metering\ninstallation the Metering Provider undertaking the work must ensure\n(1) arrangements are put in place to ensure a final reading is\ntaken at the time of de-commissioning of all metering data\nmaintained in the existing meter; and\n(2) the ownership of the existing meter is ascertained and\narrangements made for the meter to be returned to its owner\nwithin 10 business days unless otherwise agreed with the\nasset owner.\n\nRegulations 2016 177\n(b) Where the metering data from the final reading is not transferred to\nthe relevant Metering Data Provider at the time of de-\ncommissioning, the owner must ensure the metering data or final\nreading (as applicable), is provided to that Metering Data Provider\nwithin 2 business days of receipt of the meter.\nS7A.7.4.4\nNote\nS7A.7.5\nNote\nS7A.7.6 Responsibility for metering data services\nS7A.7.6.1 Metering data storage\nNote\nS7A.7.6.2 Verification of metering data for type 4, 4A, 5, 6 and 7\nTo facilitate the verification of metering data for type 4, 4A, 5, 6\nand 7 metering installations:\n(a) each Metering Coordinator must ensure that a Sample Test\nPlan is established and maintained in accordance with\nAustralian Standards \"AS 1199: Sampling procedures for\ninspection by attributes – Sampling schemes indexed by\nacceptance quality limit (AQL) for lot-by-lot inspection\" or\n\"AS 2490: Sampling Procedures and Charts for Inspection by\nVariables for Percent Nonconforming\" to validate that all\nmetering data stored in the metering data services database is\nconsistent with the energy data stored in the metering\ninstallation or the physical inventory (as applicable);\n(b) verification tests must be conducted in accordance with the\nSample Test Plan, which must not be less than once every 12\nmonths;\n\nRegulations 2016 178\n(c) the calculated metering data stored in a metering data\nservices database for a NMI is consistent with the physical\ninventory if the error associated with calculating the energy\nvalue for the sample, that is:\nis within ± 2.0%; and\n(d) if there is an inconsistency between the inventory table held in\na metering data services database for a type 7 metering\ninstallation and the physical inventory, the physical inventory\nis to be taken as prima facie evidence of the actual number of\nunmetered devices.\nNote\nProvisions relating to type 7 metering installations will only apply in this\njurisdiction in the event of a type 7 metering installation being available in this\njurisdiction and after a 12 month transitional period allowing all participants to\nachieve compliance.\nS7A.7.6.3 Metering installation type 7 – sample testing\n(a) For the purposes of sample testing type 7 metering installations, the\nMetering Coordinator must ensure that the sample size is\ndetermined using Table S7A.7.5.3.1. The sample is to be selected\nfrom unmetered devices in the inventory table for a Metering\nCoordinator.\n(b) The Metering Coordinator must ensure that the sample size for the\nfirst two validation tests is based on a ‘normal' sample size\nindicated in Table S7A.7.5.3.1.\n\nRegulations 2016 179\nTable S7A.7.5.3.1 -–Unmetered devices in inventory table\nNumber of Unmetered\nDevices in Inventory Table\nSample Size\nReduced Normal Tightened\n2 to 8 2 2 3\n9 to 15 2 3 5\n16 to 25 3 5 8\n26 to 50 5 8 13\n51 to 90 5 13 20\n91 to 150 8 20 32\n151 to 280 13 32 50\n281 to 500 20 50 80\n501 to 1200 32 80 125\n1201 to 3200 50 125 200\n3201 to 10000 80 200 315\n10001 to 35000 125 315 500\n35001 to 150000 200 500 800\n150001 to 500000 315 800 1250\n500001 to over 500 1250 2000\n\nRegulations 2016 180\n(c) The Metering Coordinator must ensure that the sample size for\nsubsequent variation tests is based on the following:\n(d) The Metering Coordinator must select sample unmetered devices\nfor a validation test from random geographic areas depending on\nthe sample size. The selection of the geographic area must be such\nthat each unmetered device has an equal chance of being included\nin the sample.\n(e) The Metering Coordinator must ensure that the validation test is\nconducted at least once every 6 months, commencing from the first\nvalidation test.\n(f) Should the results of two consecutive validation tests, based on a\nreduced sample size, be within the accuracy requirements for that\ntest, the Metering Coordinator must ensure that the next validation\ntest is conducted at least once every 12 months.\nReduced Current\nsample size?\nTightened\nNormal\nReduced Previous\nsample size? Tightened\nNormal\nPrevious test\nNo\nYes\nYes\nYes Current test\nNo\nCurrent test\nNo\nNext\nsample\nsize -\nTightened\nNext\nsample size\n- Reduced\nNext sample\nsize - Normal\n\nRegulations 2016 181\nS7A.7.6.4 Request for text of calculated metering data\nIf requested to test a type 7 metering installation by a Registered\nParticipant under clause 7A.7.2, the Metering Coordinator must:\n(a) arrange to test that the calculated metering data stored in the\nmetering data services database reflects the physical\ninventory for the type 7 metering installation;\n(b) use reasonable endeavours to conduct the test within\n15 business days of the request; and\n(c) prior to any test being undertaken, provide an estimate of\ncosts associated with the test.\nS7A.7.6.5 NTESMO's metering data substitution obligations\n(a) Where metering data has been substituted, NTESMO must advise\naffected Registered Participants at the same time as that metering\ndata is sent to financially responsible participants for settlements.\n(b) If metering data has not been transferred to NTESMO to meet the\nsettlements time frames or such metering data has been\ntransferred but is unusable, NTESMO must, in accordance with\nclause 7A.9.2:\n(1) take action to obtain the metering data; or\n(2) request the Metering Coordinator take action to obtain the\nmetering data.\nPart C\nS7A.7.7 Purpose and scope\nS7A.7.7.1 Purpose\nThe purpose of this Part is to set out obligations concerning the\nvalidation, substitution and forward estimation of metering data to\nsatisfy the Rules.\nS7A.7.7.2 Scope\n(a) This Part applies to Metering Data Providers, NTESMO and\nMetering Coordinators.\n(b) This Part must be read in conjunction with Schedule 7A.8 Part B.\n\nRegulations 2016 182\nS7A.7.8 Principles for validation, substitution and\nestimation\nS7A.7.8.1 General validation, substitution and estimation requirements\nThe principles to be applied to validation, substitution and\nestimation include the following:\n(a) the Metering Coordinator must coordinate the resolution of\nissues arising from the non-performance of metering systems,\nincluding any liaison with associated Registered Participants,\nMetering Providers and Metering Data Providers, and the\nMetering Coordinator must respond promptly to requests for\nremedial action from the Metering Data Provider or NTESMO;\n(b) the Metering Data Provider must identify metering data errors\nresulting from data collection and processing operations using\nvalidation processes in accordance with this Part.\nS7A.7.8.2 Substitution requirements\n(a) The Metering Data Provider must undertake substitutions on behalf\nof NTESMO or the Metering Coordinator, as appropriate, in a\nmanner consistent with this Part.\n(b) Substitutions may be required in the following circumstances:\n(1) where the system or equipment supporting the remote or\nmanual collection of metering data has failed or is faulty;\n(2) where the metering installation for a connection point has\nfailed or is removed from service;\n(3) to enable timely provision of metering data to financially\nresponsible participants or NTESMO for billing transactions or\nsettlements purposes, as relevant;\n(4) in situations where metering data has been irretrievably lost;\n(5) where the metering data is found to be erroneous or\nincomplete;\n(6) where metering data has not completed validation as part of\nthe registration or transfer of a connection point;\n(7) where metering data has failed or has not completed the\nvalidation process;\n\nRegulations 2016 183\n(8) where metering data cannot be obtained in the performance\ntimeframes required for the data period in question:\n(i) metering data for metering installations with remote\nacquisition must be substituted if metering data cannot\nbe obtained to meet either settlements or billing\ntransactions timeframes, as relevant, or the required\nperformance in Schedule 7A.8 Part C; and\n(ii) metering data for manually read metering installations\nmust be substituted if metering data cannot be obtained\non or within the expected timeframe of the next\nscheduled reading date for a connection point, and any\nhistorical or previous estimated metering data must be\nreplaced with substituted metering data;\n(9) when an inspection or test on the metering installation\nestablishes that a measurement error exists due to a metering\ninstallation fault;\n(10) when the affected financially responsible participant, the\nrelevant retailer and Local Network Service Provider have all\nagreed and subsequently informed the Metering Data Provider\nthat a previous substitution was inaccurate and that a re-\nsubstitution of metering data is required;\n(11) where the metering data calculation has failed the validation\ntests for a metering installation with calculated metering data;\n(12) in response to customer transfers authorised in this\n(13) in situations involving meter churn.\nS7A.7.8.3 Estimation requirement\n(a) The Metering Data Provider must undertake estimations on behalf\nof the Metering Coordinator in a manner consistent with this Part.\n(b) Estimations may be required in the following circumstances:\n(1) routinely for a period equal to or just greater than the period to\nthe next scheduled reading date or another forward period;\n(2) in response to customer transfers authorised in this\n(3) where the current published scheduled reading date has\nchanged due to a revised scheduled reading route and the\nexisting estimated metering data does not extend to or beyond\n\nRegulations 2016 184\nthe revised next scheduled reading date, and in this case the\nMetering Data Provider must adjust the estimated metering\ndata for the revised next scheduled reading date.\nS7A.7.8.4 Metering data quality flags\n(a) The Metering Data Provider must assign the relevant metering data\nquality flags to metering data as follows:\nQuality Flag Description\nA Actual metering data.\nS For any substituted metering data that is considered temporary\nand may be replaced by actual metering data. Substitutions\napply to historical date/time periods at the time of substitution.\nE For any estimated metering data that is considered temporary\nand may be replaced by actual metering data or substituted\nmetering data. Estimations apply to a period that has an end\ndate/time in the future.\nF For substitutions that are of a permanent or final nature and,\nsubject to paragraph S7A.7.8.5(b) and (e), the metering data\nwould not be replaced by actual metering data at any time.\nN This quality flag is only utilised within the interval metering data\nfile for instances where no metering data exists in the metering\ndata services database for the periods concerned.\n(b) Unless specified otherwise in this Part, Metering Data Providers\nmust apply the following quality flag rules in the metering data\nservices database:\n(1) ‘A' metering data can only be replaced with ‘A', ‘S' or ‘F'\n(2) ‘S' metering data can only be replaced with ‘A', ‘S' or ‘F'\n(3) ‘E' metering data can only be replaced with ‘A', ‘E', ‘S' or ‘F'\n(4) ‘F' metering data can only be replaced with ‘F' metering data\nas per paragraph S7A.7.8.5(f) or ‘A' metering data as per\nparagraph S7A.7.8.5(b) or S7A.7.8.5(h).\n\nRegulations 2016 185\nS7A.7.8.5 Final substitution\nThe Metering Data Provider must undertake final substitutions in\nthe following circumstances:\n(a) where a notice has been received from either the Metering\nCoordinator or the Metering Provider detailing a failure of the\nmetering installation that affects the quality of the energy data;\n(b) if actual metering data is unexpectedly recovered from the\nmetering installation and a final substitution has been\nundertaken in accordance with paragraph (1), and in this case\nthe Metering Data Provider must replace the final substituted\nmetering data with the actual metering data and maintain a\nrecord of the reason;\n(c) where the Metering Data Provider must undertake final\nsubstitutions following a meter churn;\n(d) where the Metering Data Provider has received a notice that\nthe affected financially responsible participant, the relevant\nretailer and Local Network Service Provider have agreed that\nthe metering data is erroneous and that a final substitution is\nrequired;\n(e) where NTESMO requests the provision of substitutions and\nfinal readings in response to customer transfers authorised in\nthis jurisdiction where required for the purposes of\nsettlements;\n(f) where the Metering Data Provider may undertake to replace\nexisting final substituted metering data with new final\nsubstituted metering data in accordance with this Part;\n(g) where the Metering Data Provider has found actual metering\ndata to be erroneous;\n(h) where the Metering Data Provider is replacing type 6 final\nsubstituted metering data with accumulated metering data that\nspans consecutive meter readings on agreement with the\nfinancially responsible participant, the relevant retailer and the\nLocal Network Service Provider.\n\nRegulations 2016 186\nS7A.7.9 Substitution for acquisition of metering data from\nremotely read metering installations\nS7A.7.9.1 Application of S7A.7.9\n(a) For metering installations with remote acquisition installed in\naccordance with paragraph 7A.6.8(a), the Metering Data Provider\nmay perform substitutions in accordance with clause S7A.7.10.\n(b) For all other metering installations with remote acquisition, the\nMetering Data Provider must perform substitutions in accordance\nwith clause S7A.7.9.\nS7A.7.9.2 Substitution rules\nThe Metering Data Provider must apply the following rules when\nperforming a substitution:\n(a) the Metering Data Provider must obtain clear and concise\nidentification as to the cause of any missing or erroneous\nmetering data for which substitutions are required;\n(b) the Metering Data Provider must undertake to do a type 11\nsubstitution and use metering data obtained from any check\nmetering installation associated with the connection point as\nthe first choice considered for the source of metering data for\nany substitutions undertaken;\n(c) SCADA data, where available, may be used by the Metering\nData Provider as check metering data for substitutions;\n(d) the Metering Data Provider may only undertake substitution\ntype 13 where substitution types 11 and 12 are not applicable\nor cannot be carried out;\n(e) for connection points where the financially responsible\nparticipant is a generator:\n(1) the Metering Data Provider may directly undertake\ntype 11, type 12 or type 13 substitutions if metering data\nhas failed validation;\n(2) the Metering Data Provider may undertake type 16 or 18\nsubstitutions following consultation and agreement with\nthe affected generator that the substituted metering data\nis an accurate reflection of the interval metering data\nconcerned;\n(3) if metering data cannot be collected from a metering\ninstallation or substituted within the required timeframes,\n\nRegulations 2016 187\nthe Metering Data Provider must undertake type 19\nsubstitutions as an interim until metering data can be\ncollected from the metering installation or substituted;\n(f) the Metering Data Provider may only undertake substitution\ntypes 14, 15, 16, 17, 18, or 19 where substitution types 11, 12\nand 13 are not applicable or cannot be carried out;\n(g) the Metering Data Provider may perform all substitution types\nexcept type 16 or 18 without the agreement of the affected\nfinancially responsible participant, Local Network Service\nProvider or relevant retailer and the Metering Data Provider\nmay change the quality flag to an existing type 16 or 18\nsubstitution without seeking further agreement from those\nparties;\n(h) the Metering Data Provider must notify the Local Network\nService Provider, relevant retailer and the financially\nresponsible participant for the connection point of any\nsubstitution within two business days of the substitution being\ncarried out, and this notification is to be achieved via the\nparticipant metering data file as detailed in the MDFF\nSpecification;\n(i) where there is a metering installation malfunction that cannot\nbe repaired within the periods specified in clause 7A.6.9, the\nMetering Data Provider must:\n(1) where the metering installation malfunction is due to a\nfailure of the meter to correctly record interval energy\ndata and the Metering Coordinator has been granted an\nexemption to repair the metering installation, substitute\nthe missing metering data in accordance with this Part;\n(2) for type 1-3 metering installations and other instrument\ntransformer connected metering installations, and where\na metering installation malfunction is due to a failure of\nthe remote acquisition system, arrange for an alternative\nmethod for the collection of metering data from the\nmetering installation in a timeframe that ensures the\nMetering Data Provider complies with metering data\ndelivery requirements; or\n(3) for non-instrument transformer connected metering\ninstallations, and where a metering installation\nmalfunction is due to a failure of the remote acquisition\nsystem, substitute the missing metering data in\naccordance with this Part;\n\nRegulations 2016 188\n(j) the Metering Data Provider must ensure that all substituted\nmetering data is replaced with actual metering data when it\nbecomes available.\nS7A.7.9.3 Substitution types\nType 11 – Check data\n(a) To perform a type 11 substitution, the Metering Data Provider must\nuse interval metering data obtained from the check metering\ninstallation for that metering point where:\n(1) the metering installation and check metering installation are\ninstalled at the same connection point;\n(2) the metering installation and check metering installation are\ninstalled on different ends of a transmission line where the\ndifference due to transmission line losses can be accurately\ndetermined; or\n(3) the metering installation and the check metering installation\nare installed across a parallel set of feeders having similar line\nimpedances between a common set of busbars.\nType 12 – Calculated\n(b) To perform a type 12 substitution, the Metering Data Provider must\ncalculate the interval metering data to be substituted where they\nrelate to a single unknown feed to a node based on the other\nknown energy flows to or from that node.\nType 13 – SCADA\n(c) To perform a type 13 substitution:\n(1) the Metering Data Provider must use SCADA data provided by\nNTESMO in the agreed format for substitution purposes,\nwhich originates from a similar measurement point as the\nmeter;\n(2) where SCADA data is inferior in accuracy or resolution and in\na dissimilar format to the metering data, (for example, 30 Min.\ndemand values). the Metering Data Provider may have to\nadjust the data in both magnitude and form so that the\nsubstitution is valid; and\n(3) where SCADA data is to be used for Substitution, both the\nprovided ‘E' channel and ‘B' channel SCADA data streams\nmust be used.\n\nRegulations 2016 189\nType 14 – Like day\n(d) To perform a type 14 substitution, the Metering Data Provider must\nsubstitute missing or erroneous metering data using the nearest\nequivalent day or like day method, as detailed in Table 1.\nTable 1\nTYPE 14\nSubstitution day Nearest equivalent day or like day (in\norder of availability)\nMonday Monday ##\nTuesday Tuesday## Wednesday## Thursday##\nWednesday# Thursday#\nWednesday Wednesday## Tuesday# Thursday##\nThursday# Tuesday##\nThursday Thursday## Wednesday# Tuesday#\nWednesday## Tuesday##\nFriday Friday##\nSaturday Saturday##\nSunday Sunday##\nSubstitutions for like day to be as detailed above, unless:\n(a) No metering data is available on the first listed day, the next listed\npreferred day is to be used. If there is no other suitable listed day, or\nno metering data is available on any of the listed days type 15\nsubstitution must be used.\n(b) The substitution day was a public holiday, in which case the most\nrecent Sunday is to be used.\n(c) The substitution day was not a public holiday and the listed day is a\npublic holiday, then the next listed preferred day that is not a public\nholiday is to be used.\n# Occurring in the same week as the substitution day.\n## Occurring in the week preceding that in which the substitution day\noccurs.\nType 15 – Average like day\n(e) To perform a type 15 substitution, the Metering Data Provider may\nsubstitute missing or erroneous metering data using the average\nlike day method, as detailed in Table 2.\n\nRegulations 2016 190\nTable 2\nTYPE 15\nThe interval metering data to be substituted will be calculated using an\naverage of the metering data from each corresponding interval from the\npreceding 4 weeks, or any part of those. This averaging technique may be\napplied in either of the following ways:\n(a) where the averaged interval metering data is used to provide the\nvalue for the metering data requiring substitution;\n(b) where the averaged interval metering data is used to provide the\nprofile and is scaled to a pre-determined consumption value for the\nmetering data to be substituted.\nType 15 substitutions must not be used for public holidays.\nType 16 – Agreed method\n(f) Where the Metering Data Provider is required to undertake\nsubstitution for any period greater than seven days for type 1 –\n3 metering installations or greater than 15 days for other metering\ninstallation types, the Metering Data Provider must consult and use\nreasonable endeavours to reach an agreement with the financially\nresponsible participants, relevant retailer and the Local Network\nService Provider for the connection point. This may include\nchanges to existing substitutions for any period where those\naffected parties have directed that as a result of site or end user\ninformation, the original substitutions are in error and a correction is\nrequired.\nType 17 – Linear interpolation\n(g) To perform a type 17 substitution, the Metering Data Provider may\nsubstitute metering data for consecutive intervals up to, but not\nexceeding two hours, by using simple linear interpolation.\nType 18 – Alternative\n(h) To perform a type 18 substitution, the Metering Data Provider may\nuse an alternative method of substitution subject to agreement with\nthe financially responsible participants, relevant retailer and the\nLocal Network Service Provider for the connection point. The\nspecifics of this substitution type may involve a globally applied\nmethod or a method where an adjusted profile is used to take into\naccount local conditions that affect consumption (for example, local\nholiday or end user shutdown), or where alternative metering data\nmay be available for quality checks, such as using metering register\ndata.\n\nRegulations 2016 191\nType 19 – Zero\n(i) The Metering Data Provider must undertake substitutions of ‘zero'\n(1) the Local Network Service Provider or the Metering Provider\nhas informed the Metering Data Provider of a de-energised\nconnection point or an inactive meter and the consumption is\nreasonably believed to be zero; or\n(2) substitutions are applicable for connection points where the\nfinancially responsible participant is a Generator in\naccordance with clause S7A.7.9.2.\nS7A.7.10 Substitution and estimation for manually read\ninterval metering installations\nS7A.7.10.1 Application of S7A7.10\n(a) The substitution and estimation requirements in this\nclause S7A.7.10 are only to be used for metering installations\n(1) interval metering data is manually collected as a scheduled\nmeter reading; or\n(2) the metering installations have been installed with remote\nacquisition in accordance with paragraph 7A.6.8(a).\n(b) Where remote acquisition of metering data has failed at the\nmetering installation and manual collection of interval metering data\nis required, the substitution requirements specified in\nclause S7A.7.9 apply.