NATIONAL ELECTRICITY (NORTHERN TERRITORY) (NATIONAL UNIFORM LEGISLATION) (MODIFICATION) REGULATIONS 2016
The current version of the National Electricity Rules, as modified by these
Regulations, is available at: http://www.aemc.gov.au/Energy-Rules/National-
electricity-rules/National-Electricity-Rules-(Northern-Territory)
NORTHERN TERRITORY OF AUSTRALIA
NATIONAL ELECTRICITY (NORTHERN TERRITORY) (NATIONAL
UNIFORM LEGISLATION) (MODIFICATION) REGULATIONS 2016
As in force at 1 July 2024
Table of provisions
Part 1 Preliminary matters
1 Citation ............................................................................................ 1
2 Commencement .............................................................................. 1
2A Definitions ........................................................................................ 1
Part 2 Modifications to National Electricity
Regulations
3 National Electricity Regulations modified ......................................... 1
Part 3 Modifications to National Electricity Rules
4 Interpretation ................................................................................... 2
5 National Electricity Rules modified .................................................. 2
5A Application of Rules in this jurisdiction ............................................. 2
6 Modification to operation of clause 6.6.1 in relation to local
events .............................................................................................. 3
8 Further modifications to operation of Rules ..................................... 4
9 Further modifications to operation of Rules commencing on
1 December 2017 ............................................................................ 4
9A Further modifications to operation of Rules commencing on
1 July 2019 ...................................................................................... 4
Part 4 Matters prescribed for National Electricity
(NT) Rules
10 Local event ...................................................................................... 4
Part 5 Expiry of provisions
11 Expiry of certain provisions .............................................................. 5
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Schedule 1 Modifications to National Electricity
Regulations
Part 1 Preliminary matters
1 Regulations modified ....................................................................... 7
Part 2 Modifications
2 Regulation 8 modified ...................................................................... 7
3A Schedule 1 modified ........................................................................ 7
4 Schedule 2 modified ........................................................................ 8
Schedule 2 Further modifications to operation of
National Electricity Rules
Part 1 Preliminary matters
1 Rules modified ................................................................................. 9
Part 2 Modifications
2 Clauses 1.7.1A and 1.7.1B inserted ................................................ 9
3 Clause 1.8.1 modified .................................................................... 10
3A Rule 1.9A inserted ......................................................................... 11
4 Rule 1.11 modified......................................................................... 11
5 Chapters 2, 2A, 3 and 4 modified .................................................. 11
6 Clause 5.1.2 modified .................................................................... 12
7 Clause 5.1.3 inserted ..................................................................... 14
8 Clause 5.1A.2 modified ................................................................. 15
9 Clause 5.1A.3 inserted .................................................................. 15
10 Clause 5.2.1 modified .................................................................... 16
11 Clause 5.2.2 modified .................................................................... 16
12 Clause 5.2.3 modified .................................................................... 17
13 Clause 5.2.4 modified .................................................................... 20
14 Clause 5.2.5 modified .................................................................... 22
15 Clause 5.2.7 modified .................................................................... 23
16 Clause 5.2A.2 modified ................................................................. 23
17 Clause 5.2A.3 modified ................................................................. 24
18 Clause 5.2A.6 modified ................................................................. 25
19 Clause 5.2A.8 modified ................................................................. 25
20 Clause 5.3.1 modified .................................................................... 25
21 Clause 5.3.1A modified ................................................................. 26
22 Clause 5.3.2 modified .................................................................... 27
23 Clause 5.3.3 modified .................................................................... 27
24 Clause 5.3.4 modified .................................................................... 28
25 Clause 5.3.4A modified ................................................................. 29
25A Clause 5.3.4B modified ................................................................. 29
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25B Clause 5.3.5 modified .................................................................... 29
25C Clause 5.3.6 modified .................................................................... 30
25D Clause 5.3.7 modified .................................................................... 32