\nS7A.7.10.2 Substitution and estimation rules\n(a) The Metering Data Provider must ensure that all substituted\nmetering data and estimated metering data are replaced with actual\nmetering data when it becomes available.\n(b) The Metering Data Provider must obtain clear and concise\nidentification as to the cause of any missing or erroneous metering\ndata for which substitutions are required.\n(c) Where there is a metering installation malfunction that cannot be\nrepaired within the periods specified in clause 7A.6.9, the Metering\nData Provider must substitute the missing metering data in\naccordance with this Part.\n\nRegulations 2016 192\n(d) The Metering Data Provider must only apply the following\nsubstitution and estimation types:\n(1) substitutions may be type 51, 52, 53, 54, 55, 56, 57 or 58;\n(2) estimations may be type 51, 52, 56, 57 or 58.\n(e) The Metering Data Provider must only use type 56 or 57\nsubstitutions or estimations where the historical data does not\nsupport the application of a type 51 or 52 substitution or estimation.\n(f) The Metering Data Provider must notify the Local Network Service\nProvider, the relevant retailer and the financially responsible\nparticipant for the connection point of any substitution or estimation\nwithin 2 business days of the substitution.\n(g) Metering Data Providers must not perform type 53 or 55\nsubstitutions or type 56 substitutions or estimations without the\nagreement of the Local Network Service Provider, the relevant\nretailer and the financially responsible participant for the connection\npoint. Metering Data Providers may change the quality flag to an\nexisting type 53 or 55 substitution or type 56 substitution or\nestimation without seeking further agreement from those parties.\nS7A.7.10.3 Substitution and estimation types\nType 51 – Previous years method (nearest equivalent day or\nlike day method)\n(a) To perform a type 51 substitution, the Metering Data Provider must\nprovide a substitute or estimate using the metering data from the\nnearest equivalent day or like day from the same, or similar, meter\nreading period in the previous year. The nearest equivalent day or\nlike day is to be determined from Table 3.\nType 52 – Previous meter reading method (nearest equivalent\nday or like day method)\n(b) To perform a type 52 substitution, the Metering Data Provider must\nprovide a substitute or estimate using the metering data from the\nnearest equivalent day or like day from the previous meter reading\nperiod. The nearest equivalent day or like day is to be determined\nfrom Table 3.\n\nRegulations 2016 193\nTable 3\nTYPE 51 or 52\nSubstitution day Nearest equivalent day or like day (in order\nof availability)\nMonday Monday ## Monday#\nTuesday Tuesday## Wednesday## Tuesday#\nWednesday#\nWednesday Wednesday## Tuesday## Thursday##\nWednesday# Thursday# Tuesday#\nThursday Thursday## Wednesday## Tuesday##\nThursday# Wednesday# Tuesday#\nFriday Friday## Friday#\nSaturday Saturday## Saturday#\nSunday Sunday## Sunday#\nSubstitutions or estimations for like day to be as detailed above, unless:\n(a) no metering data is available on the first listed day, in which case the\nnext listed preferred day is to be used. If there is no other suitable day,\nor no metering data is available on any of the listed days, type 52 must\nbe used;\n(b) the substitution or estimation day was a public holiday, in which case\nthe most recent Sunday is to be used; or\n(c) the substitution or estimation day was not a public holiday and the\nlisted day is a public holiday, in which case the next listed preferred\nday that is not a public holiday, Saturday or Sunday is to be used.\n## For type 51 utilise metering data from the corresponding week in\nthe previous year.\n## For type 52 utilise metering data from the corresponding week of\nthe previous meter reading period.\n# For type 51 utilise metering data from the week preceding the\ncorresponding week in the previous year.\n# For type 52 utilise metering data occurring in the week preceding the\ncorresponding week of the previous meter reading period.\n(c) Alternatively, the Metering Data Provider must provide substituted\nmetering data or estimated metering data using the average like\nday method, as detained in Table 4.\n\nRegulations 2016 194\nTable 4\nTYPE 52 (Alternative)\nThe interval metering data for which substitution or estimation is to be carried\nout will be calculated using an average of the metering data from each\ncorresponding interval from any part, or all, of the preceding 4 weeks. This\naveraging technique may be applied in either of the following ways:\n• where the averaged interval metering data is used to provide the value for\nthe metering data requiring substitution or estimation;\n• where the averaged interval metering data is used to provide the profile\nand are scaled to a pre-determined consumption value for the metering\ndata that are the subject of substitution or estimation.\nType 52 substitutes or estimates must not be used for public holidays.\nType 53 – Revision of substituted metering data\n(d) To perform a type 53 substitution, the Metering Data Provider must\nre-substitute or change substituted metering data to collecting an\nactual meter reading, where the financially responsible participant,\nthe relevant retailer and the Local Network Service Provider have\nagreed, on the basis of site or end user information, that the original\nsubstituted metering data is in error and a correction is required.\nType 54 – Linear interpolation\n(e) To perform a type 54 substitution, the Metering Data Provider may\nsubstitute metering data for intervals up to, but not exceeding\n2 hours, by using simple linear interpolation.\nType 55 – Agreed substitution method\n(f) To perform a type 55 substitution, the Metering Data Provider may\nundertake to use another method of substitution (which may be a\nmodification of an existing substitution type), where none of the\nexisting substitution types apply, subject to using reasonable\nendeavours to form an agreement with the financially responsible\nparticipant, the relevant retailer and Local Network Service Provider\nfor the connection point. The specifics of this substitution type may\ninvolve a globally applied method.\nType 56 – Prior to first reading – agreed method\n(g) Prior to the first actual meter reading and where no historical data\nexists for the connection point, the Metering Data Provider may\nprovide a substitution or estimation for the interval metering data\nusing a method agreed between the financially responsible\nparticipant, the relevant retailer and Local Network Service\nProvider.\n\nRegulations 2016 195\nType 57 – Prior to first reading – customer class method\n(h) [Not used]\nType 58 – Zero\n(i) The Metering Data Provider must undertake substitutions or\nestimations of ‘zero' where either the Local Network Service\nProvider or the Metering Provider has informed the Metering Data\nProvider of a de-energised connection point or an inactive meter\nand where the consumption is known to be zero.\nS7A.7.11 Substitution and estimation for metering\ninstallations with accumulated metering data\nS7A.7.11.1 Substitution and estimation rules\n(a) The Metering Data Provider must replace all estimated metering\ndata with either actual metering data or substituted metering data\nwhen:\n(1) actual metering data covering all or part of the estimation\nperiod is obtained;\n(2) the scheduled meter reading could not be undertaken, by\nreplacing the estimated metering data with substituted\nmetering data with a quality flag of ‘F'; or\n(3) the scheduled meter reading could not be undertaken, by\nreplacing the estimated metering data with substituted\nmetering data with a quality flag of ‘F' unless it was identified\nthat the metering installation no longer has an accumulation\nmeter installed, in which case a quality flag of ‘S' may be\nused.\n(b) Any final substituted metering data provided by the Metering Data\nProvider must be re-validated, updated or re-calculated by the\nMetering Data Provider when:\n(1) the value of the metering data obtained at the next actual\nmeter reading is found to be less than the previous final\nsubstitution; or\n(2) the final substituted value is disputed and following\nconsultation and agreement with the financially responsible\nparticipant, the relevant retailer and the Local Network Service\nProvider for the connection point, the new agreed value will be\ndetermined using type 64 substitution.\n\nRegulations 2016 196\n(c) The Metering Data Provider must obtain clear and concise\nidentification as to the cause of any missing or erroneous metering\ndata for which substitutions are required.\n(d) The Metering Data Provider may apply the following substitution\nand estimation types:\n(1) substitutions may be type 61, 62, 63, 64, 65, 66, 67 or 68;\n(2) estimations may be type 61, 62, 63, 65 or 68.\nWhen to use Type 62 substitution\n(e) Where the scheduled meter reading cycle is less frequent than\nmonthly, the Metering Data Provider may only use a type 62\nsubstitution or estimation method when metering data from the\nsame, or similar, meter reading period last year (that is, type 61) is\nnot available.\nWhen to use Type 63 substitution\n(f) The Metering Data Provider may use type 63 substitutions or\nestimations only when the metering data from the same, or similar,\nmeter reading period last year and metering data from the previous\nmeter reading period is not available (that is, when type 61 and\ntype 62 substitution or estimation methods cannot be used).\nWhen to use Type 65 substitution\n(g) The Metering Data Provider may use type 65 substitutions or\nestimations only when the metering data from the same, or similar,\nmeter reading period last year or the metering data from the\nprevious meter reading period is not available (that is, when type 61\nand type 62 substitution or estimation methods cannot be used).\nWhen to use Type 67 substitution\n(h) The Metering Data Provider must only use a type 67 substitution\nwhen:\n(1) directed by the Metering Coordinator;\n(2) not expressly disallowed in this jurisdiction;\n(3) the retail customer-provided meter reading meets the\nvalidation rules for that data stream; or\n(4) the Metering Data Provider has no actual metering data.\n\nRegulations 2016 197\nWhen to use Type 64 or 66 substitution\n(i) Metering Data Providers must not perform type 64 or 66\nsubstitutions without seeking the agreement of the financially\nresponsible participant, the relevant retailer and the Local Network\nService Provider for the connection point. Metering Data Providers\nmay, however, undertake to change the quality flag to an existing\ntype 64 or 66 substitution without seeking further agreement from\nthose parties.\n(j) The Metering Data Provider must notify the relevant parties for the\nconnection point of any substitution or estimation within 2 business\ndays of the substitution or estimation. Notification must comply with\nthe obligations set out in S7A.8.9.11.\nS7A.7.11.2 Substitution and estimation types\nType 61 – Previous year method (average daily consumption\nmethod\n(a) To perform a type 61 substitution, the Metering Data Provider must\nprovide a substitution or estimation of the meter reading by\ncalculating the energy consumption as per the following formula:\nType 62 – Previous meter reading method (average daily\nconsumption method)\n(b) To perform a type 62 substitution, the Metering Data Provider must\nprovide a substitution or estimation of the meter reading by\ncalculating the energy consumption as per the following formula:\n\nRegulations 2016 198\nType 63 – Customer class method\n(c) To perform a type 63 substitution, the Metering Data Provider must\nprovide a substitution or estimation by calculating the energy\nconsumption as per the following formula:\nType 64 – Agreed method\n(d) To perform a type 64 substitution, the Metering Data Provider may\nundertake to use another method of substitution (which may be a\nmodification of an existing substitution type), where none of the\nexisting substitution types are applicable, subject to using\nreasonable endeavours to form an agreement with the financially\nresponsible participant, the relevant retailer and Local Network\nService Provider for the connection point. The specifics of this\nsubstitution type may involve a globally applied method.\nType 66 – ADL method\n(e) [Not used]\nType 66 – Revision of substituted metering data\n(f) To perform a type 66 substitution, the Metering Data Provider must\nre-substitute or change substituted metering data prior to collecting\nan actual meter reading where the financially responsible\nparticipant, the relevant retailer and the Local Network Service\nProvider for the connection point have agreed to revise the original\nsubstituted metering data, on the basis of site or end user specific\ninformation.\nType 67 – Customer reading\n(g) Unless the Metering Data Provider is required to apply a type 68\nsubstitution, the Metering Data Provider must substitute any\npreviously substituted metering data or estimated metering data\nbased directly on a meter reading provided by an end user.\nType 68 – Zero\n(h) The Metering Data Provider must undertake substitutions or\nestimations of ‘zero' where either the Local Network Service\nProvider or Metering Provider has informed the Metering Data\nProvider of a de-energised connection point or an inactive meter\n\nRegulations 2016 199\nand where the consumption is known to be zero.\nS7A.7.12 Substitution and estimation for calculated\nS7A.7.12.1 Substitution rules\n(a) The Metering Data Provider must:\n(1) obtain clear and concise identification as to the cause of any\nmissing or erroneous calculated metering data for which\nsubstituted metering data are required;\n(2) ensure that all substituted metering data and estimated\nmetering data are based on calculated metering data and not\non any previous substitutions or estimations (as applicable);\n(3) base calculated metering data for type 7 metering installations\non inventory table data as follows:\n(i) where the inventory table has not been updated for the\nperiod concerned, calculated metering data must be\nbased on the most recent available information and\nprovided as an estimate; and\n(ii) where the inventory table is correct for the period\nconcerned, the calculated metering data must be flagged\nas ‘A' metering data, however, when the inventory table\nis subsequently updated for the period concerned, the\ncalculated metering data must be flagged as ‘F' metering\n(4) notify the Local Network Service Provider, the relevant\nretailer and the financially responsible participant for the\nconnection point of any substituted calculated metering\ndata within 2 business days of the substitution, and this\nnotification is achieved via the Participant metering data\nfile as detailed within Schedule 7A.8; and\n(5) flag all calculated metering data substitutions as ‘F'.\n(b) The Metering Data Provider may apply the following substitution\nand estimations types:\n(1) substitutions may be type 71, 72, 73, or 74;\n(2) estimations may be type 75.\n\nRegulations 2016 200\nS7A.7.12.2 Substitution and estimation types\nType 71 – Recalculation\n(a) To perform a type 71 substitution, the Metering Data Provider must\nsubstitute calculated metering data with the calculated metering\ndata obtained by a recalculation based on the current inventory\ntables, load tables and on/off tables.\nType 72 – Revised tables\n(b) Where the error in the calculated metering data is due to errors in\nthe inventory table, load table and on/off table, the Metering Data\nProvider must substitute calculated metering data by a recalculation\nbased on the most recent inventory tables, load tables and on/off\ntables in which there were no errors.\nType 73 – Revised algorithm\n(c) Where the error in the calculated metering data is due to an error in\nits calculation, the Metering Data Provider must substitute the most\nrecent calculated metering data for which there was no error.\nType 74 – Agreed method\n(d) The Metering Data Provider may use another method of calculated\nmetering data substitution (which may be a modification of an\nexisting substitution type), where none of the existing substitution\ntypes is applicable, subject to using reasonable endeavours to form\nan agreement between the financially responsible participant, the\nrelevant retailer and Local Network Service Provider for the\nconnection point. The specifics of this substitution type may involve\na globally applied method.\nType 75 – Existing table\n(e) The Metering Data Provider must provide an estimate for the\ncalculated metering data based on the most recent inventory table\nuntil such time as an updated inventory table is received for the\nperiod concerned.\nS7A.7.13 Data validation requirements\nS7A.7.13.1 Validation requirements for all metering installations\nMetering Data Providers must manage systems and processes on\nthe basis that:\n(a) stored metering data held in the meter buffer might be subject\nto installation measurement error;\n\nRegulations 2016 201\n(b) data delivered by reading systems, (for example, remote\nreading systems, hand-held readers and conversion software)\nmight not be recovered from the meters without corruption;\nand\n(c) auditable validation procedures are of critical importance and\ncan have a direct impact on disputes. It is essential that\nMetering Data Providers comply with these validation\nprocedures and that all metering data is subject to validation\nprior to delivery to NTESMO, Registered Participants and\nfinancially responsible participants.\nS7A.7.13.2 Validation of interval metering data alarms\n(a) The Metering Data Provider must validate interval metering data\nagainst the following meter alarms when these are provided in the\nmeter:\n(1) power failure/meter loss of supply;\n(2) voltage transformer or phase failure;\n(3) pulse overflow;\n(4) cyclic redundancy check error; and\n(5) time tolerance.\n(b) Where interval metering installations assign alarms to the data\nchannel and the interval metering data concerned, the Metering\nData Provider must process the alarm along with the metering data\nas part of the required validation.\n(c) The Metering Data Provider must ensure that all metering data\nalarm reports are signed off and dated by the person actioning the\ndata exception report review as part of the validation.\n(d) The Metering Data Provider must validate all interval metering data\nwith all metering data alarms prior to providing to NTESMO,\nRegistered Participants or financially responsible participants.\n(e) All Metering Data Provider exception reports must provide, for all\ninstances where the interval metering data was found to be\ncorrupted, an indication of the subsequent actions undertaken by\nthe Metering Data Provider.\n\nRegulations 2016 202\nS7A.7.13.3 Validation within the meter reading process for manually\nread metering installations\nValidations during collection of interval metering data\n(a) The validations to be performed by Metering Data Providers\nresponsible for the collection of interval metering data from\nmanually read metering installations are as follows:\n(1) the meter serial number matches the recorded meter serial\nnumber;\n(2) the security of the metering installation is intact, for example,\nmeter seals are in place and in good order;\n(3) the time synchronisation of the metering installation is correct\nto ACST inclusive of any load control devices.\nValidations during collection of accumulated metering data\n(b) The validations to be performed by Metering Data Providers\nresponsible for the collection of accumulated metering data are as\nfollows:\n(1) the value of metering data from the current meter reading ≥\nthe value of metering data from the previous meter reading;\n(2) the value of metering data from the current meter reading is\nvalid against an expected minimum value;\n(3) the value of metering data from the current meter reading is\nvalid against an expected maximum value;\n(4) the meter serial number matches the recorded meter serial\nnumber;\n(5) the security of the metering installation is intact, for example,\nmeter seals are in place and in good order;\n(6) the time synchronisation of the metering installation is correct\nto ACST inclusive of any load control devices;\n(7) the dial capacity is checked against the recorded dial capacity.\nS7A.7.13.4 Validation as part of the registration process\nGeneral requirements\n(a) Metering Data Providers must confirm information about the NMI is\nprovided to NTESMO, where this is required in accordance with\nclause 7A.10.1, after any installation or change to a metering\n\nRegulations 2016 203\ninstallation prior to the provision of any metering data to NTESMO\nor Registered Participants for the purposes of settlements.\nValidation of metering data from remotely read metering\n(b) Metering Data Providers must carry out the following validations\nafter any installation or change to a metering installation with\nremote acquisition of metering data prior to the distribution of any\ninterval metering data to NTESMO, Registered Participants or\nfinancially responsible participants for the purposes of settlements\nor billing transactions:\n(1) for instrument transformer connected metering installations,\nthe metering installation is recording metering data correctly,\nin conjunction with the Metering Provider;\n(2) for whole current metering installations, the metering data\ncorrectly pertains to the registered metering installation;\n(3) all data streams are captured.\nValidation of interval metering data from manually read\n(c) The Metering Data Provider must carry out the following validations\nin conjunction with the Metering Provider for manually read interval\nmetering installations after any changes to a metering installation\nprior to the provision of any interval metering data to NTESMO,\nRegistered Participants or financially responsible participants for\nthe purposes of settlements or billing transactions:\n(1) the metering data correctly pertains to the registered metering\n(2) all data streams are captured.\nValidation of accumulated metering data from manually read\n(d) Metering Data Providers must carry out the following validations,\nfollowing any changes to a metering installation and prior to the\nprovision of any accumulated metering data to NTESMO,\nRegistered Participants or financially responsible participants for\nthe purposes of settlements or billing transactions:\n(1) the metering data correctly pertains to the registered metering\n(2) all data streams are captured.\n\nRegulations 2016 204\nValidation of type 7 metering installations\n(e) Metering Data Providers must validate the calculated metering data\non registration of all metering installations to verify that the\ninventory tables, load tables and on/off tables are complete and\ncorrect for the specifics of the metering installation.\nS7A.7.13.5 Validation of metering data\nGeneral\n(a) For metering installations with remote acquisition installed in\naccordance with paragraph 7A.6.8(a), the Metering Data Provider\nmay perform validation in accordance with clauses S7A.7.14.4 and\nS7A.7.14.5, instead of clause S7A.7.14.2.\nValidations for remotely read metering installations\n(b) Metering Data Providers must, as a minimum, undertake the\nfollowing validations within the metering data services database for\nmetering installation types with remote acquisition of metering data:\n(ii) this check may additionally be performed in the polling\nsoftware;\n(2) a check of the maximum value of active energy and reactive\nenergy:\n(i) for current transformer metering installations, the\nmaximum value is to be initially determined by the\nconnected current transformer ratio of the metering\n(ii) for whole current metering installations the maximum\nrating of the meter is to be used;\n(3) a check against a nominated minimum value or, alternatively,\na 'zero' check that tests for an acceptable number of zero\nintervals values per day to be derived from the site's historical\n\nRegulations 2016 205\n(4) a check for null (no values) metering data in the metering data\nservices database for all data streams:\n(i) the aim of this check is to ensure that there is a 100%\nmetering data set (and substitution for any missing\ninterval metering data is undertaken);\n(5) a check for the meter alarms referred to in clause S7A.7.13.2\nand ensure:\n(i) that a process is in place that captures these meter\nalarms within the validation and ensures that any meter\nalarm occurrences are retained as part of the metering\ndata audit trail;\n(ii) the provision of details of the occurrences of meter\nalarms to relevant Registered Participants within the\nmetering data file in accordance with the MDFF\nSpecification.\nValidations for metering installations with checking metering\nor partial check metering\n(c) Metering Data Providers must undertake the following validations\nby comparing the metering data and check metering data for all\nmetering installations that have associated check metering\ninstallations or partial check metering installations:\n(1) for metering installations where the check metering installation\nduplicates the metering installation accuracy, the Metering\nData Provider must validate the metering installation data\nstreams and check metering data streams on a per interval\nbasis, and the average of the two validated metering data sets\nwill be used to determine the energy measurement;\n(2) for installations where the check metering data validation\nrequires a comparison based on nodal balance (comparing\nthe sum energy flow to the busbar against energy flow from\nthe busbar):\nthat will facilitate comparison of interval metering data for\neach energy flow on a per interval basis;\n\nRegulations 2016 206\nascertain whether error differences in nodal balance are\nacceptable;\ndifference for each connection point, based on historical\n(iv) the maximum error difference considered acceptable for\nany connection point is 1% on a per interval basis, and\nthe Metering Data Provider should minimise this for each\nconnection point, based on historical metering data;\n(3) where the check metering installation is remote from the\nmetering installation (for example, at the other end of a\ntransmission line or the other side of a transformer):\nthat will facilitate comparison of interval metering data\nfrom the metering installation and the check metering\ninstallation on a per interval basis with adjustment for\nrespective transformer or transmission line losses;\nascertain whether the error differences between the\nmetering data from the metering installation and check\nmetering installation are acceptable;\ndifference for each connection point, based on historical\n(iv) the maximum error difference considered acceptable for\nany connection point is 5% on a per interval basis, and\nthe Metering Data Provider should minimise this for each\nconnection point, based on historical metering data;\n(4) for connection points where SCADA data is made available by\nNTESMO for the purposes of validation, the Metering Data\nProvider must validate the metering data by comparison of the\ninterval metering data against the SCADA data as provided by\nNTESMO in the agreed format:\n\nRegulations 2016 207\nthat will facilitate comparison of interval metering data\nfrom the metering installation and the SCADA data on a\nper interval basis;\nascertain whether error differences between the interval\nmetering data from the metering installation and the\nSCADA data are acceptable;\ndifference value for each connection point, based on\nhistorical metering data;\n(iv) the Metering Data Provider must construct an\nappropriate validation algorithm as the SCADA data may\nbe derived from a different measurement point, have a\ndifferent interval collection period or have a different\nbase unit of measurement, (for example, power not\nenergy value) with allowances for a larger error of\nmeasurement;\n(5) the Metering Data Provider is only required to undertake\nvalidation of metering data against the SCADA data on the\nprimary data channel i.e. only ‘B' channel validation where the\nfinancially responsible participant is a Generator and only ‘E'\nchannel validation for loads, such as pumps.\nValidations for interval metering data from manually read\nmetering installations with current transformers\n(d) Metering Data Providers must, as a minimum, undertake the\nfollowing validations on interval metering data from manually read\nmetering installations with current transformers within the metering\ndata services database:\n(ii) this check may additionally be performed in the\ncollection software;\n(2) a check of the maximum value of active energy, which must\ninitially be determined by the connected current transformer\nratio of the metering installation (maximum reactive energy\nchecks may also be performed as an option);\n\nRegulations 2016 208\n(3) a check against a nominated minimum value or, alternatively,\na ‘zero' check that tests for an acceptable number of zero\ninterval values per day to be derived from the site's historical\n(4) a check for null (no values) metering data in the metering data\nservices database for all metering data streams:\n(i) the aim of this check is to ensure that there is a 100%\nmetering data set (and that substitution for any missing\ninterval metering data is undertaken);\n(5) a check for meter alarms referred to in clause S7A.7.13.2 and\nensure that:\n(i) a process is in place that captures these meter alarms\nwithin the validation and ensures that any meter alarm\noccurrences are retained as part of the metering data\naudit trail; and\n(ii) the relevant Registered Participants are notified of the\noccurrences of these meter alarms within the metering\ndata file in the MDFF specification;\n(6) where supported by the meter(s), validation for a given period\nof interval metering data by comparison of the totalised\ninterval energy data (accumulation register reading) and the\nchange in the meter cumulative registers (energy tolerance); it\nis acknowledged that this check would not identify current\ntransformer ratio changes that have occurred after initial\ncommissioning and have not been advised to the Metering\nData Provider;\n(7) a check of the metering data for continuity and reasonability\nover the meter reading period:\n(i) check that no gaps in the metering data exist;\n(ii) check that metering data for the expected period has\nbeen delivered based on the scheduled meter reading\n\nRegulations 2016 209\nValidations for interval metering data from whole current\nmanually read metering installations\n(e) Metering Data Providers must, as a minimum, undertake the\nfollowing validations on metering data from whole current manually\nread interval metering installations within the metering data services\ndatabase:\n(ii) this check may additionally be performed in the\ncollection software;\n(2) a check of the maximum value of active energy (maximum\nreactive energy checks may also be performed as an option),\nand the maximum value is to be initially set to the rating of the\nmeter;\n(3) a check for null (no values) metering data in the metering data\nservices database for all metering data streams:\n(i) the aim of this check is to ensure that there is a\n100% metering data set (and that substitution for any\nmissing interval metering data is undertaken);\n(4) a check for meter alarms referred to in clause S7A.7.13.2 and\nthe Metering Data Provider is not required to validate the\ninterval metering data for power outage or power failure\nalarms, but must ensure that:\n(i) a process is in place that captures these meter alarms\nwithin the validation and ensures that any meter alarm\noccurrences are retained as part of the metering data\naudit trail;\n(ii) the relevant Registered Participants are notified of the\noccurrences of these meter alarms within the metering\ndata file in accordance with the MDFF specification;\n\nRegulations 2016 210\n(5) where supported by the meter(s), validation for a given period\nof interval metering data by comparison of the totalised\ninterval energy data (accumulation register reading) and the\nchange in the meter cumulative registers (energy tolerance);\n(6) a check of the metering data for continuity and reasonability\nover the meter reading period:\n(i) check that no gaps in the metering data exist;\n(ii) check that metering data for the expected period has\nbeen delivered based on the scheduled meter reading\nValidations for accumulation metering data from manually read\n(f) Metering Data Providers must undertake the following validations\nwithin the metering data services database for metering\ninstallations with accumulated metering data:\n(1) a check against a nominated minimum value of metering data\ncollected from the metering installation;\n(2) a check against a nominated maximum value of metering data\ncollected from the metering installation, and this is to be\napplied to both the metering data collected from the metering\ninstallation and the calculated energy consumption values;\n(3) the current value of metering data collected from the metering\ninstallation ≥ previous value of metering data collected from\nthe metering installation;\n(4) the current value of metering data collected from the metering\ninstallation is numeric and ≥ 0;\n(5) the current date that metering data is collected from the\nmetering installation > the previous date that metering data\nwas collected from the metering installation;\n(6) a check for null (no values) metering data in the metering data\nservices database for all metering data streams, and the aim\nof this check is to ensure that there is a 100% metering data\nset and substitution for any missing metering data is\nundertaken.\n\nRegulations 2016 211\nValidations for type 7 metering installations\n(g) Metering Data Providers must undertake the following validations of\ncalculated metering data within the metering data services\ndatabase:\n(1) a check against a nominated maximum calculated metering\ndata value;\n(2) for subparagraph (1), calculated metering data value is\nnumeric and ≥ 0;\n(3) a check for null (no values) calculated metering data for all\nmetering data streams, and the aim of this check is to ensure\nthat there is a 100% calculated metering data set (and\nsubstitution for any missing calculated metering data has been\nundertaken);\n(4) a check of the inventory tables, load tables and on/off tables\nusing a process approved by the Metering Coordinator to\nensure that the correct version of these tables is being used\nfor the production of calculated metering data;\n(5) a check against a nominated minimum value, or alternatively,\na ‘zero' check that tests for an acceptable number of zero\nInterval values per day;\n(6) calculated metering data date > previous calculated metering\ndata date.\nS7A.7.14 Determination of metering data for unmetered\nloads\nNote\nObligations for determination of metering data for unmetered load, including\nrequirements and methodologies for calculating metering data and associated\nresponsibilities, will be considered in the event of a type 7 metering installation\nbeing available in this jurisdiction and after a 12 month transitional period\nallowing all participants to achieve compliance.\n\nRegulations 2016 212\nS7A.7.14.1 Load table\nNote\nResponsibility for developing, maintaining and publishing the load table will be\nconsidered in the event of a type 7 metering installation being available in this\njurisdiction and after a 12 month transitional period allowing all participants to\nachieve compliance.\n(a) The load table must set out:\n(1) for each controlled unmetered device, its load (which includes\nany associated control gear, in watts) for use in calculating\ninterval metering data in accordance with clause S7A.7.14.2;\nand\n(2) for each uncontrolled unmetered device, its annual energy\nconsumption in accordance with clause S7A.7.14.3. The\nannual energy consumption is used to calculate the calculated\ndevice wattage (in watts) which is used to calculate the\ninterval metering data for each device type as follows:\nWhere i = Uncontrolled unmetered device type i.\n(b) Proposals to add a new unmetered device load to the load table\nmust include load measurement tests conducted by a NATA\naccredited laboratory or an overseas equivalent.\n(c) Agreement for an unmetered device load to be added to the load\ntable does not replace any obligation for an interested party to\nobtain appropriate approvals related to the performance and\nacceptance of use of the unmetered device.\nS7A.7.14.2 Controlled unmetered devices\nMetering data calculation\n(a) The Metering Coordinator must ensure that the interval metering\ndata for controlled unmetered devices classified as a type 7\nmetering installation are calculated in accordance with the following\nalgorithm:\nInterval metering data for TIj for NMI (in watt hours) =\n\nRegulations 2016 213\ni = device type\nj = TI\nk = proportion of device attributable to that NMI\nTI is in minutes.\nUnmetered device wattage/device wattage is determined from the\nload table.\nUnmetered device count/device count is determined from the\ninventory table.\nPeriod load is switched on is determined from the on/off table.\nInventory table\n(b) For each NMI, a separate inventory table is required that identifies\neach unmetered device type that forms part of the load and for\neach unmetered device type lists:\n(1) the unmetered device type;\n(2) the form of on/off control – photoelectric cell control, timer\ncontrol, ripple control or other control;\n(3) if timer control or ripple control, the on/off times for the timer\ncontrol or the ripple control system;\n(4) if other control, the on/off times;\n(5) if an unmetered device is shared with another NMI, the\nproportion of load that is agreed by affected Registered\nParticipants to be attributable to that NMI (k), and each\nk factor will be less than 1 and the sum of the k factors for a\nshared unmetered device across each respective NMI must\nbe equal to 1;\n(6) if an unmetered device is not shared with another NMI, the\nk factor must be equal to 1;\n(7) the number of such unmetered devices installed;\n(8) the effective start date – the first day on which that record in\nmetering data for that NMI;\n\nRegulations 2016 214\n(9) the effective end date – the last day on which that record in\nmetering data for that NMI; and\n(10) the last change date – the date that record in the inventory\ntable was most recently created or modified.\n(c) Each unmetered device in the inventory table is a unique\ncombination of physical hardware, time control classification and\nshared portion. For example, if an unmetered device is shared with\nanother NMI, the individual portions of the unmetered device(s)\nmust be included in the inventory table as a separate unmetered\ndevice type on each NMI.\n(d) Each Metering Coordinator must develop the initial inventory table\nfor the NMIs for which it is responsible. The initial inventory table\nmust be agreed by each affected Registered Participant and the\nrelevant end user.\n(e) Each Metering Coordinator must update the inventory table for the\nNMIs for which it is responsible on at least a monthly basis to\nensure that the accuracy requirements in clause S7A.7.6.2 are met.\nAny changes to the inventory table may only be made on a\nretrospective basis where:\n(1) agreed by the Metering Coordinator and the affected\nRegistered Participants; or\n(2) necessary to comply with clause 7A.7.4.\n(f) The Metering Coordinator must communicate any material changes\nto the inventory table to the affected Registered Participants.\n(g) The Metering Coordinator must provide the inventory table to\nrelevant Registered Participants when requested.\nOn/off table\n(h) The form of on/off control may be:\n(1) photoelecetric;\n(2) timer control, or ripple control; or\n(3) other control.\n\nRegulations 2016 215\nPhotoelectric cell control\n(i) The Metering Coordinator must ensure that the appropriate sunset\ntimes and sunrise times are obtained from the Australian\nGovernment Geoscience website\n(www.ga.gov.au/geodesy/astro/sunrise.jsp), based on the longitude\nand latitude of the relevant town and Australian Central Standard\nTime.\n(j) The Metering Coordinator must ensure that the period that the load\ncommencing after sunset and\nfinishing prior to sunrise\ncommencing after sunrise and\nfinishing prior to sunset\nwhich the sunset occurs\n(Period load is switched on) =\nwhich the sunrise occurs\n(Period load is switched on) =\nTimer control\n(k) If the on/off times for an unmetered device is controlled by a timer\nor ripple injection system:\n(1) On time = ON time set on timer or ripple injection system;\n(2) Off time = OFF time set on timer or ripple injection system.\n\nRegulations 2016 216\n(l) The Metering Coordinator must ensure that the period that the load\ncommencing after on time and\nfinishing prior to off time\ncommencing after off time and\nfinishing prior to on time\nwhich the on time occurs\nwhich the off time occurs\nOther control\n(m) Where the on/off times for an unmetered device are not in\naccordance with paragraphs (i) to (m), the following alternative\nforms of control may be used:\n(1) On time = sunset time + ON delay or ON time set on timer or\nripple injection system;\n(2) Off time = sunrise time + OFF delay or OFF time set on timer\nor ripple injection system or a fixed duration after ON time.\n(n) Where sunrise or sunset times are used, the time is determined in\naccordance with paragraph (j).\n(o) The Metering Coordinator must ensure that the period that the load\ncommencing after on time and\nfinishing prior to off time\ncommencing after off time and\nfinishing prior to on time\n\nRegulations 2016 217\nwhich the on time occurs\nwhich the off time occurs\nS7A.7.14.3 Uncontrolled unmetered devices\n(a) [Not used]\nEnergy calculation\n(b) The Metering Coordinator must ensure that the interval metering\ndata for other unmetered loads, which have been classified as a\ntype 7 metering installation, is calculated in accordance with the\nfollowing algorithm:\nInventory table\n(c) For each NMI, a separate inventory table is required that identifies\neach device type that forms part of the NMI load and for each\ndevice type lists:\n(1) the device type;\n(2) the form of on/off control (24 hours per day);\n(3) if a device is shared with another NMI, the proportion of load\nthat is agreed by relevant financially responsible participants\nto be attributable to that NMI (k), and each k factor will be less\nthan 1 and the sum of the k factors for a shared unmetered\ndevice across each respective NMI must be equal to 1;\n(4) if a device is not shared with another NMI, the k factor must be\nequal to 1;\n(5) the number of such devices installed;\n(6) the effective start date – the first day on which that record in\nmetering data for that NMI;\n\nRegulations 2016 218\n(7) the effective end date – the last day on which that record in\nmetering data for that NMI; and\n(8) the last change date – the date that record in the inventory\ntable was most recently created or modified.\n(d) Each device in the inventory table is a unique combination of\nphysical hardware, time control classification and shared portion.\nFor example, if a device is shared with another NMI, the individual\nportions of the device(s) must be included in the inventory table as\na separate device type on each NMI.\n(e) Each Metering Coordinator must develop the initial inventory table\nfor the NMIs for which it is responsible. The initial inventory table\nmust be agreed by the relevant financially responsible participants\nand the relevant end-use customer.\n(f) Each Metering Coordinator must use reasonable endeavours to\nupdate the inventory table, for the NMIs for which it is responsible,\non at least a monthly basis for any additions, deletions and\nmodifications to ensure that the accuracy requirements in\nclause S7A.7.6.2 are met. Such additions, deletions or\nmodifications to the inventory table may only be made on a\nretrospective basis where:\n(1) agreed by the Metering Coordinator and the relevant\nfinancially responsible participants; or\n(2) necessary to comply with clause 7A.7.6.\n(g) The Metering Coordinator must communicate any material changes\nto the inventory table to the relevant financially responsible\nparticipants.\n(h) The Metering Coordinator must provide the inventory table to\nrelevant financially responsible participants when requested.\nOn/off table\n(i) Other unmetered loads are assumed to operate 24 hours per day.\n(j) For each recording interval period load is switched on = 1.\n\nRegulations 2016 219\nSchedule 7A.8 Service level procedures\nPart A Introduction\nS7A.8.1 Introduction\nS7A.8.1.1 Purpose and scope\n(a) This schedule applies to Metering Providers and Metering Data\nProviders.\n(b) This schedule sets out:\n(1) the requirements for the provision, installation and\nmaintenance of metering installations by Metering Providers;\n(2) requirements for the systems and processes for the collection,\nprocessing and delivery of metering data by Metering Data\nProviders;\n(3) the performance levels associated with the collection,\nprocessing and delivery of metering data;\n(4) the data formats that must be used for the delivery of metering\n(5) the requirements for the management of relevant NT NMI\nData; and\n(6) the requirements for the processing of metering data\nassociated with connection point transfers and the alteration of\nmetering installations where one or more devices are\nreplaced.\nS7A.8.1.2 Definitions\ncollect, collection, collected mean a process undertaken by the\nMetering Data Provider to obtain metering data from a meter or\nService Providers means Metering Data Providers, Metering\nProviders and Local Network Service Providers.\n\nRegulations 2016 220\nPart B Metering provider services\nS7A.8.2 Introduction\nS7A.8.2.1 Purpose and exclusions\n(a) Part B of this schedule:\n(1) details the obligations, technical requirements, measurement\nprocess and performance requirements that are to be\nperformed, administered and maintained by a Metering\nProvider;\n(2) details the obligations and technical/operational requirements\nin the provision, installation and maintenance of the metering\ninstallation by a Metering Provider;\n(3) relates to Metering Providers who undertake the provision,\ninstallation and maintenance of various metering installation\ntypes as stipulated; and\n(4) sets out minimum requirements for Metering Providers.\n(b) For service provision at connection points where:\n(1) the Metering Provider and the Metering Data Provider are part\nof the same company; and\n(2) metering installation provision or maintenance work is\nperformed using internal processes and procedures,\nthose internal processes and procedures will be deemed to be\ncompliant with this Part if the metering work satisfies the\nperformance and quality outcomes of this Part.\nS7A.8.2.2 Services\nThe Metering Provider is responsible for the provision of metering\nprovision services, including but not limited to:\n(a) maintaining the ongoing metering installation compliance with\n(b) the provision and maintenance of physical metering\ninstallation security controls;\n(c) the provision, installation and maintenance of the metering\n\nRegulations 2016 221\n(d) the maintenance of metering installation password security;\nand\n(e) the development and maintenance of an Asset Test Plan.\nS7A.8.3 General requirements\nS7A.8.3.1 Metering Provider capability and competency\nMetering Providers must:\n(a) employ personnel with the skills, knowledge and expertise\nnecessary for the discharge of the responsibilities under\nChapter 7A and have procedures for ensuring that personnel\nmaintain their knowledge and understanding of the\nrequirements of the Rules;\n(b) maintain a register of employees, which for each employee\nmust include:\n(1) skills, knowledge and expertise;\n(2) qualifications, registrations and accreditations where\napplicable to the discharge of Metering Provider duties;\n(3) training undertaken and planned;\n(4) authorisations to provide opinions and interpretations of\ntechnical information; and\n(5) authorisations to access metering installations within\nsecure and restricted areas;\n(c) have policies and procedures for making statements of\nopinions and interpretations, documented within the quality\nsystem;\n(d) comply with:\n(1) AS 3000 Wiring Rules;\n(2) applicable Australian Communications and Media\nAuthority (ACMA) communications and cabling\n(3) C-Tick compliance requirements;\n(4) jurisdictional legislation, including safety legislation and\nregulations; and\n\nRegulations 2016 222\n(5) any reasonable requirements of the Local Network\nService Provider when working on or around Local\nNetwork Service Provider.