25E Clause 5.3.8 modified .................................................................... 33
25F Clause 5.3.9 modified .................................................................... 33
25G Clause 5.3.10 modified .................................................................. 36
25H Clause 5.3.11 modified .................................................................. 37
25I Clause 5.3A.1 modified ................................................................. 37
25J Clause 5.3A.3 modified ................................................................. 38
25K Clause 5.3A.4 modified ................................................................. 39
25L Clause 5.3A.8 modified ................................................................. 39
25M Clause 5.3A.9 modified ................................................................. 39
25N Clause 5.3A.10 modified................................................................ 40
25O Clause 5.3A.12 modified................................................................ 40
25P Rule 5.3AA modified ...................................................................... 41
25Q Clause 5.4.3 modified .................................................................... 41
25R Clause 5.4.5 modified .................................................................... 41
25S Clause 5.5.1 modified .................................................................... 41
25T Clause 5.6.1 modified .................................................................... 42
25U Clause 5.6.2 modified .................................................................... 42
25V Clause 5.7.1 modified .................................................................... 43
25W Clause 5.7.2 modified .................................................................... 44
25X Clause 5.7.3 modified .................................................................... 44
25Y Clause 5.7.3A modified ................................................................. 47
25Z Clause 5.7.4 modified .................................................................... 47
25ZA Clause 5.7.5 modified .................................................................... 48
25ZB Clause 5.7.6 modified .................................................................... 49
25ZC Clause 5.8.2 modified .................................................................... 50
25ZD Clause 5.8.3 modified .................................................................... 50
25ZE Clause 5.8.4 modified .................................................................... 51
25ZF Clause 5.8.5 modified .................................................................... 51
25ZG Clause 5.9.2 modified .................................................................... 51
25ZH Clause 5.9.3 modified .................................................................... 52
25ZI Clause 5.9.4 modified .................................................................... 52
25ZJ Clause 5.9.4A modified ................................................................. 53
25ZK Clause 5.9.5 modified .................................................................... 53
25ZL Clause 5.9.6 modified .................................................................... 53
25ZM Clause 5.10.1 modified .................................................................. 54
25ZN Clause 5.10.2 modified .................................................................. 54
25ZO Clause 5.11.1 modified .................................................................. 55
25ZP Clause 5.11.2 modified .................................................................. 55
25ZQ Clause 5.12.1 modified .................................................................. 56
25ZR Clause 5.12.2 modified .................................................................. 56
25ZS Clause 5.13.1 modified .................................................................. 57
25ZT Clause 5.13.2 modified .................................................................. 57
25ZU Clause 5.13.3 modified .................................................................. 57
25ZV Rule 5.13A modified ...................................................................... 58
25ZW Clause 5.14.1 modified .................................................................. 58
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25ZX Clause 5.14B.1 modified................................................................ 58
25ZY Clause 5.15.1 modified .................................................................. 58
25ZZ Clause 5.15.2 modified .................................................................. 58
25ZZA Clause 5.16.1 modified .................................................................. 59
25ZZB Clause 5.16.2 modified .................................................................. 59
25ZZC Clause 5.16.3 modified .................................................................. 59
25ZZD Clause 5.16.4 modified .................................................................. 60
25ZZE Clause 5.16.5 modified .................................................................. 60
25ZZF Clause 5.17.1 modified .................................................................. 60
25ZZG Clause 5.17.2 modified .................................................................. 61
25ZZH Clause 5.17.3 modified .................................................................. 61
25ZZI Clause 5.17.4 modified .................................................................. 61
25ZZJ Clause 5.17.5 modified .................................................................. 62