\nS7A.8.3.2 Use of contractors\nWhere a Metering Provider engages a sub-contractor to perform\nany of its obligations specified in the Rules, the Metering Provider:\n(a) must have policies and procedures for assessing the sub-\ncontractor's capability, competency and processes,\nprocedures and systems, to ensure that they are compliant\nwith the Rules;\n(b) must ensure that auditable processes are in place to certify\nthat all work performed by the sub-contractor complies with\n(c) remains liable for all acts and omissions of any sub-contractor;\nand\n(d) must authorise the sub-contractor to provide any specific\nopinion or interpretation of technical information.\nS7A.8.3.3 Insurance\n(a) hold public liability insurance for an amount not less than\n$10,000,000 per occurrence;\n(b) hold professional indemnity insurance for an amount of not\nless than $1,000,000 per occurrence; and\n(c) provide the Utilities Commission with certified current copies\nof insurance policies on request.\nNote\nIf a Metering Data Provider, Metering Provider and Metering Coordinator are the\nsame legal entity, a single insurance policy for public liability insurance for an\namount not less than $10,000,000 per occurrence and professional indemnity\ninsurance for an amount of not less than $1,000,000 per occurrence that covers\nthe operations of the Metering Data Provider, Metering Provider and Metering\nCoordinator roles will satisfy the insurance requirements under this schedule.\nS7A.8.4 Device management and test equipment\nS7A.8.4.1 Procurement\nThe Metering Provider must have processes and systems in place\nfor the procurement of meters, instrument transformers and any\n\nRegulations 2016 223\nother devices that can be installed by the Metering Provider within a\nmetering installation, and ensure that metering installation\ncomponents are suitable for use in accordance with the Rules.\nS7A.8.4.2 Storage, handling and transport\n(a) The Metering Provider must have processes that are consistent\nwith good industry practice, specifying the requirements for storage,\nhandling (including packaging) and transport (including return to\nowner) of any equipment that is calibrated including meters,\ninstrument transformers and test equipment. The processes must\nbe designed to:\n(1) minimise the risk of physical or environmental damage to the\nequipment; and\n(2) identify conditions under which the physical condition of the\nequipment or accuracy is compromised as a result of storage,\ntransport or handling.\n(b) The Metering Provider must ensure that meters, instrument\ntransformers and devices removed from the metering installation\nare returned to their owner within 10 business days following their\nremoval, unless otherwise agreed with the owner.\nS7A.8.4.3 Management of test equipment\n(a) establish a register of test equipment used for testing metering\ninstallations, meters and instrument transformers;\n(b) maintain records of test equipment, including records of\ncalibration certificates, for at least 7 years from the issue date\nof the calibration certificate;\n(c) ensure that all test equipment is calibrated by a NATA\naccredited testing laboratory holding ISO 9001 and 17025\naccreditation for the calibration of test equipment, current at\nthe time of calibration; and\n(d) ensure that all tests are undertaken with test equipment where\nthe calibration certificate is current and stated calibration due\ndate has not passed.\n\nRegulations 2016 224\nS7A.8.4.4 Management of meter programming and authorised software\n(a) establish a register of equipment and authorised software\nused for programming meters; and\n(b) maintain records of equipment, authorised software and\nprograms used for programming meters, including any\nchanges to firmware or software within the meter, for at least\n7 years from the most recent date of use.\nS7A.8.5 Installation and commissioning requirements\nS7A.8.5.1 General commissioning requirements\nThe Metering Provider must develop, maintain and operate\nprocesses and procedures for the installation and commissioning of\nmetering installations for which they are accredited, which must\ninclude installation and verification requirements to ensure that:\n(a) electrical wiring at the metering installation is:\n(1) wired and terminated in compliance with meter and\ninstrument transformer manufacturer requirements,\nrelevant Australian Standards and jurisdictional\n(2) terminated in a manner that ensures no electrical\nconductors are exposed, that the cable type and size,\nand number of cables terminated in any one termination\nare appropriate and that all terminations are tight;\n(3) of an appropriate cable type, size and insulation that\nmeets the requirements of AS 3000;\n(4) connected with the correct polarity at each termination\nand connection; and\n(5) connected with the correct phase sequence, where three\nphases are connected at the metering installation; in the\ncase of a change to an existing metering installation, the\nexisting phase sequence is maintained;\n(b) the accuracy class of metering installations and any\ndocumentation from a certified body verifying the errors of\nmeters and instrument transformers comply with the Rules;\n(c) nameplate information reflects the design accuracy class of\nthe meters and instrument transformers;\n\nRegulations 2016 225\n(d) the actual connected ratios of all instrument transformers at a\nmetering installation and the calculation of the constant to be\napplied to the collection and processing of metering data by\nthe Metering Data Provider are aligned;\n(e) burdens applied to instrument transformers are within the\nrated burden specified on the name plate of the instrument\ntransformer;\n(f) voltage phase sequence relationships are correct unless the\nMetering Provider can verify to the satisfaction of NTESMO\nthe accuracy of the metering installation when a non-standard\nphase sequence is applied;\n(g) the combined current and voltage phase relationships at the\nmeter terminals are correct;\n(h) the meter programming parameters, display and error\nfunctions are all correct in accordance with manufacturer\nspecifications, including the measurement of the forward\nrotation of energy applied to the meter, and that the correct\npulse rates have been programmed into the meter;\n(i) where the metering installation includes instrument\ntransformers, register readings are validated by use of a load\nbeing placed on the load side of the metering installation and\nmay include a timing check by comparing the readings on the\nmeter display or pulse indicators against load and time;\n(j) where the metering installation has meter alarms, occurrences\nof alarms identified on commissioning are investigated and\nresolved prior to leaving the site;\n(k) where an aerial or antenna is installed as part of the metering\ninstallation, it is installed in accordance with the\nmanufacturer's instructions and in a manner that maintains the\nintegrity of the meter enclosure, including water and\nenvironmental seals; and\n(l) the time setting of the metering installation is referenced in\naccordance with clause 7A.8.8.\n\nRegulations 2016 226\nS7A.8.5.2 Metering data validation requirements\nThe Metering Provider must develop, maintain and operate\nprocesses and procedures for the validation of interval metering\ndata with the Metering Data Provider on the installation or alteration\nof that metering installation, which must include processes to\nensure that:\n(a) metering data is validated in accordance with schedule S7A.7;\n(b) where validation has failed or cannot reasonably be\nundertaken, the Metering Provider informs the Metering Data\nProvider and the Metering Coordinator that the metering\ninstallation cannot be validated and undertake wiring checks\nwhich visibly verify correct connection and phase relationships\nof voltage and current circuits and also undertake one or more\nof the following alternative measurements and commissioning\nchecks to enable the Metering Coordinator and Metering\nProvider to confirm that the metering installation complies with\nthe Rules:\n(1) utilisation of meter energy measurement to calculate\nload/ demand and that this value is reflective of expected\nmagnitude;\n(2) use of a dummy load or phantom load box to verify\ncorrect energy measurement at the metering installation;\nand\n(3) compare meter measurement of energy or load with an\nalternative measurement of demand, current and other\nmeasurements of electrical energy;\n(c) where the Metering Provider has undertaken in-situ testing to\nverify correct energy measurement at the metering installation,\nthe Metering Provider informs the Metering Data Provider of\nthe start and end times of the test to facilitate the Metering\nData Provider substituting and validating metering data.\nS7A.8.6 Metering installation maintenance\nS7A.8.6.1 Test plans\n(a) The Metering Provider must develop and maintain Asset Test Plans\nthat provide confirmation of the Metering Provider's testing\napproach to ensure metering installations are maintained:\n(1) in accordance with the testing and inspection requirements of\n\nRegulations 2016 227\n(2) in accordance with approved Asset Management Strategies;\nor\n(3) in any combination of the above.\n(b) As a minimum, the Metering Provider's Asset Test Plans must\ninclude:\n(1) the approach to testing and inspecting for each metering\ninstallation, or groups of metering installations;\n(2) where appropriate, the approach to testing and inspecting\nvarious device types; and\n(3) the details of the test equipment and test methodology to be\nemployed in undertaking works considered in the test plan.\nS7A.8.6.2 Management of metering installation malfunctions\n(a) The Metering Provider must have processes and systems to\nsupport the Metering Coordinator in identifying and rectifying a\nmetering installation malfunction in the timeframes specified in\nclause 7A.6.9.\n(b) Where a Metering Provider identifies a metering installation\nmalfunction, the Metering Provider must advise the Metering Data\nProvider and the Metering Coordinator within 1 business day of\nidentification in accordance with paragraph 7A.6.9(d).\nS7A.8.6.3 Telecommunications\n(a) The Metering Provider must advise the Metering Data Provider and\nthe Metering Coordinator if communications equipment is to be\ntemporarily disconnected such that it may affect the remote\nacquisition of metering data.\n(b) The Metering Provider must use reasonable endeavours to assist\nthe Metering Coordinator and the Metering Data Provider with the\nmanual collection of metering data from the metering installation\nwhere remote acquisition becomes unavailable.\nS7A.8.6.4 Non-conforming test results or calibrations\nThe Metering Provider must have a process for the management of\nnon-conforming test results or calibrations at a metering installation,\nand for devices removed from a metering installation for testing and\nevaluation, which must include:\n(a) a process to perform the evaluation of the non-conformance;\n\nRegulations 2016 228\n(b) authority for management of the non-conformance;\n(c) notification of the non-conformance to parties affected by the\nnon-conformance, which must include the Metering\nCoordinator, Metering Data Provider, financially responsible\nparticipant, Local Network Service Provider and NTESMO;\nand\n(d) initiation of corrective action.\nS7A.8.7 Systems and administration\nS7A.8.7.1 Register of metering installations\n(a) The Metering Provider must establish and maintain a register of\nmetering installations which must include:\n(1) the identity and characteristics of metering equipment\n(instrument transformers, metering installation and check\nmetering installation), including:\n(i) serial numbers;\n(ii) metering installation identification name;\n(iii) metering installation types and models;\n(iv) instrument transformer ratios (available and connected);\n(v) current test and calibration programme details, test\nresults and references to test certificates;\n(vi) asset management plan and testing schedule;\n(vii) calibration tables, where applied to achieve metering\ninstallation accuracy;\n(viii) Metering Provider(s) and Metering Data Provider(s)\ndetails;\n(ix) summation scheme values and multipliers; and\n(x) data register coding details;\n(2) for metering installations for connection points in a market\noperated or administered by NTESMO – any matters identified\nby NTESMO in a communication guideline issued in from time\nto time accordance with clause S7A.1.3.\n\nRegulations 2016 229\n(b) The register must be retained electronically for at least 13 months\nfor each metering installation from when the details of the metering\ninstallation are first recorded in the register and may be archived\nafter this period.\n(c) The register must be retained for at least 7 years for each metering\ninstallation from when the details of the metering installation are\nfirst recorded in the register and any archiving retrieval mechanisms\nmust facilitate analysis and management of information using the\nsame processing rules applied to the electronic register.\n(d) The Metering Provider must provide information from their register\nof metering installations to a party authorised to receive data in\naccordance with clause 7A.13.5 in a timeframe agreed with that\nparty.\nS7A.8.7.2 Disaster recovery\n(a) The Metering Provider must establish and maintain a disaster\nrecovery plan and business continuity processes that include:\n(1) detailed documentation that is maintained up to date,\nshowing revisions and the date of the last review;\n(2) confirmation at least annually by the Metering Provider's\nmanagement that the plan is current for the systems and\nprocesses in place; and\n(3) confirmation that the plan has been subjected to an\nannual end-to-end test that facilitates both a ‘fail-over'\nfrom and ‘recovery' back to the production system.\n(b) In the event of an IT system failure, the Metering Provider must\nensure that systems are returned to normal operational service\nwithin 5 business days of the failure, as evidenced by:\n(1) the software and the most recent back-up of data being\nrestored to operational service within the 5 business days; and\n(2) no outstanding processing or delivery of NT NMI Data to\nNTESMO and Registered Participants.\n(c) The Metering Provider must at its earliest opportunity notify\nNTESMO of any failure where the Metering Provider has a\nrequirement to implement its disaster recovery plan.\nS7A.8.7.3 Audits undertaken by the Utilities Commission\nThe Metering Provider must undertake all services in a manner that\nis auditable by the Utilities Commission and must provide all\n\nRegulations 2016 230\nreasonable assistance to the Utilities Commission in discharging its\nobligations under the Rules and any relevant jurisdictional\nlegislation in relation to metering installations.\nPart C Metering Data Provider services\nS7A.8.8 Introduction\nS7A.8.8.1 Purpose\n(a) The purpose of Part C of this schedule is to detail the obligations,\ntechnical requirements, measurement processes and performance\nrequirements that are to be performed, administered and\nmaintained by the Metering Data Provider.\n(b) This Part details:\n(1) the obligations of Metering Data Providers in the provision of\nmetering data services;\n(2) the obligations of Metering Data Providers to establish and\nmaintain a metering data services database; and\n(3) the obligations of Metering Data Providers in support of the\nMetering Coordinator.\nS7A.8.8.2 Obligations\nMetering data services\n(a) Each Metering Data Provider must:\n(1) provide metering data services in accordance with the Rules\nand relevant jurisdictional codes and policies;\n(2) establish, maintain and operate a metering data services\ndatabase;\n(3) ensure that metering data is kept confidential and secure and\nonly provided to persons entitled to have such access in\naccordance with the Rules;\n(4) undertake the collection, processing and delivery of metering\ndata and meter alarm occurrences; and\n(5) co-operate in good faith with NTESMO, and all Registered\nParticipants, Metering Providers and Metering Data Providers.\n\nRegulations 2016 231\nInsurance\n(b) The Metering Data Provider must:\n(1) hold public liability insurance for an amount not less than\n$10,000,000 per occurrence; and\n(2) hold professional indemnity insurance for an amount of not\nless than $1,000,000 per occurrence.\nNote\nIf a Metering Data Provider, Metering Provider and Metering Coordinator are the\nsame legal entity, a single insurance policy for public liability insurance for an\namount not less than $10,000,000 per occurrence and professional indemnity\ninsurance for an amount of not less than $1,000,000 per occurrence that covers\nthe operations of the Metering Data Provider, Metering Provider and Metering\nCoordinator roles will satisfy the insurance requirements under this schedule.\nUse of sub-contactors\n(c) Where a Metering Data Provider engages a sub-contractor to\nperform any of the Metering Data Provider's obligations specified in\nthe Rules, the Metering Data Provider:\n(1) must have policies and procedures for assessing the sub-\ncontractor's capability, competency, processes, procedures\nand systems, to ensure that the sub-contractor complies with\n(2) must ensure that auditable processes are in place to certify\nthat all work performed by the sub-contractor complies with\n(3) remains liable for all acts and omissions of its sub-contractor;\n(4) must authorise the sub-contractor to provide any specific\nopinion or interpretation of technical information where a\nMetering Data Provider so engages a sub-contractor; and\n(5) must provide the Utilities Commission, on request, with any\ninformation pertaining to the sub-contractor that the Utilities\nCommission reasonably considers necessary for the\ndischarge of the Metering Data Provider's responsibilities\nunder the Rules.\nSpecific obligations\n(d) Each Metering Data Provider must:\n(1) undertake validation, substitution and estimation of metering\ndata in accordance with schedule S7A.7 Part C;\n\nRegulations 2016 232\n(2) provide metering data services;\n(3) ensure registered details of the connection point are fully\nrecorded in the Metering Data Provider's metering data\nservices database;\n(4) ensure metering details and parameters within the metering\ndata services database are correct such that the metering\ndata in the metering data services database is accurate;\n(5) facilitate the timely commissioning and registration of the\n(6) establish and maintain a metering register in its metering data\nservices database.\nMetering register\n(e) Each Metering Data Provider must ensure that information in its\nmetering register is:\n(1) registered in co-operation with the Metering Coordinator and\nMetering Provider;\n(2) provided on request to persons entitled to have access to that\ninformation in accordance with paragraph 7A.13.5(c);\n(3) communicated to other Metering Data Providers having the\nright of access as a result of the transfer of a connection point;\n(4) populated with the following:\n(i) connection and metering point reference details,\nincluding:\n(A) agreed locations and reference details (for\nexample, drawing numbers);\n(B) loss compensation calculation details;\n(C) site identification names;\n(D) details of financially responsible participants and\nLocal Network Service Providers associated with\nthe connection point;\n(E) details of the Metering Coordinator;\n\nRegulations 2016 233\n(ii) the identity and characteristics of metering equipment\n(that is, instrument transformers, metering installation\nand check metering installation), including:\n(A) serial numbers;\n(B) metering installation identification name;\n(C) metering installation types and models;\n(D) Metering Provider(s) and Metering Data Provider(s)\ndetails;\n(E) summation scheme values and multipliers; and\n(F) data register coding details;\n(iii) for types 1, 2, 3 and 4 metering installations, data\ncommunication details, if relevant, including:\n(A) telephone number(s) for access to energy data;\n(B) communication equipment type and serial\nnumbers;\n(C) communication protocol details or references;\n(D) data conversion details;\n(E) user identifications and access rights; and\n(F) 'write' password (to be contained in a hidden or\nprotected field);\n(iv) data validation, substitution and estimation processes\nagreed between affected parties, including;\n(A) algorithms;\n(B) data comparison techniques;\n(C) processing and alarms (for example, voltage\nsource limits; phase angle limits);\n(D) check metering compensation details; and\n(E) alternate data sources; and\n\nRegulations 2016 234\n(5) for metering installations for connection points in a market\noperated or administered by NTESMO, includes any relevant\nmatters identified by NTESMO in a communication guideline\nissued from time to time in accordance with clause S7A.1.3.\nS7A.8.9 Service requirements\nS7A.8.9.1 System requirements\nEach Metering Provider must maintain and operate a metering data\nservices database to facilitate the:\n(a) collection of metering data;\n(b) processing, calculation, validation, substitution and estimation\nof metering data;\n(c) delivery of metering data and metering register data to\nNTESMO, Registered Participants, financially responsible\nparticipants and other Service Providers;\n(d) assignment and version control of participant roles for\nconnection points;\n(e) commissioning of each metering installation into the Metering\nData Provider's metering data services database;\n(f) loading of metering data relating to meter churn; and\n(g) storage and archiving of metering data and validated metering\ndata from the metering installation.\nS7A.8.9.2 Metering data services database\nEach Metering Data Provider must maintain and operate a metering\ndata services database that provides a full audit trail and version\ncontrol capability. This functionality must be applied to:\n(a) metering data;\n(b) assigned data quality flags;\n(c) substitution and estimation types;\n(d) meter alarms;\n(e) metering register information;\n(f) the delivery of metering data to Registered Participants,\nfinancially responsible participants and NTESMO; and\n\nRegulations 2016 235\n(g) the mapping of all metering data streams (including logical\nmetering data streams).\nS7A.8.9.3 Exception reports\nEach Metering Data Provider must maintain, operate and monitor a\nsystem that supports the detection of system or process errors.\nThese exception reports must include, but not be limited to:\n(a) missed reads and missing intervals of metering data within the\nmetering data services database;\n(b) long term substitutions and estimations;\n(c) metering data errors and data overlaps;\n(d) validation or metering register errors;\n(e) failed batch processing, database errors and hardware\nfailures;\n(f) the capture of file syntax errors, failed and rejected metering\ndata deliveries;\n(g) status management of collection interfaces; and\n(h) status management of metering installation malfunctions.\nS7A.8.9.4 Collection process requirements\n(a) Each Metering Data Provider must use reasonable endeavours to\nensure actual meter readings and occurrences of meter alarms are\ncollected for all connection points.\n(b) Each Metering Data Provider must operate a process that:\n(1) records and logs faults and problems associated with the\nreading function of meters, and this process must record and\nlog, but is not limited to, any:\n(i) access problems;\n(ii) metering installation security problems;\n(iii) metering installation faults;\n(iv) read failures; and\n(v) metering installation time synchronisation errors; and\n\nRegulations 2016 236\n(2) supports the Metering Coordinator, the Metering Provider, or\nboth, in the rectification of any metering installation\nmalfunctions or problems associated with the reading function\nof meters.\n(c) On request by the financially responsible participant, a Metering\nData Provider must use reasonable endeavours to carry out a\nspecial meter reading or final reading within 3 business days of the\nreceipt of the request unless an alternative timeframe has been\nagreed.\nS7A.8.9.5 Specific collection process requirements for remotely read\n(a) Each Metering Data Provider must be capable of initiating a remote\nacquisition for metering data from type 1 to 3 metering installations\nwhere relevant metering data is missing, erroneous or has failed\nvalidation.\n(b) Each Metering Data Provider must operate and maintain a process\n(1) initiates an alternative method to collect metering data where\nremote acquisition becomes unavailable; and\n(2) provides a log detailing successful reading events for each\nmetering installation, or alternatively an exception report of\nfailed meter readings.\nS7A.8.9.6 Specific collection process requirements for manually read\nEach Metering Data Provider must:\n(a) develop and maintain a meter reading schedule in accordance\nwith Schedule 7A.7 Part B;\n(b) maintain reading routes with particular attention to any specific\naccess requirements and hazard information;\n(c) use reasonable endeavours to ensure that metering data is\ncollected at least once every 3 months;\n(d) ensure that scheduled reading date lists and programmed\nreading equipment is provisioned, updated and maintained;\n(e) use reasonable endeavours to ensure that metering data is\ncollected within 2 business days prior to or 2 business days\nsubsequent to a scheduled reading date; and\n\nRegulations 2016 237\n(f) ensure that all metering data collected and any fault reason\ncodes associated with a reading failure are transferred to the\nmetering data services database within 1 business day of the\ndata being collected or attempted to be collected from the\nS7A.8.9.7 Metering data processing requirements\nGeneral\n(a) Each Metering Data Provider must have a process to:\n(1) confirm and utilise the roles for connection points;\n(2) assign and store the date/time stamp of when the metering\ndata was entered into the Metering Data Provider's metering\ndata services database;\n(3) ensure that all metering data is stored in the metering data\nservices database with the correct:\n(i) quality flag;\n(ii) applicable substitution or estimation type code; and\n(iii) applicable substitution or estimation reason code;\n(4) check the metering data services database for missing\nmetering data and overlaps;\n(5) aggregate interval metering data for a connection point into a\n30-minute interval net metering data stream prior to delivery to\nNTESMO or financially responsible participants in accordance\nwith the Rules;\n(6) load metering data in an alternative format provided by a\nMetering Provider where there is a communications error,\nfailed reading or metering installation malfunction that\nprevents the normal collection of metering data from a\n(7) whenever any substitutions or estimations are carried out,\nnotify:\n(i) NTESMO (in respect of a metering installation used for\nthe purposes of settlements);\n(ii) Registered Participants for the connection point; and\n\nRegulations 2016 238\n(iii) financially responsible participants (in respect of a\nmetering installation used for the purposes of billing\ntransactions).\nErroneous data\n(b) Where the Metering Coordinator or Metering Provider informs a\nMetering Data Provider of a situation that may cause metering data\nto be erroneous, the Metering Data Provider must identify and\nsubstitute any erroneous metering data.\n(c) Where any Registered Participant for the connection point disputes\nmetering data, the Metering Data Provider must investigate, and, if\nnecessary correct the metering data in accordance with\nSchedule 7A.7 Part C.\nMeter alarms\n(d) Where a meter alarm has occurred, the Metering Data Provider\nmust process the occurrence of the meter alarm along with the\nmetering data as part of the validation process in accordance with\nSchedule 7A.7 Part C.\nS7A.8.9.8 Specific metering data processing requirements for type 1, 2, 3\nand 4 metering installations\nEach Metering Data Provider must be able to undertake simple\ncumulative or subtractive processes to manage complex metering\nconfigurations. Typically, the system must support:\n(a) an A+B+C or A-B-C aggregation configuration;\n(b) validation capability for standard partial or check meter\nconnection points that incorporate a simple comparison of a\nsingle metering data stream to a single check metering data\nstream within an acceptable tolerance; and\n(c) the calculation of the average of the 2 validated data sets for\nmetering installations where the check metering installation\nduplicates the metering installation and accuracy level, and\nthe average of the 2 validated data sets must be delivered to:\n(1) NTESMO (in respect of a metering installation used for\nthe purposes of settlements);\n(2) Registered Participants; and\n(3) financially responsible participants (in respect of a\nmetering installation used for the purposes of billing\ntransactions).\n\nRegulations 2016 239\nS7A.8.9.9 Specific metering data processing requirements for type 7\nInventory tables, load tables and on/off tables\n(a) Each Metering Data Provider must store inventory tables, load\ntables and on/off tables in the metering data services database\n(b) Each Metering Data Provider must ensure:\n(1) inventory tables are complete, correct and updated with any\nchanges provided by the Local Network Service Provider or\n(2) on/off tables are complete and correct; and\n(3) load tables are complete and correct.\n(c) Each Metering Data Provider must ensure the inventory table, load\ntable and on/off table are versioned for metering data calculations.\nProcessing of calculated metering data\n(d) Each Metering Data Provider must ensure that all calculated\nmetering data is validated and processed into recording intervals.\nS7A.8.9.10 Specific metering data estimation requirements for\nmanually read and type 7 metering installations\n(a) Each Metering Data Provider must have a process for the creation\nof estimated metering data for type 4A, 5, 6 and 7 metering\n(b) To meet metering data delivery requirements, this process must\neither:\n(1) create individual blocks of estimated metering data on a daily\nbasis; or\n(2) create a single block of estimated metering data:\n(i) from the date of the last meter reading to a period\nbeyond the next scheduled reading date for type 4A, 5\nand 6 metering installations; or\n(ii) from the date of the last calculation to a period beyond\nthe next scheduled calculation for type 7 metering\n\nRegulations 2016 240\nS7A.8.9.11 Delivery performance requirements for metering data\nObligation to deliver information to NTESMO\n(a) Where this clause S7A.8.9.11 imposes an obligation on a Metering\nData Provider to deliver metering data or other information to\nNTESMO, that obligation only applies in respect of a metering\ninstallation that is used for the purposes of settlements.\nObligation to deliver information to financially responsible\nparticipants\n(b) Where this clause S7A.8.9.11 (other than paragraph S7A.8.9.11(e))\nimposes an obligation on a Metering Data Provider to deliver\nmetering data or other information to financially responsible\nparticipants, that obligation only applies in respect of a metering\ninstallation that is used for the purposes of billing transactions.\nValidated metering data to be delivered\n(c) Each Metering Data Provider must ensure only validated metering\ndata is delivered to NTESMO, Registered Participants and\nfinancially responsible participants.\nDelivery timing requirements\n(d) Subject to any agreement to the contrary as contemplated by\nclause S7A.8.13.1, each Metering Data Provider must:\n(1) deliver to NTESMO, Registered Participants and financially\nresponsible participants all actual meter readings that passed\nvalidation within 2 business days of the actual meter readings\nbeing received into the metering data services database;\n(2) substitute, validate and deliver to NTESMO, Registered\nParticipants and financially responsible participants the\nsubstituted metering data within 2 business days of the actual\nmeter readings being received into the metering data services\ndatabase and failing validation;\n(3) substitute, validate and deliver to NTESMO, Registered\nParticipants and financially responsible participants the\nsubstituted metering data within 2 business days of the receipt\nof any fault reason codes associated with a reading failure or\nfailed interrogation event, into the metering data services\ndatabase;\n\nRegulations 2016 241\n(4) validate and deliver to NTESMO, Registered Participants and\nfinancially responsible participants all substituted metering\ndata within 2 business days of the metering data being\nsubstituted;\n(5) ensure that all metering data is delivered to NTESMO,\nRegistered Participants and financially responsible\nparticipants for the full period of any retrospectively created\nmetering data streams within 2 business days of that metering\ndata streams being created; and\n(6) for type 4A, 5, 6 and 7 metering installations, validate and\ndeliver to NTESMO, Registered Participants and financially\nresponsible participants all estimated metering data within\n2 business days of the metering data being estimated.\n(e) Each Metering Data Provider must provide metering data to the\nrelevant financially responsible participants within 2 business days\nof receiving a completed notification of a change of financially\nresponsible participants, including estimated metering data, for a\ntype 4A, 5, 6 or 7 metering installation.\nReview of failed validations\n(f) Each Metering Data Provider must ensure that all failed validations\nare reviewed promptly so as to:\n(1) where the initial review of the failed validation identifies that\nthe actual meter readings are valid, deliver the actual meter\nreadings to NTESMO, Registered Participants and financially\nresponsible participants within 2 business days of the\nmetering data being received into the metering data services\ndatabase; and\n(2) where further information is required to validate the actual\nmeter readings, and the receipt of such information identifies\nthat the actual meter readings are valid, deliver the actual\nmeter readings to NTESMO, Registered Participants and\nfinancially responsible participants within 2 business days of\nthe metering data passing validation.\nOperational delays\n(g) The Metering Data Provider must notify NTESMO and affected\nRegistered Participants immediately upon the identification of any\noperational delays impacting on normal metering data delivery.\n\nRegulations 2016 242\nS7A.8.10 Data management following the alteration of type\nof metering installation at a connection point\nS7A.8.10.1 Meter churn scenarios\n(a) Meter churn can result in a change to the configuration of metering\ndata recorded by a metering installation. This change in metering\ndata may result in an alteration to the Metering Data File Format\nfile.\n(b) Where a meter churn takes place, each Metering Data Provider\nmust:\n(1) comply with the Metering Data File Format requirements when\nconstructing the Metering Data File Format file associated with\nthe change in type of metering installation; and\n(2) for a meter churn scenario described in an item of column 1 of\nthe following table, comply with the requirements for the\nmanagement of metering data described in the provision listed\nin column 2 of that item of the following table:\nColumn 1\nMeter churn scenario\nColumn 2\nProvision\ntype 6 metering installation to a new type\n6 metering installation (Scenario 1)\nClause S7A.8.10.2\ntype 6 metering installation to a type 1,\n2, 3, 4, 4A, or 5 metering installation\n(Scenario 2)\nClause S7A.8.10.3\ntype 1, 2, 3, 4, 4A, or 5 metering\ninstallation to a type 6 metering\ninstallation (Scenario 3)\nClause S7A.8.10.4\ntype 1, 2, 3, 4, 4A, or 5 metering\ninstallation to a new type 1, 2, 3, 4, 4A,\nor 5 metering installation (Scenario 4)\nClause S7A.8.10.5\n\nRegulations 2016 243\nS7A.8.10.2 Scenario 1\nThe Metering Data Provider must have a process to ensure that:\n(a) the final accumulation meter reading(s) from the removed\ntype 6 metering installation are applied at the end of the day\nprior to the meter churn;\n(b) the start reading(s) for a new type 6 metering installation are\napplied at the start of the day of the meter churn; and\n(c) estimated metering data is provided for any metering data\nstreams made active as a result of the meter churn.\nS7A.8.10.3 Scenario 2\n(a) The Metering Data Provider must have a process to ensure that:\n(1) the final accumulation meter reading(s) from the removed\ntype 6 metering installation are applied at the end of the day\nprior to the meter churn;\n(2) the metering data for the new type 1, 2, 3, 4, 4A, or 5 metering\ninstallation commences at the start of the day of the meter\nchurn; and\n(3) estimated metering data is provided for any metering data\nstreams made active as a result of the meter churn for a new\ntype 4A or type 5 metering installation.\n(b) The Metering Data Provider must have a process to ensure that the\nmetering data for the period of the meter churn day between the\nstart of the day and the commissioning of the new metering\ninstallation is provided as zeroes with a quality flag of F.\nS7A.8.10.4 Scenario 3\nWhere reversion from a type 1, 2, 3, 4, 4A, or 5 metering installation\nto a type 6 metering installation is permitted, the Metering Data\nProvider must have a process to ensure that:\n(a) the final reading(s) from the removed type 1, 2, 3, 4, 4A, or\n5 metering installation cease at the end of the day of the meter\nchurn;\n(b) the metering data for the period of the meter churn day\nbetween commissioning of the new metering installation and\nthe end of the day of the meter churn is provided as zeroes\nwith a quality flag of F; and\n\nRegulations 2016 244\n(c) the start reading(s) for the new type 6 metering installation are\napplied at the start of the day following the day of the meter\nchurn.\nS7A.8.10.5 Scenario 4\nEach Metering Data Provider must have a process to ensure\ncompliance with the following requirements:\n(a) the final reading(s) from the removed type 1, 2, 3, 4, 4A, or\n5 metering installation is collected up to the removal of the old\nmetering installation on the day of the meter churn;\n(b) the metering data for the new type 1, 2, 3, 4, 4A, or 5 metering\ninstallation commences at the start of the day of the meter\nchurn;\n(c) the Metering Data Provider related to the new metering\ninstallation must obtain metering data for the period of the\nmeter churn day between the start of the meter churn day and\nthe removal of the old metering installation from the Metering\nData Provider related to the old metering installation;\n(d) the Metering Data Provider related to the new metering\ninstallation must combine the metering data from the old\nmetering installation and the new metering installation for the\nday of meter churn and deliver metering data for the whole\nday of meter churn;\n(e) where meter churn results in a change to the recording of\nmetering data from 15-minute to 30-minute intervals, the 15-\nminute intervals of metering data from the start of the meter\nchurn day until the commissioning of the new metering\ninstallation are to be aggregated to form interval metering\n(f) where meter churn results in a change to the recording of\nmetering data from 30-minute to 15-minute intervals:\n(1) the 15-minute intervals of metering data from the\ncommissioning of the new metering installation to the\nend of the meter churn day are to be aggregated to form\n30-minute interval metering data; or\n(2) the 30-minute intervals of metering data for the start of\nthe meter churn day may be disaggregated to form\n15-minute interval metering data, where agreed with the\n\nRegulations 2016 245\n(g) estimated metering data is provided for any metering data\nstreams made active as a result of the meter churn for a new\ntype 4A or type 5 metering installation;\n(h) where meter churn results in a metering data stream being\nmade active, the Metering Data Provider related to the new\nmetering installation must provide metering data from the start\nof the day to the commissioning of the new metering\ninstallation by providing zeroes with a quality flag of F;\n(i) where meter churn results in a metering data stream being\nmade inactive, the Metering Data Provider must provide\nmetering data from the commissioning of the new metering\ninstallation to the end of the day by providing zeroes with a\nquality flag of F; and\n(j) the Metering Data Provider must create final substituted\nmetering data for the period between the existing metering\ninstallation being removed and the commissioning of the new\nS7A.8.11 System architecture and administration\nS7A.8.11.1 Metering data archival and recovery\nEach Metering Data Provider must have retrieval mechanisms (both\nelectronic and archived) that allow the metering data retained in its\nmetering data services database under clause 7A.8.3 to be\naccessed, recovered, re-evaluated and delivered in agreed\ntimeframes to NTESMO, Registered Participants or financially\nresponsible participants.\nS7A.8.11.2 Data backup\nAll metering data and metering register information must be\nbacked-up, at a minimum, on a daily basis and held in a secure\nenvironment.\nS7A.8.11.3 Disaster recovery\nRequirement for disaster recovery plan\n(a) Each Metering Data Provider must ensure that a disaster recovery\nplan is established and in place to ensure that in the event of a\nsystem failure, its IT systems can be returned to normal operational\nservice within 2 business days.\n\nRegulations 2016 246\n(b) The Metering Data Provider must ensure that the disaster recovery\nplan is:\n(1) up to date with all documentation showing revisions; and\n(2) witnessed and dated at least annually by the Metering Data\nProvider as being current for the systems and processes in\nplace.\nFall-over system approach\n(c) Where a Metering Data Provider adopts a disaster recovery plan\nthat has a complete ‘fail-over' system approach, the disaster\nrecovery plan must be subjected to a test annually that facilitates a\nfull ‘fail-over' to the recovery system.\nSegmented system approach\n(d) Where the Metering Data Provider adopts a disaster recovery plan\nthat has a segmented system approach, the disaster recovery plan\nmust:\n(1) detail the interfaces and relationships between system\nsegments;\n(2) be established for each individual system segment;\n(3) be tested annually with evidence retained to show disaster\nrecovery for each individual system segment; and\n(4) have, for each individual system segment, a procedure that\nclearly details the process to establish a return to full\noperation.\nTesting\n(e) Expected evidence to support disaster recovery plan testing should\ninclude, but not be limited to:\n(1) a test plan of the fail-over;\n(2) results of the fail-over including timing;\n(3) system logs indicating fail-over and recovery; and\n(4) logs or notations evidencing resumption of Metering Data\nProvider operations.\n\nRegulations 2016 247\nActions following system failure\n(f) If a system failure occurs, the Metering Data Provider must ensure\nthat within 2 business days:\n(1) its metering data services database is restored to operational\nservice; and\n(2) all processing and delivery backlogs of metering data to\nNTESMO and Registered Participants is completed.\nNotice to NTESMO of activation of disaster recovery plan\n(g) The Metering Data Provider must, at its earliest opportunity, notify\nNTESMO of any failure where the Metering Data Provider has a\nrequirement to activate its disaster recovery plan.\nS7A.8.11.4 System administration and data management\nMetering data services database\n(a) The metering data services database must be operated and\nadministered by a Metering Data Provider to facilitate:\n(1) controlled access to systems and data using unique\nidentification and passwords for each user;\n(2) the restriction of access to the underlying database tables to\nnominated system administrators;\n(3) the restriction of Registered Participant access to metering\ndata and NT NMI data in accordance with\nparagraph 7A.13.5(c);\n(4) a minimum of 95% system availability (that is, hardware and\nsystems downtime do not exceed a maximum of 438 hours\nper annum).\nMetering register\n(b) Each Metering Data Provider must maintain full audit trails and\nversion control of metering register information, metering data for at\nleast 7 years so that any data output produced by the system can\nbe re-produced from source data.\n\nRegulations 2016 248\nS7A.8.12 Quality control\nS7A.8.12.1 Audits\n(a) Audits may be undertaken at any time by the Utilities Commission\nin accordance with the Rules and may be carried out following a\nrequest from a Registered Participant.\n(b) Where an audit of a metering installation is conducted by the\nUtilities Commission under clause 7A.7.4, and metering data must\nbe obtained from the Metering Data Provider in support of this\naudit, the Metering Data Provider must provide the metering data\nwithin 2 business days of the Utilities Commission's request.\n(c) Each Metering Data Provider must assist the Utilities Commission\nwith reasonable requests for the provisioning of metering data and\nrelevant information relating to connection points that are part of the\naudit process of Metering Coordinators, Metering Providers and\nMetering Data Providers.\nS7A.8.12.2 Corrective action\n(a) Each Metering Data Provider must take corrective action on any\nreported instances of non-compliance identified by NTESMO or\nthrough a Metering Data Provider audit process.\n(b) Where a Metering Data Provider becomes aware that incorrect\nmetering data has been delivered to NTESMO and Registered\nParticipants, the Metering Data Provider must provide corrected\nmetering data to all affected parties within 1 business day as\nrequired by paragraph 7A.8.3(d).\n(c) NTESMO may request corrective action where errors or omissions\nare found within the settlements process and such requests are to\nbe actioned as a priority by the Metering Data Provider.\n(d) Where the Metering Data Provider cannot deliver the corrected\nmetering data in the timeframe specified above, the Metering Data\nProvider must advise NTESMO and agree on an alternative\ndelivery time.\nS7A.8.13.1 Administration\nProvision of data\n(a) A Registered Participant may request a Metering Data Provider to:\n(1) provide metering data in an alternative format, method or\ntimeframe;\n\nRegulations 2016 249\n(2) provide any other metering data services; or\n(3) any combination of the above.\nNo data to be provided\n(b) A Registered Participant may request a Metering Data Provider to\nnot provide or deliver any metering data to the Registered\nParticipant as required under this Part.\nSystem changes not required\n(c) There is no requirement for a Metering Data Provider to implement\nsystem changes and processes to facilitate bilateral agreements.\nBilateral agreement not to impact metering data delivery to\n(d) Any acceptance by a Metering Data Provider to deliver metering\ndata to a Registered Participant in accordance with any agreement\ncontemplated by this clause S7A.8.13.1 or acceptance to not\nprovide any metering data in accordance with such an agreement\nmust not impact on metering data delivery to NTESMO or any other\nRegistered Participant for the connection point(s) concerned.\nBilateral agreement to be auditable\n(e) Any bilateral agreement established between a Registered\nParticipant and a Metering Data Provider must be in writing and\nmade available to the Utilities Commission on request for audit\npurposes.\nS7A.8.13.2 Quality systems\nEach Metering Data Provider must operate and retain a quality\nsystem that is at least equal to a quality accreditation to the\nISO9001 or ISO9002 standards.