25ZZK Rule 5.18 modified......................................................................... 62
25ZZL Rule 5.18A modified ...................................................................... 63
25ZZM Clause 5.18A.1 modified................................................................ 63
25ZZN Clause 5.18A.2 modified................................................................ 63
25ZZO Clause 5.18A.3 modified................................................................ 64
25ZZP Clause 5.18B.1 modified................................................................ 65
25ZZQ Rule 5.20 modified......................................................................... 65
25ZZR Rules 5.20A, 5.20B and 5.20C modified ........................................ 66
25ZZS Rules 5.21 and 5.22 modified ........................................................ 66
25ZZT Schedules 5.1a to 5.3a modified ................................................... 66
25ZZU Schedule 5.4A modified ................................................................. 66
25ZZV Schedule 5.4B modified ................................................................. 67
25ZZW Schedules 5.5, 5.5.3, 5.5.4 and 5.5.5 modified.............................. 67
25ZZX Schedule 5.6 modified ................................................................... 68
25ZZY Schedule 5.8 modified ................................................................... 68
25ZZZ Schedule 5.9 modified ................................................................... 69
25ZZZA Schedule 5.11 modified ................................................................. 69
25ZZZB Schedule 5.12 modified ................................................................. 70
26 Clause 5A.A.1 modified ................................................................. 70
27 Clause 5A.A.2 modified ................................................................. 70
28 Clause 5A.A.3 modified ................................................................. 70
30 Clause 5A.B.3 modified ................................................................. 71
31 Clause 5A.B.5 modified ................................................................. 71
33 Clause 5A.C.1 modified ................................................................. 71
34 Clause 5A.D.1A modified............................................................... 71
38 Clause 5A.E.3 modified ................................................................. 72
39 Clause 5A.E.4 modified ................................................................. 72
41 Clause 5A.F.5 modified ................................................................. 72
42 Rules 6.0 and 6.0A inserted .......................................................... 73
43 Clause 6.1.3 modified .................................................................... 74
44 Clause 6.2.1 modified .................................................................... 75
47 Clause 6.4.1 modified .................................................................... 76
49 Clause 6.4.4 modified .................................................................... 76
50 Clause 6.4.5 modified .................................................................... 77
51 Rule 6.4A modified ........................................................................ 77
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52 Clause 6.5.1 modified .................................................................... 78
53 Clause 6.5.2 modified .................................................................... 78
54 Clause 6.5.8 modified .................................................................... 79
55 Clause 6.5.8A modified ................................................................. 79
56 Clause 6.6.1 modified .................................................................... 80
57 Clause 6.6.1 modified (expires when NERL applied) .................... 80
60 Clause 6.6.2 modified .................................................................... 80
61 Clause 6.6.3 modified .................................................................... 81
62 Clause 6.6.4 modified .................................................................... 81
63 Clause 6.6A.1 modified ................................................................. 81
63A Clause 6.7.1 modified .................................................................... 81
63B Clause 6.7.2 modified .................................................................... 82
63C Clause 6.7.5 modified .................................................................... 83
68 Rule 6.14A modified ...................................................................... 83
69 Clause 6.15.3 modified .................................................................. 84
70 Clause 6.15.4 modified .................................................................. 84
72 Clause 6.17.1B inserted ................................................................ 85
74 Clause 6.18.9 modified .................................................................. 85
75 Chapter 6, Parts M and N modified ............................................... 86
75A Rule 6.20.1 modified ...................................................................... 86
75B Rule 6.21.3 modified ...................................................................... 88
75C Rule 6.22.2 modified ...................................................................... 89
77 Clause S6.1.1 modified ................................................................. 90
78 Clause S6.1.2 modified ................................................................. 92