\n","sortOrder":111},{"sectionNumber":"88","sectionType":"section","heading":"Clause 8.1.3 modified","content":"88 Clause 8.1.3 modified\nAfter clause 8.1.3, heading\nNote\nClause 8.1.3(b)(5) and (7) has no effect in this jurisdiction (see regulation 5A of\n\nRegulations 2016 250\n","sortOrder":112},{"sectionNumber":"89","sectionType":"section","heading":"Chapter 8, Part B modified","content":"89 Chapter 8, Part B modified\nAfter Chapter 8, Part B, heading\n","sortOrder":113},{"sectionNumber":"90","sectionType":"section","heading":"Clause 8.6.1 modified","content":"90 Clause 8.6.1 modified\nAfter clause 8.6.1, heading\nNote\nClause 8.6.1(d) and (e) has no effect in this jurisdiction (see regulation 5A of the\n","sortOrder":114},{"sectionNumber":"91","sectionType":"section","heading":"Clause 8.6.2 modified","content":"91 Clause 8.6.2 modified\nAfter clause 8.6.2, heading\nNote\nClause 8.6.2(l) has no effect in this jurisdiction (see regulation 5A of the National\n","sortOrder":115},{"sectionNumber":"92","sectionType":"section","heading":"Clause 8.6.5 replaced","content":"92 Clause 8.6.5 replaced\nClause 8.6.5\nrepeal, insert\n8.6.5 Indemnity to AER and AEMC\nEach Registered Participant must indemnify the AER and the\nAEMC against any claim, action, damage, loss, liability, expense or\noutgoing which the AER or the AEMC pays, suffers, incurs or is\nliable for in respect of any breach by that Registered Participant or\nany officer, agent or employee of that Registered Participant of this\nrule 8.6.\n\nRegulations 2016 251\n","sortOrder":116},{"sectionNumber":"93","sectionType":"section","heading":"Clauses 8.6.6 and 8.6.7 modified","content":"93 Clauses 8.6.6 and 8.6.7 modified\nAfter clauses 8.6.6 and 8.6.7, headings\nNote\nThis clause has no effect in this jurisdiction (see regulation 5A of the National\n","sortOrder":117},{"sectionNumber":"94","sectionType":"section","heading":"Clause 8.7.1 modified","content":"94 Clause 8.7.1 modified\n(1) Clause 8.7.1(b)(1)\nomit\nand AEMO\n(2) Clause 8.7.1(c)(3)\nomit\n, all Registered Participants and AEMO\nand all Registered Participants\n","sortOrder":118},{"sectionNumber":"95","sectionType":"section","heading":"Clause 8.7.2 modified","content":"95 Clause 8.7.2 modified\n(1) Clause 8.7.2, heading\n8.7.2 Reporting requirements and monitoring standards for\nRegistered Participants\nNote\nClause 8.7.2(a)(2) and (4) and (b)(2) has no effect in this jurisdiction (see\n(2) Clause 8.7.2(a)(5)\nomit\n\nRegulations 2016 252\n(3) Clause 8.7.2(b)(1)\nomit\n, AEMO\n(4) Clause 8.7.2(b)(1)\nomit\n, (4)\n(5) Clause 8.7.2(c)\nomit\nAEMO and\n(6) Clause 8.7.2(e)\nand AEMO\n(7) Clause 8.7.2(f)\nomit\nall words from \"neither\" to \"be)\"\na Registered Participant must not recklessly or knowingly provide,\nor permit any other person to provide on behalf of that Registered\nParticipant\n(8) Clause 8.7.2(g)\nomit\n(9) Clause 8.7.2(g) and (h)\nomit\nand/or AEMO (as the case may be)\n\nRegulations 2016 253\n(10) Clause 8.7.2(g)\nomit\nand (to the extent relevant) AEMO\n","sortOrder":119},{"sectionNumber":"96","sectionType":"section","heading":"Clause 8.7.6 modified","content":"96 Clause 8.7.6 modified\nAfter clause 8.7.6, heading\nNote\nClause 8.7.6 has no effect in this jurisdiction (see regulation 5A of the National\n","sortOrder":120},{"sectionNumber":"97","sectionType":"section","heading":"Chapter 8, Parts E and G modified","content":"97 Chapter 8, Parts E and G modified\nAfter Chapter 8, Parts E and G, headings\nNote\n","sortOrder":121},{"sectionNumber":"98","sectionType":"section","heading":"Chapter 8, Parts H modified","content":"98 Chapter 8, Parts H modified\nAfter Chapter 8, Part H, heading\n","sortOrder":122},{"sectionNumber":"99","sectionType":"section","heading":"Chapter 10 modified","content":"99 Chapter 10 modified\n(1) Chapter 10, definitions accumulated energy data, accumulated\nmetering data, application to connect, business day,\ncalculated metering data, check meter, check metering data,\ncheck metering installation, connection point, control centre,\nCustomer, customer authorised representative, day,\nDistribution Network Service Provider, distribution system,\nestimated metering data, facilities, financially responsible,\nGenerator, interval energy data, interval metering data,\nMetering Coordinator, Metering Data Provider, metering data\nservices, metering data services database, metering\n\nRegulations 2016 254\ninstallation malfunction, Metering Provider, National Electricity\nLaw, national grid, Network Service Provider, NMI, nominal\nvoltage, nominated pass through event considerations,\npositive change event, power system, regulatory control\nperiod, remote acquisition, Rules, substituted metering data,\ntelecommunications network, time, transmission network,\nTransmission Network Service Provider, transmission or\ndistribution system and unmetered connection point\nomit\n(2) Chapter 10\ninsert (in alphabetical order)\n1st regulatory control period\nIn relation to a Network Service Provider in this jurisdiction, means\nthe first period during which the provider will be or is subject to a\ncontrol mechanism imposed by a distribution determination, being\nthe period from 1 July 2019 to 30 June 2024.\n2009-14 NT regulatory control period\nThe regulatory control period that commenced on 1 July 2009\nunder the NT Network Access Code.\n2014-19 NT regulatory control period\nThe regulatory control period that commenced on 1 July 2014\nunder the NT Network Access Code.\n2014 NT Ministerial Direction\nThe direction issued by the shareholding Minister of Power and\nWater Corporation ABN 15 947 352 360 to the board of the\nCorporation under section 8(4)(a) of the Government Owned\nCorporations Act (NT), dated 19 June 2014.\n2014 NT Network Price Determination\nThe \"2014 Network Price Determination\" made by the Utilities\nCommission under the Utilities Commission Act (NT), Electricity\nReform Act (NT) and Chapter 6 of the NT Network Access Code\n(a) applies, or applied, from 1 July 2014 to 30 June 2019; and\n\nRegulations 2016 255\n(b) because of section 57 of the Electricity Networks (Third Party\nAccess) Act (NT), is, or was, a network pricing determination\nmade under section 6A(1) of that Act,\nas amended, varied or substituted from time to time.\naccumulated energy data\nThe data that results from the measurement of the flow of electricity\nin a power conductor where the data represents a period in excess\nof a recording interval. Accumulated energy data is held in the\nmetering installation. The measurement is carried out at a metering\naccumulated metering data\nThe accumulated energy data, once collected from a metering\ninstallation, is accumulated metering data. Accumulated metering\ndata is held in a metering data services database.\napplication to connect\nAn application made by a Connection Applicant in accordance with\nChapter 5, Part A for connection to a network and/or the provision\nof network services or modification of a connection to a network\nand/or the provision of network services.\nAustralian Central Standard Time (ACST)\nThe time that is set at 9 hours and 30 minutes in advance of\nCo-ordinated Universal Time.\nbusiness day\nA day that is not:\n(a) a Saturday or Sunday; or\n(b) a public holiday as defined in section 17 of the Interpretation\nAct (NT) (other than a public holiday that is part of a day) in\nthe City of Darwin.\ncalculated metering data\nThe recording interval data corresponding to the calculation of\nconsumed energy for a type 7 metering installation in accordance\nwith schedule 7A.7. Calculated metering data is held in the\nmetering data services database.\n\nRegulations 2016 256\ncheck meter\nAn additional meter used as a source of check metering data for\ntype 1 and type 2 metering installations as specified in\ncheck metering data\nThe energy data, once collected from a check metering installation,\nis check metering data. Check metering data is held in a metering\ndata services database.\ncheck metering installation\nA metering installation that includes a check meter which is used as\nthe source of check metering data for data validation.\nconnection point\nThe agreed point of supply established between Network Service\nProvider(s) and another Registered Participant, Non-Registered\nCustomer or franchise customer.\ncontrol centre\nThe facilities used by NTESMO for managing power system\nsecurity and administering a market.\nCustomer\n(a) under Part 3 of the Electricity Reform Act (NT), holds a licence\nauthorising the selling of electricity; but\n(b) does not hold a licence authorising the ownership or operation\nof an electricity network under that Part.\ncustomer authorised representative\nA person authorised by a retail customer to request and receive\ninformation under Chapter 7A on the retail customer's behalf.\nday\nUnless otherwise specified, the 24 hour period beginning and\nending at midnight Australian Central Standard Time.\n\nRegulations 2016 257\nDistribution Network Service Provider\n(a) engages in the activity of owning, controlling, or operating a\ndistribution system; and\n(b) under Part 3 of the Electricity Reform Act (NT), holds a licence\nauthorising the ownership or operation of an electricity\ndistribution system\n(a) a distribution network, together with the connection assets\nassociated with the distribution network, which is connected to\nanother transmission or distribution system within the other\nparticipating jurisdictions; or\n(b) a distribution network that forms part or all of a local electricity\nsystem, together with the connection assets associated with\nthe distribution network.\nConnection assets on their own do not constitute a distribution\nsystem.\nestimated metering data\nThe estimated values of accumulated metering data, interval\nmetering data or calculated metering data that have been prepared\nin accordance with schedule 7A.7. Estimated metering data is held\nin a metering data services database.\nfacilities\nA generic term associated with the apparatus, equipment, buildings\nand necessary associated supporting resources provided at,\ntypically:\n(a) a power station or generating unit;\n(b) a substation or power station switchyard;\n(c) a control centre (being an NTESMO control centre, or a\ndistribution or transmission network control centre);\n(d) facilities providing an exit service.\n\nRegulations 2016 258\nfinancially responsible\nIn relation to a connection point, a term which is used to describe\nthe person authorised to have either:\n1. the load connected at that connection point; or\n2. the generating unit connected at that connection point.\nThe obligations on Customers (including retailers) and Generators in relation to\nthe authorisation of, respectively, load or generating units connected at a\nconnection point will be considered as part of the phased implementation of the\nGenerator\n(a) engages in the activity of owning, controlling or operating a\ngenerating system that is connected to, or who otherwise\nsupplies electricity to, a transmission or distribution system;\nand\n(b) is a Registered Participant who, under Part 3 of the Electricity\nReform Act 2000 (NT), holds a licence authorising the\ngeneration of electricity.\nFor the purposes of Chapter 5, the term includes a person who:\n(a) is required or intends to hold a licence authorising the\ngeneration of electricity;\n(b) is covered by an exemption from the requirement to hold a\nlicence for the generation of electricity;\n(c) is a non-registered embedded generator (as defined in\nclause 5A.A.1) who has made an election under\nclause 5A.A.2(c); or\n(d) is a non-registered embedded generator (as defined in\nclause 5A.A.1) above the relevant materiality threshold (as\ndefined in Chapter 5).\ninterval energy data\nThe data that results from the measurement of the flow of electricity\nin a power conductor where the data is prepared and recorded by\nthe metering installation in intervals which correspond to a\nrecording interval or are submultiples of a recording interval.\nInterval energy data is held in the metering installation.\n\nRegulations 2016 259\ninterval meter\nA meter that records interval energy data.\ninterval metering data\nThe interval energy data, once collected from a metering\ninstallation, is interval metering data. Interval metering data is held\nin a metering data services database.\nMetering Coordinator\nA person appointed to the role of Metering Coordinator in this\nMetering Data Provider\nA person appointed to be a Metering Data Provider for a connection\nmetering data services\nThe services that involve the collection, processing, storage and\ndelivery of metering data and the management of relevant NT NMI\ndata in accordance with the Rules.\nmetering data services database\nThe database established and maintained by the Metering Data\nProvider that holds metering data and NT NMI data relating to each\nmetering installation for which the Metering Coordinator has\nappointed the Metering Data Provider to provide metering data\nservices.\nmetering installation malfunction\nThe full or partial failure of the metering installation in which the\n(a) does not meet the requirements of schedule 7A.4;\n(b) does not record, or incorrectly records, energy data; or\n(c) does not allow, or provide for, collection of energy data.\nMetering Provider\nA person appointed to be a Metering Provider for a connection\n\nRegulations 2016 260\nNational Electricity Law\nThe National Electricity (NT) Law.\nnational grid\nThe sum of:\n(a) all connected transmission systems and distribution systems\nwithin the other participating jurisdictions; and\n(b) the transmission systems and distribution systems in this\nNetwork Service Provider\nA Distribution Network Service Provider or Transmission Network\nService Provider.\nNMI\nA National Metering Identifier issued by the relevant Network\nService Provider.\nnominal voltage\nThe design voltage level, nominated for a particular location on the\npower system, such that power lines and circuits that are\nelectrically connected other than through transformers have the\nsame nominal voltage regardless of operating voltage.\nnominated pass through event considerations\nThe nominated pass through event considerations are:\n(a) whether the event proposed is an event covered by a category\nof pass through event specified in clause 6.6.1(a1)(1AA) to (4)\n(in the case of a distribution determination) or\nclause 6A.7.3(a1)(1) to (4) (in the case of a transmission\ndetermination);\n(b) whether the nature or type of event can be clearly identified at\nthe time the determination is made for the service provider;\n(c) whether a prudent service provider could reasonably prevent\nan event of that nature or type from occurring or substantially\nmitigate the cost impact of such an event;\n\nRegulations 2016 261\n(d) whether the relevant service provider could insure against the\nevent, having regard to:\n(1) the availability (including the extent of availability in\nterms of liability limits) of insurance against the event on\nreasonable commercial terms; or\n(2) whether the event can be self-insured on the basis that:\n(i) it is possible to calculate the self-insurance\npremium; and\n(ii) the potential cost to the relevant service provider\nwould not have a significant impact on the service\nprovider's ability to provide network services; and\n(e) any other matter the AER considers relevant and which the\nAER has notified Network Service Providers is a nominated\npass through event consideration.\nNT equivalent services\nRegulated network access services (as defined in clause 3 of the\nNT Network Access Code) that are designated as direct control\nservices in Table 3.1 of Part A of the 2014 NT Network Price\nDetermination.\nNT Network Access Code\nThe Network Access Code as defined in section 2A(1) of the\nElectricity Networks (Third Party Access) Act (NT).\nNT NMI data\nThe following data in respect of a connection point:\n(a) the NMI of the connection point and the street address of the\nrelevant connection point to which that NMI is referable;\n(b) the NMI checksum for the connection point;\n(c) the identity of the relevant Network Service Provider;\n(d) the relevant distribution loss factor applicable to the\nconnection point;\n(e) the Network Tariff (identified by a code) applicable in respect\nof the connection point;\n\nRegulations 2016 262\n(f) the read cycle date, or date of next scheduled read or date in\na relevant code representing the read cycle date or date of\nnext scheduled read, for that connection point,\nand, to avoid doubt, does not include any metering data or other\ndetails of an end-user's consumption at that connection point.\npositive change event\nFor a Distribution Network Service Provider, a pass through event\nwhich entails the Distribution Network Service Provider incurring\nmaterially higher costs in providing direct control services than it\nwould have incurred but for that event, but does not include a\ncontingent project or an associated trigger event.\nFor a Transmission Network Service Provider, a pass through event\nwhich entails the Transmission Network Service Provider incurring\nmaterially higher costs in providing prescribed transmission\nservices than it would have incurred but for that event, but does not\ninclude a contingent project or an associated trigger event.\npower system\nThe electricity power system of the national grid including\nassociated generation and transmission and distribution networks\nfor the supply of electricity, operated as an integrated arrangement\nor arrangements.\nrecording interval\nA 30 minute period ending on the hour (Australian Central Standard\nTime) or on the half-hour and, if identified by a time, means the 30\nminute period ending at that time.\nregulatory control period\nIn respect of a Network Service Provider, a period of not less than\n5 regulatory years for which the provider is subject to a control\nmechanism imposed by a distribution determination.\nremote acquisition\nThe acquisition of interval metering data from a telecommunications\nnetwork connected to a metering installation that:\n(a) does not, at any time, require the presence of a person at, or\nnear, the interval metering installation for the purposes of data\ncollection or data verification (whether this occurs manually as\na walk-by reading or through the use of a vehicle as a close\nproximity drive-by reading); and\n\nRegulations 2016 263\n(b) includes but is not limited to methods that transmit data via:\n(1) fixed-line telephone (‘direct dial-up');\n(2) satellite;\n(3) the internet;\n(4) wireless or radio, including mobile telephone networks;\n(5) power line carrier; or\n(6) any other equivalent technology.\nRules\nThe National Electricity Rules as defined in section 2(1) of the\nNational Electricity Law.\nsubstituted metering data\nThe substituted values of accumulated metering data, interval\nmetering data or calculated metering data prepared in accordance\nwith schedule 7A.7. Substituted metering data is held in a metering\ndata services database.\ntelecommunications network\nA telecommunications network that provides access for public use.\ntime\nAustralian Central Standard Time.\ntransmission network\nAny of the following:\n(a) a network in this jurisdiction operating at nominal voltages of\n66kV and above;\n(b) a network or part of a network prescribed by local instrument\nto be a transmission network or part of a transmission\nnetwork,\nbut does not include a network or part of a network prescribed by\nlocal instrument not to be a transmission network or part of a\ntransmission network.\n\nRegulations 2016 264\nFor a participating jurisdiction other than the State of Victoria, an\nidentified shared user asset owned, controlled or operated by a\nPrimary Transmission Network Service Provider (including a third\nparty IUSA that is the subject of a network operating agreement)\nforms part of that Primary Transmission Network Service Provider's\ntransmission network.\nThe National Electricity (Northern Territory) (National Uniform Legislation)\n(Modification) Regulations 2016 are a local instrument.\nTransmission Network Service Provider\n(a) engages in the activity of owning, controlling or operating a\ntransmission system; and\n(b) under Part 3 of the Electricity Reform Act (NT), holds a licence\nauthorising the ownership or operation of an electricity\ntransmission or distribution system\nA transmission system or a distribution system.\nunmetered connection point\nA connection point at which a meter is not necessary under\nschedule 7A.1.\nUtilities Commission\nThe Utilities Commission of the Northern Territory established by\nsection 5 of the Utilities Commission Act (NT).\n(3) Chapter 10, definition applicable regulatory instruments, at the\nend\n(6A) Northern Territory:\n(a) the Electricity Reform Act (NT);\n(b) all instruments made and licences granted under the\nElectricity Reform Act (NT);\n(c) the Utilities Commission Act (NT); and\n(d) all instruments made under the Utilities Commission Act (NT).\n\nRegulations 2016 265\n(4) Chapter 10, definition franchise customer, at the end\nThere are no franchise customers in this jurisdiction.\n","sortOrder":123},{"sectionNumber":"99A","sectionType":"section","heading":"Chapter 10 modified (further definitions substituted and","content":"99A Chapter 10 modified (further definitions substituted and\ninserted)\n(1) Chapter 10, definitions access standard, connection alteration,\nconnection contract, Dedicated Connection Asset Service\nProvider, dispatch, distribution network user access,\nembedded network, funded augmentation, generating system,\nIncoming Retailer, Local Network Service Provider, market,\nmarket load, metering register, normal voltage, performance\nstandard, plant, power system security, profile, retail\ncustomer, satisfactory operating state, secure operating state,\nsettlements, settlements ready data, system standard and\ntransmission consultation procedures\nomit\n(2) Chapter 10\naccess standard\nA particular technical requirement as recorded in a connection\nagreement.\nbilling transaction\nThe activity of producing bills and credit notes in markets that are\nnot operated or administered by NTESMO.\nconnection alteration\nHas (in the context of Chapters 5A and 7A) the meaning given in\nclause 5A.A.1.\nconnection contract\nHas (in the context of Chapters 5A and 7A) the meaning given in\nclause 5A.A.1.\n\nRegulations 2016 266\nDedicated Connection Asset Service Provider\nA Transmission Network Service Provider to the extent that it owns\nor operates a dedicated connection asset in accordance with a\nlicence under the Electricity Reform Act 2000 (NT).\ndispatch\nThe act of initiating or enabling all or part of the response to an\ninstruction issued to a Generator to synchronise, supply ancillary\nservices, or supply energy.\ndistribution network user access\nThe power transfer capability of the distribution network in respect\nof:\n(a) generating units or a group of generating units; and\n(b) network elements,\nat a connection point which has been negotiated in accordance with\nrules 5.3, 5.3A and 5.3AA.\nFor the avoidance of doubt, distribution network user access extends to the\ntransmission network for the purposes of Chapter 6.\nelectricity retail supply code\nThe Electricity Retail Supply Code made by the Utilities\nCommission under section 24 of the Utilities Commission Act 2000\n(NT) (as published by the Utilities Commission from time to time).\nembedded network\nA distribution system that is connected to a distribution system\ncontrolled or operated by the Local Network Service Provider (other\nthan a distribution system that is owned, controlled or operated by\nthe Local Network Service Provider).\nenergy ombudsman\nThe person holder or occupying the office of Ombudsman for the\nNorthern Territory established by section 9 of the Ombudsman\nAct 2009 (NT).\n\nRegulations 2016 267\nfunded augmentation\nA transmission network augmentation for which the Transmission\nNetwork Service Provider is not entitled to receive a charge\npursuant to Chapter 6.\ngenerating system\n(a) Subject to paragraph (b), for the purposes of the Rules, a\nsystem comprising one or more generating units.\n(b) For the purposes of Chapter 5, a system comprising one or\nmore generating units and includes auxiliary or reactive plant\nthat is located on the Generator's side of the connection point\nand is necessary for the generating system to meet its\nperformance obligations.\nIncoming Retailer\nA retailer that:\n(a) that has a contract with a customer at a connection point; and\n(b) has initiated the customer transfer process in accordance with\nthe electricity retail supply code,\nbut which is not yet designated the financially responsible\nparticipant for that connection point.\nLocal Network Service Provider\nPower and Water Corporation ABN 15 947 352 360.\nmarket\n(a) except for the purposes of Chapter 7A:\n(i) a market or exchange operated or administered by\nNTESMO, whether being a market for energy or any\nother market or exchange; or\n(ii) a market or exchange for energy that is not operated or\nadministered by NTESMO; and\n(b) for the purposes of Chapter 7A, a market or exchange for\nenergy.\n\nRegulations 2016 268\nmarket load\nA load for an NMI classified by the relevant retailer or, with the\nconsent of the financially responsible person for that load, by some\nother person, as a market load. There can be more than one\nmarket load at any one connection point.\nmetering register\nA register of information associated with a metering installation as\nrequired by schedule 7A.1.\nnew meter deployment\nThe replacement of an existing electricity meter of one or more\nsmall customers which is arranged by a retailer, other than where\nthe replacement is:\n(a) at the request of the relevant small customer or to enable the\nprovision of a product or service the customer has agreed to\nacquire from the retailer or any other person;\n(b) a maintenance replacement; or\n(c) required as a result of a metering installation malfunction.\nnormal voltage\nIn respect of a connection point, its nominal voltage or such other\nvoltage up to 10% higher or lower than normal voltage, as approved\nby NTESMO, for that connection point, at the request of the\nNetwork Service Provider who provides connection to the power\nsystem.\nNTESMO (being the Northern Territory Electricity System and\nMarket Operator)\nAs the case requires:\n(a) the entity that undertakes the performance of the functions set\nout in the Rules that relate to monitoring or controlling the\noperation of the power system in respect of one or more of the\nlocal electricity systems; or\n(b) the entity that undertakes the performance of the functions set\nout in the Rules that relate to operating or administering a\nmarket in respect of one or more of the local electricity\nsystems.\n\nRegulations 2016 269\nperformance standard\nA standard of performance that:\n(a) is established as a result of it being taken to be an applicable\nperformance standard in accordance with jurisdictional\n(b) forms part of the terms and conditions of a connection\nagreement.\nplant\nIn relation to a connection point, includes all equipment involved in\ngenerating, utilising or transmitting electrical energy.\npower system security\nThe safe scheduling, operation and control of the power system on\na continuous basis in accordance with the principles set out in\nThe principles that will be set out in jurisdictional electricity legislation in the\nabove definition will correspond to principles set out in clause 4.2.6 in the Rules\napplying in other participating jurisdictions.\nprofile\nMetering data or costs for a longer period than a recording interval\nallocated into recording intervals.\nretail customer\nHas the same meaning as in the National Electricity Law.\nIn the context of Chapter 5A, the above definition has been supplemented by a\ndefinition specifically applicable to that Chapter. See clause 5A.A.1.\nsatisfactory operating state\nIn relation to the power system, has the meaning given in\nThe meaning given in jurisdictional electricity legislation in the above definition\nwill correspond to the meaning given in clause 4.2.2 in the Rules applying in\nother participating jurisdictions.\n\nRegulations 2016 270\nsecure operating state\nIn relation to the power system, has the meaning given in\nThe meaning given in jurisdictional electricity legislation in the above definition\nwill correspond to the meaning given in clause 4.2.4 in the Rules applying in\nother participating jurisdictions.\nsettlements\nThe activity of producing bills and credit notes in markets operated\nor administered by NTESMO.\nsettlement ready data\nThe metering data that has undergone a validation and substitution\nprocess by NTESMO for the purposes of settlements and is held in\nthe metering database.\nsystem standard\nA standard for the performance of the power system as set out in\njurisdictional electricity legislation that:\n(a) is necessary for the safe and reliable operation of the power\nsystem;\n(b) is necessary for the safe and reliable operation of the facilities\nof Registered Participants; and\n(c) is consistent with good electricity industry practice.\ntransmission consultation procedures\nThe procedures set out in Part H of Chapter 6A (as applying in the\nother participating jurisdictions) that must be followed by:\n(a) the AER in making, developing or amending guidelines,\nmodels or schemes or in reviewing methodologies; or\n(b) the AEMC in developing or amending guidelines.\n\nRegulations 2016 271\n","sortOrder":124},{"sectionNumber":"102","sectionType":"section","heading":"Chapter 10 modified (expires on 1 July 2029)","content":"102 Chapter 10 modified (expires on 1 July 2029)\n","sortOrder":125},{"sectionNumber":"Part 10","sectionType":"part","heading":null,"content":"Chapter 10\ninsert (in alphabetical order)\n2nd regulatory control period\nIn relation to a Network Service Provider in this jurisdiction, means\nthe second period during which the provider will be or is subject to a\ncontrol mechanism imposed by a distribution determination, being\nthe period from 1 July 2024 to 30 June 2029.\nThis definition expires on 1 July 2029.\n","sortOrder":126},{"sectionNumber":"103","sectionType":"section","heading":"Chapter 10 modified (expires when NERL is applied)","content":"103 Chapter 10 modified (expires when NERL is applied)\nChapter 10, definition energy laws\nenergy laws\n(a) the national electricity legislation as defined in the National\nElectricity Law;\n(b) these Rules and instruments made under these Rules;\n(c) the national gas legislation as defined in the National Gas\n(NT) Law;\n(d) the National Gas Rules as defined in the National Gas (NT)\nLaw and instruments made under those Rules; and\n(e) any other Northern Territory legislation that regulates energy.\nThe modifications to this definition expire when the National Energy Retail Law is\napplied as a law of this jurisdiction.\n\nRegulations 2016 272\n","sortOrder":127},{"sectionNumber":"104","sectionType":"section","heading":"Chapter 11 modified","content":"104 Chapter 11 modified\nAfter Chapter 11, heading\nParts A to ZZI, ZZK, ZZL, ZZN (except for clause 11.86.8), ZZO to ZZT, ZZV and\nZZX have no effect in this jurisdiction (see regulation 5A of the National Electricity\n(Northern Territory) (National Uniform Legislation) (Modification) Regulations).\nThe application of those Parts may be revisited as part of the phased\n","sortOrder":128},{"sectionNumber":"105","sectionType":"section","heading":"Clause 11.93.1 modified","content":"105 Clause 11.93.1 modified\nClause 11.93.1, definition subsequent regulatory control period\nsubsequent regulatory control period of:\n(a) Power and Water Corporation – means the 1st regulatory\ncontrol period; or\n(b) another affected DNSP or affected TNSP – means the\nregulatory control period for that affected DNSP or affected\nTNSP that immediately follows the current regulatory control\n","sortOrder":129},{"sectionNumber":"106","sectionType":"section","heading":"Chapter 11A inserted","content":"106 Chapter 11A inserted\nAfter Chapter 11\n11A. NT Savings and Transitional Rules\nPart A Savings and transitional rules for Chapter 5\n11A.1 Chapter 5 provisions\n(1) In this Rule:\nregulatory investment test means a regulatory investment test\nunder Part D of Chapter 5.\n(2) A Primary Transmission Network Service Provider is not required to\npublish or provide information under clause 5.2A.5(a) until\n\nRegulations 2016 273\n(3) A Distribution Network Service Provider is not required to have and\npublish its first information pack under clause 5.3A.3(a)(3) until\n(4) A Distribution Network Service Provider is not required to include in\nits first Distribution Annual Planning Report published under\nclause 5.13.2 the information specified in clause S5.8(a)(5) if\ninformation on energy and demand forecasts was not required to be\nreported by the Distribution Network Service Provider under\njurisdictional electricity legislation applicable at the time the\nprevious report was prepared.\n(5) The requirement to undertake a regulatory investment test does not\napply in relation to:\n(a) a project that was assessed by the AER for the purposes of its\ndistribution determination for Power and Water Corporation\n(ABN 15 947 352 360) for the period of 5 years commencing\non 1 July 2019; or\n(b) a project where an assessment equivalent to a regulatory\ninvestment test has been commenced by Power and Water\nCorporation before 1 July 2019.\n(6) A Transmission Network Service Provider is not required to comply\nwith clause 5.18A.3(f) until 1 July 2024 in relation to the content of\nan impact assessment under that clause.\nPart B Savings and transitional rules for Chapter 5A\nNote\nPart B of this Chapter has no effect in this jurisdiction until 1 July 2019 (see\n11A.2 Model standing offers\n11A.2.1 Definitions\nIn this Rule:\nNT distributor means Power and Water Corporation ABN 15 947\n352 360.\nrelevant provisions means Chapter 5A and Chapter 6, Part DA.\ntransition date means the date on which the transition period\nends.\n\nRegulations 2016 274\ntransition period means the period from the commencement of the\n1st regulatory control period (being 1 July 2019) to 30 June 2020.\n11A.2.2 Extended meaning of some terms\nDuring the transition period:\n(a) a basic connection service includes not only a connection\nservice for which a model standing offer has been approved\nby the AER (see paragraph (c) of the definition in\nclause 5A.A.1) but also one for which the AER's approval of a\nmodel standing offer is not required;\n(b) a standard connection service includes not only a connection\nservice for which a model standing offer has been approved\nby the AER (see the definition in clause 5A.A.1) but also one\nfor which the AER's approval of a model standing offer is not\nrequired; and\n(c) a model standing offer includes a document prepared and\npublished by the NT distributor, without the AER's approval,\nas a model standing offer to have effect during the transition\nperiod (but not beyond the end of that period).\n11A.2.3 Transitional operation of relevant provisions\n(a) During the transition period, the relevant provisions operate subject\nto the exclusions, qualifications and modifications prescribed by this\nRule.\n(b) However, the relevant provisions operate without the exclusions,\nqualifications and modifications prescribed by this Rule insofar as\nthey relate to:\n(1) a period beyond the transition period; or\n(2) a person (such as a new entrant to the industry) that is not the\nNT distributor.\nExample\nIf the NT distributor submits a regulatory proposal for the regulatory control\nperiod that follows the transition period, the distributor is bound by the relevant\nprovisions (without exclusion, qualification or modification) in relation to the\nregulatory proposal even though the proposal is submitted during the transition\n(c) A transaction commenced by or with the NT distributor during the\ntransition period may be continued and completed after the\ntransition period without regard to changes to the rules governing\nthe transaction that take effect at the end of the transition period.\n\nRegulations 2016 275\n11A.2.4 Exclusions, qualifications and modifications\nDuring the transition period, the relevant provisions apply to, and in\nrelation to, the NT distributor subject to the following exclusions,\nqualifications and modifications:\nModel standing offers (basic connection services)\n(a) A document, prepared by the NT distributor and published on\nthe NT distributor's website, will (although not approved by the\nAER) be regarded as a model standing offer to provide basic\nconnection services during the transition period if it complies\nwith the requirements of clause 5A.B.2(b) as to its terms and\nconditions.\n(b) If, during the transition period, the AER approves a model\nstanding offer for the same basic connection services, the\napproved model standing offer supersedes the former model\nstanding offer under this clause.\n(c) The NT distributor's obligation to have a model standing offer\nto provide basic connection services (clause 5A.B.1) operates\nduring the transition period but the AER's approval of the\nmodel standing offer is not required until the transition date.\n(d) The NT distributor's obligation to submit for the AER's\napproval a proposed model standing offer to provide basic\nconnection services (clause 5A.B.2(a)) does not arise until\nModel standing offer (standard connection services)\n(e) A document, prepared by the NT distributor and published on\nthe NT distributor's website, will (although not approved by the\nAER) be regarded as a model standing offer to provide\nstandard connection services during the transition period if it\ncomplies with the requirements of clause 5A.B.4(c) as to its\nterms and conditions.\n(f) If, during the transition period, the AER approves a model\nstanding offer for the same standard connection services, and\nthe approved model standing offer is to take effect before the\nend of the transition period, the approved model standing offer\nsupersedes the former model standing offer.\n(g) The NT distributor may submit for the AER's approval a model\nstanding offer to provide standard connection services\n(clause 5A.B.4) during the transition period but the AER's\napproval of the standing offer is not required until the transition\n\nRegulations 2016 276\nAmendment of standing offers\n(h) During the transition period, the NT distributor may amend a\nstanding offer to provide basic connection services or\nstandard connection services during the transition period by\npublishing the amendments and the amended text on its\nwebsite. (This paragraph applies during the transition period to\nthe exclusion of clause 5A.B.6.)\n11A.2.5 References\nA reference to any of the relevant provisions in a legislative or other\ninstrument will be construed, during the transition period, as a\nreference to the provision as modified by this Rule.\nPart C Savings and transitional rules for Chapter 7A\nNote\nPart C of this Chapter has no effect in this jurisdiction until 1 July 2019 (see\nLegislation) (Modification) Regulations). The application of Part C will be\n11A.3 Existing metering installations\n(a) This rule applies in relation to a metering installation installed at a\nconnection point on a transmission network or distribution network\nin this jurisdiction that is in service immediately before 1 July 2019.\n(b) The following requirements must be complied with in relation to the\n(1) the requirements imposed on a metering installation at a\nconnection point on a distribution network or transmission\nnetwork in this jurisdiction by, under or for the purposes of a\nlaw of this jurisdiction that is in force immediately before\n1 July 2019 (the NT requirements); and\n(2) the requirements imposed in respect of the metering\ninstallation by the Rules.\n(c) The requirements imposed in respect of the metering installation by\nthe following provisions are taken to be complied with:\n(1) clause 7A.6.2(a);\n(2) clause 7A.6.3(a);\n(3) clause 7A.6.4, other than paragraph (b);\n(4) clause 7A.6.5;\n\nRegulations 2016 277\n(5) schedule 7A.1, other than clause S7A.1.3;\n(6) clause S7A.3.2.2;\n(7) schedule 7A.5.\n(d) For the purposes of the operation of Chapter 7A in respect of the\nmetering installation, a reference in:\n(1) clause 7A.7.2 to \"the technical requirements\";\n(2) clause 7A.7.3 to \"requirements of the Rules\";\n(3) clause 7A.7.4 to \"schedule 7A.1\" or \"relevant accuracy\nrequirement\";\n(4) clause 7A.8.7 to \"schedule 7A.1\";\n(5) clause S7A.3.2.2(c) to \"requirements of the Rules\"; and\n(6) Chapter 10, definition metering installation malfunction, to\n\"the requirements of schedule 7A.1\",\nmust be regarded as a reference to \"the NT requirements\".\n(e) If the metering installation is replaced on or after 1 July 2019,\nparagraphs (b) to (d) no longer apply in respect of the metering\n11A.4 Testing metering installations\nThe time periods for testing of metering installations under\nTable S7A.6.1.2 do not apply to metering installations that are at\nleast 10 years old on 1 July 2019 until 1 July 2022.\n11A.5 Metering data services database and related requirements\n(1) The Metering Data Provider for this jurisdiction on 1 July 2019 is\nnot, on or after that date, required to comply with all the\nrequirements under rule 7A.8 relating to establishing and\nmaintaining a metering data services database but the following\nrequirements will apply:\n(a) the Metering Data Provider must ensure that all of those\nrequirements under rule 7A.8 are complied with by\n31 March 2025 (with the period between 1 July 2019 and\n31 March 2025 being referred to as the transitional period),\nincluding by acquiring, gaining or upgrading computing\ncapabilities, equipment and other assets and materials, and\nestablishing or enhancing processes and systems, to ensure\n\nRegulations 2016 278\ncompliance;\n(b) during the transitional period, the Metering Data Provider\nmust, insofar as is reasonably practicable, use its existing\nresources and capabilities (and any upgraded, enhanced,\nadditional or new resources and capabilities as they become\nreasonably available) to comply with those requirements\nunder rule 7A.8, especially in relation to the validation,\nsubstitution and estimation of metering data in its metering\ndata services database; and\n(c) without limiting paragraph (b), the Metering Data Provider\nmust use its best endeavours to:\n(i) maximise the quality of metering data; and\n(ii) maximise transparency in processes for verifying,\nvalidating, calculating and estimating metering data.\n(2) During the transitional period:\n(a) the requirements imposed by clause S7A.7.13.5(c)(4) and (5)\nwill not apply in relation to the Metering Data Provider;\n(b) the Metering Data Provider is only required to include\ninformation, data and matters on its metering register in\naccordance with the requirements of clause S7A.8.8.2(e)(4) to\nthe extent that it is reasonably able to do so; and\n(c) the reference in clause S7A.8.8.2(e)(5) to a communication\nguideline, in its application to the Metering Data Provider, will\nbe taken to be a reference to the interim communication\nguideline prepared by NTESMO under rule 11A.6.\n(3) In addition, during the transitional period:\n(a) the Metering Provider is only required to include information,\ndata and matters on a register of metering installations in\naccordance with the requirements of clause S7A.8.7.1(a)(1) to\nthe extent that it is reasonably able to do so; and\n(b) the reference in clause S7A.8.7.1(a)(2) to a communication\nguideline, in its application to the Metering Provider, will be\ntaken to be a reference to the interim communication guideline\nprepared by NTESMO under rule 11A.6.\n(4) For the transitional period, if information about a metering\ninstallation is included in the metering register, then the metering\ninstallation is to be taken, for the purposes of Chapter 7A, to be\nregistered with NTESMO.\n\nRegulations 2016 279\n11A.6 Communication guideline\nNTESMO is not required to have a comprehensive communication\nguideline in place under clause S7A.1.3 until the Metering Data\nProvider is in a position to comply with its obligations under\nrule 7A.8 relating to establishing and maintaining a metering data\nservices database, after taking into account the operation of\nrule 11A.5, but the following requirements will apply:\n(a) NTESMO must have an interim communication guideline in\nplace by 1 January 2020;\n(b) the interim communication guideline must comply with the\nrequirements of clause S7A.1.3(c), (d) and (e) insofar as is\nreasonably practicable and after taking into account the\nMetering Data Provider's resources and capabilities during the\nperiod applying under clause 11A.5(1)(a);\n(c) NTESMO must maintain the interim communication guideline\nuntil the Metering Data Provider is in a position to comply the\nobligations under rule 7A.8, and may review and vary the\ninterim communication guideline from time to time; and\n(d) NTESMO must revise or replace the interim communication\nguideline so that a comprehensive communication guideline is\nin place when the Metering Data Provider is in a position to\ncomply with its obligations under rule 7A.8.\n11A.7 Timeframes for meters to be installed\n(1) In this rule:\ncommencement date means 1 July 2019.\nmaintenance replacement means the replacement of a retail\ncustomer's existing meter arranged by a retailer that is based on\nthe results of sample testing of a meter population carried out in\naccordance with Chapter 7A:\n(a) which indicates that it is necessary or appropriate, in\naccordance with good electricity industry practice, for the\nmeter to be replaced to ensure compliance with Chapter 7A;\nand\n(b) details of which have been provided to the retailer under\nChapter 7A, together with the results of the sample testing that\nsupport the need for the replacement.\n\nRegulations 2016 280\nnew meter deployment means the replacement of an existing\nmeter of one or more retail customers which is arranged by a\nretailer other than where the replacement is:\n(a) at the request of the relevant retail customer or to enable the\nprovision of a product or service the retail customer has\nagreed to acquire from the retailer or any other person;\n(b) a maintenance replacement; or\n(c) as a result of a metering installation malfunction.\n(2) This rule applies where, before the commencement date, a retailer\nhas an outstanding request for a meter to be installed, including in\nrelation to a new connection, at a retail customer's premises and\nthat request does not relate to a new meter deployment or a\nmetering installation malfunction (an existing metering\ninstallation request).\n(3) On and from the commencement date, Chapter 7A will apply to an\nexisting metering installation request as if:\n(a) the timeframe for the meter to be installed for the purposes of\nclause 7A.6.10(a)(2) ends at the later of:\n(i) 6 business days from the date the retailer is informed\nthat the connection service (as defined in clause 5A.A.1)\nis complete; and\n(ii) 6 business days from the commencement date;\n(b) for the purposes of clause 7A.6.11(a)(2), the retailer received\nthe request from the retail customer on the commencement\ndate; and\n(c) for the purposes of clause 7A.6.12(a)(1)(ii) and (d), the retailer\nreceived the request from the retail customer on the\ncommencement date.\n\n","sortOrder":130},{"sectionNumber":"Sch 3","sectionType":"schedule","heading":"Further modifications to operation of National Electricity Rules commencing","content":"Schedule 3 Further modifications to operation of National Electricity Rules commencing\non 1 December 2017\nRegulations 2016 281\nSchedule 3 Further modifications to operation of National\nElectricity Rules commencing on\nregulation 9\nRules with effect on and from 1 December 2017.\n2 Clause 8.6.1A replaced\nClause 8.6.1A\nrepeal, insert\n8.6.1A Application\nFor the purposes of this Part only, \"Registered Participant\" is\ndeemed to include not just Registered Participants but also\nMetering Providers and Metering Data Providers.\n3 Chapter 10 modified\nChapter 10, definition retail customer\nretail customer\nHas the same meaning as in the National Electricity Law.\nOtherwise, a person to whom electricity is sold by a retailer, and\nsupplied in respect of connection points, for the premises of the\nperson, and includes a person (or a person who is of a class of\npersons) prescribed by these Rules for the purposes of this\ndefinition.\nIn the context of Chapter 5A, the above definition has been supplemented by a\ndefinition specifically applicable to that Chapter. See clause 5A.A.1.\n\n","sortOrder":131},{"sectionNumber":"Sch 4","sectionType":"schedule","heading":"Further modifications to operation of National Electricity Rules commencing","content":"Schedule 4 Further modifications to operation of National Electricity Rules commencing\non 1 July 2019\nRegulations 2016 282\nSchedule 4 Further modifications to operation of National\nElectricity Rules commencing on 1 July 2019\nregulation 9A\nRules with effect on and from 1 July 2019.\n2 Chapter 10 modified\nChapter 10, definition Registered Participant\nRegistered Participant\nEach of the following:\n(a) a Registered participant as defined in the National Electricity\nLaw;\n(b) for the purposes of the Rules, other than Chapter 5, Part A – a\n(c) as set out in clause 8.6.1A, for the purposes of Chapter 8, Part\nC – a Metering Provider or Metering Data Provider.\n\nRegulations 2016 283\n1 KEY Key to abbreviations\namd = amended od = order\napp = appendix om = omitted\nbl = by-law pt = Part\nch = Chapter r = regulation/rule\ncl = clause rem = remainder\ndiv = Division renum = renumbered\nexp = expires/expired rep = repealed\nf = forms s = section\nGaz = Gazette sch = Schedule\nhdg = heading sdiv = Subdivision\nins = inserted SL = Subordinate Legislation\nlt = long title sub = substituted\nnc = not commenced\n2 LIST OF LEGISLATION\nRegulations 2016 (SL No. 17, 2016)\nNotified 27 April 2016\nCommenced r 9 and sch 3: 1 December 2016; rem:1 July 2016 (r 2)\nAmendment Regulations 2017 (SL No. 17, 2017)\nNotified 29 June 2017\nCommenced 1 July 2017 (r 2)\nAmendment Regulations 2018 (SL No. 26, 2018)\nNotified 19 December 2018\nCommenced 19 December 2018\nAmendment Regulations 2019 (SL No. 15, 2019)\nNotified 1 July 2019\nCommenced 1 July 2019 (r 2)\nStatute Law Revision Act 2020 (Act No. 26, 2020)\nAssent 19 November 2020\nCommenced 20 November 2020 (s 2)\nAmendment Regulations 2021(SL No. 21, 2021)\nNotified 22 December 2021\nCommenced 22 December 2021\nAmendment Regulations 2024 (SL No. 12, 2024)\nDate made 27 June 2024\nCommenced 28 June 2024 (r 2)\n\nRegulations 2016 284\nElectricity Legislation Amendment Regulations 2024 (SL No. 13, 2024)\nDate made 27 June 2024\nCommenced 1 July 2024 (r 2, s 2(2) Electricity Legislation Amendment\nAct 2024 (Act No. 26, 2023) and Gaz S54, 26 June 2024)\n3 GENERAL AMENDMENTS\nGeneral amendments of a formal nature (which are not referred to in the table\nof amendments to this reprint) are made by the Interpretation Legislation\nAmendment Act 2018 (Act No. 22, 2018) to: r 1.\n4 LIST OF AMENDMENTS\nr 2A ins No. 17, 2017, r 4\nr 4 amd No. 17, 2017, r 5\nr 5A ins No. 17, 2017, r 6\namd No. 15, 2019, r 4\nr 6 amd No. 17, 2017, r 7\nr 6A ins No. 17, 2017, r 8\nexp No. 17, 2016, r 11(2) as sub by No. 17, 2017, r 12\nr 7 exp No. 17, 2016, r 11(2) as sub by No. 17, 2017, r 12\nr 9 sub No. 17, 2017, r 9\nr 9A ins No. 17, 2017, r 9\nr 10 amd No. 13, 2024, r 14\npt 4 hdg amd No. 17, 2017, r 10\nr 10A ins No. 17, 2017, r 11\nexp No. 17, 2016, r 11(2) as sub by No. 17, 2017, r 12\nr 11 sub No. 17, 2017, r 12\nsch 1 amd No. 17, 2017, r 13; No. 15, 2019, r 5; No. 17, 2016, r 11(2) as sub by\nNo. 17, 2017, r 12\nsch 2 amd No. 17, 2016, r 11(6); No. 17, 2017, r 14; No. 26, 2018, r 4; No. 17,\n2016, r 11(1) as sub by No. 17, 2017, r 12; No. 15, 2019, rr 6 to 22; Act\nNo. 26, 2020, s 3; No. 21, 2021, r 4; No. 17, 2016, r 11(2) as sub by No. 17,\n2017, r 12; No. 12, 2024, r 4\nsch 3 sub No. 17, 2017, r 15\nsch 4 ins No. 17, 2017, r 15","sortOrder":132}],"analysis":{"kimi_summary":{"_metrics":{"completionTokens":656},"content_quality":"ok","complexity_score":9,"scope_assessment":{"changed":false,"description":"The legislation appears to remain within its original scope of adapting national electricity rules for NT application. The extensive modifications and phased implementation notes are consistent with the stated purpose of providing a transitional framework for NT adoption of national uniform legislation."},"complexity_factors":["Extensive cross-referencing — the legislation modifies another set of rules (the National Electricity Rules) rather than standing alone","Numerous defined terms with NT-specific meanings (e.g., 'local electricity system', 'NTESMO', '2014 NT Network Price Determination')","Layered commencement and expiry dates — different provisions take effect at different times (1 July 2016, 1 December 2016, 1 July 2017, 1 July 2019, 1 July 2024, 1 July 2029)","Conditional application — many rules are explicitly noted as having 'no effect in this jurisdiction' or being subject to future 'phased implementation'","Nested modifications within modifications — Schedule 2 contains over 100 clauses each modifying specific rules, often with multiple sub-modifications per clause","Technical metering specifications in Chapter 7A with detailed accuracy requirements, testing intervals, and substitution methodologies","Interaction between national law, NT legislation, and 'jurisdictional electricity legislation' creating a three-layer regulatory framework"],"plain_english_summary":"This legislation adapts the **National Electricity Rules** (which govern Australia's national electricity market) specifically for the **Northern Territory**. Think of it as a \"translation guide\" that makes the national rules work for the NT's unique situation.\n\n**What it does:**\n- **Modifies** the national electricity regulations and rules so they apply in the NT, replacing references to national bodies like AEMO (the Australian Energy Market Operator) with **NTESMO** (the Northern Territory's equivalent)\n- **Phases in** the national framework gradually — many complex market rules (like full retail competition and national metering standards) are noted as \"will be revisited as part of phased implementation\"\n- **Preserves NT-specific arrangements** — for example, keeping the **Utilities Commission** as the local regulator rather than shifting everything to national bodies, and maintaining the **2014 NT Network Price Determination** as the basis for network pricing during the transition\n- **Creates a transitional metering framework** (Chapter 7A) that sits in place of the national metering rules until the NT is ready to adopt the full national system\n\n**Who it affects:**\n- **Power and Water Corporation** — the main NT network service provider\n- **Electricity retailers and generators** operating in the NT\n- **Large energy users** connecting to the network\n- **The Utilities Commission** and **NTESMO** — the local regulatory bodies\n\n**Why it matters:**\nThe NT isn't fully integrated into the National Electricity Market (NEM) like the eastern states. This legislation provides a pathway to bring the NT into alignment with national standards while respecting its smaller scale, different market structure, and existing regulatory arrangements. It's essentially a **bridge** between the NT's current system and the national framework."},"issue_detection":{"absurdities":[],"contradictions":[]},"flash_summary_failed":{"failed":true,"reason":"A positive credit balance is required for all requests, including BYOK, so fallback providers remain available. Add credits at https://vercel.com/d?to=%2F%5Bteam%5D%2F%7E%2Fai%3Fmodal%3Dtop-up to continue.","source":"analysis-cron"},"summary":{"complexity_score":6,"scope_assessment":{"changed":false,"description":"Based on available information, the instrument appears to remain consistent with its original purpose: adapting national electricity rules for NT-specific application. There is no indication of scope creep beyond the intended modification role, though the lengthy delayed commencement may reflect adjustments in how broadly the modifications were designed to apply."},"complexity_factors":["Operates as a modification layer on top of already-complex national electricity law, requiring readers to cross-reference the National Electricity Law and Rules simultaneously","The NT's adoption of national uniform legislation adds a further jurisdictional layer — you must understand both Commonwealth/national frameworks and NT-specific implementation","The 5-year gap between making (2019) and commencement (2024) creates temporal complexity — users must track which rules apply at which point in time","The title references multiple nested legislative concepts: 'national uniform legislation', 'modification regulations', and jurisdiction-specific application","Electricity regulation is a technically specialised area with significant industry-specific terminology (NEM, network tariffs, ring-fencing, etc.)","The actual modification content is not visible in the extract provided, but modification regulations of this type typically alter specific provisions by substituting, omitting or inserting text — making them impossible to understand without reading the parent instrument in parallel"],"plain_english_summary":"These regulations adapt Australia’s national electricity rules for the Northern Territory, overriding or adjusting parts so they fit the NT’s smaller, more isolated grid and market. They affect NT electricity businesses, consumers and regulators by shaping how the national framework applies locally. Made in June 2019, the instrument only takes effect on 1 July 2024, aligning the changes with a planned transition timetable."},"flash_summary":{"complexity_score":10,"scope_assessment":{"changed":true,"description":"Yes. The Regulations go beyond a narrow, mechanical localising of the National Electricity Rules and instead create an extensive, NT‑specific regime. That expansion includes (a) insertion of a full metering chapter (Chapter 7A) with detailed technical, security and data obligations; (b) substitution of national operational roles with NT bodies (NTESMO and the Utilities Commission) across hundreds of provisions; (c) bespoke economic/regulatory treatments for the NT first regulatory control period (special roll‑forward, RAB and building block rules); and (d) many staged carve‑outs and time‑limited exceptions that produce a complex transitional architecture (see regulation 5A, Schedule 2 generally, and Chapter 11A). These additions substantially increase the instrument's substantive scope — from \"modification to localise national rules\" to establishing a tailored local regulatory, operational and technical framework for the NT electricity system."},"complexity_factors":["Very large instrument (Schedules run to hundreds of clauses and pages) — Schedule 2 alone modifies virtually every Chapter and inserts Chapter 7A with multiple technical schedules.","High number of defined terms changed/added (Chapter 10 substitutions, many new definitions: e.g. accumulated metering data, calculated metering data, NT NMI data, 1st/2nd regulatory control period).","Extensive cross‑referencing between national Rules, NT 'jurisdictional electricity legislation' and the 2014 NT Network Price Determination (many clauses replace references to national schedules with 'jurisdictional electricity legislation').","Multiple nested exceptions and 'no effect' carve‑outs across many clauses (e.g. regulation 5A and numerous \"Note: ... has no effect in this jurisdiction\" annotations).","Phased implementation with multiple commencement dates and staggered expiries (1 Jul 2016, 1 Dec 2016, 1 Jul 2019, 31 Mar 2025, expiries 2019/2024/2029 and 'when NERL applied' — see regulation 2, 9, 9A, 11 and Chapter 11A).","Replacement of national institutions with local equivalents across hundreds of references (AEMO → NTESMO) — operational semantics change throughout the Rules.","Insertion of detailed technical metering regime (Chapter 7A and Schedules 7A.1–7A.8) including metering types, accuracy tables, testing regimes, data formats, security, retention, and substitution/estimation algorithms.","Complex economic/regulatory modifications with bespoke RAB roll‑forward and building block treatments (S6.2.3A, S6.1.1/S6.1.2 amendments) and adoption of specific AER guidelines/models as of fixed dates.","Multiple civil penalty classifications and audit/retention obligations cross‑linked to jurisdictional regulations — legal and enforcement complexity.","Transitional rules that both alter immediate obligations and create future switching points (many provisions marked to be 'revisited' as part of phased implementation), producing conditional logic at multiple layers."],"plain_english_summary":"**What this instrument does (mechanics first)\n\n- This instrument makes the National Electricity Rules (NER) and the National Electricity Regulations operate as the local NT electricity law, but with a large set of specified Northern Territory (NT) modifications and carve‑outs so the national rules fit the NT context (see regulation 5 and Schedule 2).\n- It replaces many references to national bodies and arrangements with NT equivalents (for example, substituting NTESMO — the Northern Territory Electricity System and Market Operator — for AEMO in many provisions: Schedule 2, many clauses). It also preserves functions for the NT Utilities Commission and Power and Water Corporation where appropriate (see Schedule 2, e.g. clauses about registers and metering roles).\n- It inserts a comprehensive NT metering regime (Chapter 7A and extensive Schedules 7A.1–7A.8) that sets out roles (Metering Coordinator, Metering Provider, Metering Data Provider), technical metering types, accuracy, testing, data handling, metering database requirements, security and reporting obligations (Schedule 2, clause 87 and following schedules).\n- It modifies economic/regulatory chapters (Chapter 6 and related Schedules) to fit NT circumstances: single‑system treatment for Distribution Network Service Providers that own multiple networks, special roll‑forward and opening RAB (regulatory asset base) rules, adoption of specified AER guidelines/models as of fixed dates, and transitional arrangements for the first regulatory control period (various clauses in Schedule 2, notably Rules 6.0/6.0A and numerous clause modifications in Chapter 6 and S6 schedules).\n- It creates NT‑specific treatments for 'local events' and retailer insolvency pass‑throughs (regulation 6 and regulation 10), including how Distribution Network Service Providers recover (or must exclude) costs recoverable under local credit support or winding‑up.\n- It stages implementation and sunsets many special modifications: some rules commence immediately, some on 1 Dec 2016 or 1 July 2019, several provisions expire on fixed dates (1 July 2019, 1 July 2024, 1 July 2029) or when the National Energy Retail Law (NERL) is adopted in the NT (regulation 2, 9, 9A and regulation 11).\n\nWho is directly affected\n\n- Power and Water Corporation (the incumbent Local Network Service Provider) and NT network businesses: the instrument preserves NT-specific regulatory arrangements (opening RAB, building block treatment and transitional regulatory rules) and treats multiple distribution systems owned by one provider as a single system for some regulatory purposes (Schedule 2, rules 6.0/6.0A; S6.2.3A).\n- NTESMO and the Utilities Commission: NTESMO gains operational, metering and data roles formerly exercised by AEMO in other jurisdictions (see Schedule 2, multiple substitutions AEMO → NTESMO and Chapter 7A). The Utilities Commission retains licensing, oversight and audit roles (see Schedule 2 references and Chapter 11A transitional rules).\n- Metering market participants (Metering Coordinators, Metering Providers, Metering Data Providers) and retailers: Chapter 7A imposes detailed technical, security, testing and record‑keeping obligations (schedules 7A.1–7A.8). The Local Network Service Provider is, for many connection types, taken to be accredited and the default Metering Coordinator/Provider (see Schedule 2, e.g. 7A.4.1(b),(c); 7A.5).\n- Generators, connection applicants and network users: connection processes, technical standards and negotiation/dispute pathways are adjusted to use ‘jurisdictional electricity legislation’ for many technical requirements and to bring transmission and distribution negotiating frameworks into a common Chapter 6 context (see many amendments in Schedule 2, e.g. rules 5.2–5.3, 5.2A, 6.22.2).\n- Retailers and customers: meter installation timeframes, prepayment device rules, and disclosure/consumer data provisions are set out in Chapter 7A (see 7A.6.10–7A.6.14, 7A.11–7A.12).\n\nWhy it matters (official purpose, and practical trade‑offs)\n\n- Officially the Regulations are the NT’s way of applying the national rules while preserving NT jurisdictional arrangements and implementing the NER in stages. The instrument claims to permit a \"phased implementation\" so the NT can adopt national obligations where practical (see regulation 5A and many \"Note: ... will be revisited as part of phased implementation\" annotations in Schedule 2).\n\n- Practical trade‑offs and the mechanics that drive them:\n  - Implementation cost and capability requirements are concentrated on the bodies that must operate metering databases and system control locally — NTESMO, the Metering Data Provider and Metering Providers. The instrument sets hard technical and data‑retention obligations (e.g. metering data retention, clocks synced to ACST, storage windows) that will require investment in IT, metering hardware and processes (see Chapter 7A and Schedules 7A.7 and 7A.8).\n  - The Local Network Service Provider (Power and Water) is given default accreditation and several default roles (for certain meter types and as Metering Coordinator/Provider), which reduces immediate market entry for independent metering businesses in those areas but preserves continuity and lowers short‑term rollout risk (see 7A.4 and 7A.5). The Rules allow contracting out, however, subject to accreditation and safety requirements (7A.4.1(d), 7A.4.2(d)).\n  - Replacing AEMO with an NT operator (NTESMO) increases local operational control and faster local decision‑making (NTESMO handles metering database, some security and emergency coordination), but introduces coordination costs with national market bodies when interconnection occurs. The instrument pre‑specifies many AER guidelines and models as of particular dates (for example, post‑tax revenue model, Rate of Return Guidelines, shared asset and expenditure guidelines as taken in force on 1 July 2016/2019) so certain regulatory metrics are imported wholesale rather than generated locally (see Schedule 2 clauses 47, 52, 53, 49, 50). That reduces regulatory uncertainty for investors but cedes future local tailoring unless revised later.\n  - Many national NER provisions are expressly disabled (marked as \"no effect\") in the NT (regulation 5A and many notes in Schedule 2). That narrows immediate scope and reduces compliance burden in the short term, but it also delays harmonisation with the national market and leaves a complex transitional patchwork.\n\nWho pays, who decides, what behaviour changes\n\n- Who pays: network businesses, Metering Providers/Providers, and retailers will bear the capital and operating costs of compliance (meter replacements, testing, data systems, security, accreditation). The Rules also preserve mechanisms for cost recovery through distribution determinations and pass‑throughs, but with NT‑specific limits and exclusions (see clause 6.6.1 modified by regulation 6 and Part 3 definition of local event, regulation 10). Retailer insolvency costs and amounts recoverable under local credit supports are specifically excluded from some pass‑through calculations (regulation 6(3)).\n- Who decides: NT bodies (NTESMO, Utilities Commission, Power and Water) have increased decision and operational authority locally; the AER still has the economic regulatory role for distribution determinations but within NT‑modified rules; many AER instruments/guidelines are taken as if published on fixed dates (Schedule 2, multiple clauses) to provide certainty.\n- Behaviour changes induced: network owners must prepare building block proposals and RAB roll‑forwards under NT‑specific methodologies; metering market participants must meet accreditation, testing and data‑handling standards; retailers and customers face defined meter installation timeframes and new data access rights; generators and connection applicants will negotiate under amended connection and access rules that reference jurisdictional electricity legislation.\n\nCosts, incentives, trade‑offs, implementation risk and compliance burden (concrete mechanisms)\n\n- Compliance and investment cost: detailed technical standards (meter classes, storage windows, test intervals, ISO quality system requirements) and data‑retention rules create measurable IT and hardware costs for Metering Providers and Data Providers (see Chapter 7A and Schedules S7A.4–S7A.8). The instrument sets explicit insurance and auditing requirements (e.g. public liability, professional indemnity and audit cooperation obligations in S7A.8).\n- Concentrated benefits / concentrated costs: incumbents (Power and Water; the NT Metering Data Provider) get preserved roles and transitional protection. Independent metering businesses face a higher barrier to immediate competition where the Local Network Service Provider is taken to be accredited and the default supplier for many meter types (see 7A.4.1(b),(c)).\n- Rent‑seeking and capture risk: the instrument's substantial tailoring and adoption of specific guideline versions (AER instruments as of fixed dates) concentrates influence over implementation on entities (Utilities Commission, NTESMO, Power and Water) that were involved in the local design. The drafting locks in particular AER models/guidelines rather than leaving full discretion to later AER decisions (see Schedule 2 clauses adopting guidelines/models as at specified dates, e.g. 6.4.1(ca), 6.4.4(ea), 6.5.1(da), 6.5.2(qa)).\n- Substitution effects and unintended consequences: phased carve‑outs and \"no effect\" labels defer some national obligations; that reduces immediate operational complexity but risks additional future transition costs when phased‑in provisions finally take effect (transition deadlines scattered across 2019, 2024, 2029 and the date NERL applies — see regulation 11).\n- Implementation risk: NTESMO and the Metering Data Provider must stand up a metering database and validation/substitution processes. The instrument recognises this by providing transitional relief and explicit timelines (e.g. Chapter 11A transitional rules and rule 11A.5 requiring full compliance by 31 March 2025 for metering database obligations). If the local providers lack capacity or funding, delivery risk is high.\n\nSelected key references (where to look in the instrument)\n\n- How national rules are modified and what is excluded: regulation 5A and Schedule 2 notes.\n- Local event / retailer insolvency and pass‑through treatment: regulation 6 and regulation 10.\n- Metering chapter and technical metering rules: Schedule 2 insertion of Chapter 7A (clause 87 and following), Schedules 7A.1–7A.8.\n- Economic/regulatory modifications (RAB, building blocks, AER guideline adoption): Schedule 2 (rules 6.0/6.0A, S6.2.3A, clauses 6.4.1, 6.4.4, 6.4.5, 6.5.1–6.5.2, 6.22.2 and many S6 provisions).\n- Transitional and expiry mechanisms: regulation 11 and Chapter 11A transitional rules (Schedule 2, Chapter 11A).\n\nBottom line\n\nMechanically, these Regulations transplant the national rules into NT law but with an extensive, NT‑specific set of modifications that (1) replace national operational bodies/functions with local counterparts (NTESMO, Utilities Commission, Power and Water), (2) introduce a full NT metering regime, (3) adjust economic regulation and cost recovery rules to NT historical determinations and the first regulatory control period, and (4) stage and time‑limit many modifications while preserving the possibility of later harmonisation. The largest practical effects are increased compliance and capital costs for metering and data systems, a shift of operational control to NT institutions, and transitional protection for existing NT institutions and regulatory arrangements (see regulation 5A; Schedule 2; Chapter 7A; Chapter 11A)."}},"importantCases":[],"_links":{"self":"/api/acts/national-electricity-northern-territory-national-uniform-legislation-modification-regulations-2016","history":"/api/acts/national-electricity-northern-territory-national-uniform-legislation-modification-regulations-2016/history","analysis":"/api/acts/national-electricity-northern-territory-national-uniform-legislation-modification-regulations-2016/analysis","conflicts":"/api/acts/national-electricity-northern-territory-national-uniform-legislation-modification-regulations-2016/conflicts","importantCases":"/api/acts/national-electricity-northern-territory-national-uniform-legislation-modification-regulations-2016/important-cases","documents":"/api/acts/national-electricity-northern-territory-national-uniform-legislation-modification-regulations-2016/documents"}}