79 Clause S6.2.1 modified ................................................................. 93
80 Clause S6.2.1 modified ................................................................. 94
82 Clause S6.2.2A modified ............................................................... 94
83 Clause S6.2.2B modified ............................................................... 95
84 Clause S6.2.3A inserted ................................................................ 95
85 Chapters 6A and 6B modified ........................................................ 98
86 Chapter 7 modified ........................................................................ 98
87 Chapter 7A inserted ....................................................................... 98
88 Clause 8.1.3 modified .................................................................. 249
89 Chapter 8, Part B modified .......................................................... 250
90 Clause 8.6.1 modified .................................................................. 250
91 Clause 8.6.2 modified .................................................................. 250
92 Clause 8.6.5 replaced .................................................................. 250
93 Clauses 8.6.6 and 8.6.7 modified ................................................ 251
94 Clause 8.7.1 modified .................................................................. 251
95 Clause 8.7.2 modified .................................................................. 251
96 Clause 8.7.6 modified .................................................................. 253
97 Chapter 8, Parts E and G modified .............................................. 253
98 Chapter 8, Parts H modified ........................................................ 253
99 Chapter 10 modified .................................................................... 253
99A Chapter 10 modified (further definitions substituted and
inserted)....................................................................................... 265
102 Chapter 10 modified (expires on 1 July 2029) ............................. 271
103 Chapter 10 modified (expires when NERL is applied) ................. 271
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104 Chapter 11 modified .................................................................... 272
105 Clause 11.93.1 modified .............................................................. 272
106 Chapter 11A inserted ................................................................... 272
Schedule 3 Further modifications to operation of
National Electricity Rules commencing on
1 December 2017
1 Rules modified ............................................................................. 281
2 Clause 8.6.1A replaced ............................................................... 281
3 Chapter 10 modified .................................................................... 281
Schedule 4 Further modifications to operation of
National Electricity Rules commencing on
1 July 2019
1 Rules modified ............................................................................. 282
2 Chapter 10 modified .................................................................... 282
ENDNOTES
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NORTHERN TERRITORY OF AUSTRALIA
____________________
As in force at 1 July 2024
____________________
NATIONAL ELECTRICITY (NORTHERN TERRITORY) (NATIONAL
UNIFORM LEGISLATION) (MODIFICATION) REGULATIONS 2016
Regulations under the National Electricity (Northern Territory) (National
Uniform) Legislation Act 2015
Part 1 Preliminary matters
1 Citation
These Regulations may be cited as the National Electricity
(Northern Territory) (National Uniform Legislation) (Modification)
Regulations 2016.
2 Commencement
(1) Regulation 9 and Schedule 3 commence on 1 December 2016.
(2) The remaining provisions of these Regulations commence on
1 July 2016.
2A Definitions
In these Regulations:
2014 NT Network Price Determination, for Part 3, see
regulation 4(1).
applicable regulatory instruments, for Part 3, see regulation 4(1).
local support, for Part 3, see regulation 4(1).
Part 2 Modifications to National Electricity
Regulations
3 National Electricity Regulations modified
For section 13(2)(b) of the Act, the regulations in force from time to
time under Part 4 of the National Electricity (South Australia)
Act 1996 (SA) are modified as set out in Schedule 1.
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Part 3 Modifications to National Electricity Rules
National Electricity (Northern Territory) (National Uniform Legislation) (Modification)
Regulations 2016 2
Part 3 Modifications to National Electricity Rules
4 Interpretation
(1) In this Part:
2014 NT Network Price Determination, see the National
Electricity (NT) Rules, Chapter 10.
applicable regulatory instruments, see the 2014 NT Network
Price Determination, Part B, Schedule 1, clause 1.1.
local support means credit support as defined in the 2014 NT
Network Price Determination, Part B, Schedule 1, clause 1.1.
(2) An expression used in regulation 6, 6A or 7 that is italicised has the
same meaning as it has in the National Electricity (NT) Rules.
5 National Electricity Rules modified
For section 13(2)(c) of the Act, the operation of the National
Electricity Rules is modified as set out in this Part for the purpose of
their having the force of law in this jurisdiction under section 9 of the
National Electricity (NT) Law.
5A Application of Rules in this jurisdiction
(1) The following provisions of the National Electricity (NT) Rules have
no effect in this jurisdiction:
(a) Chapter 1, rule 1.11;
(b) Chapters 2, 2A, 3 and 4;
(c) Chapter 5, clauses 5.2.3(a) and (k), 5.2.4(d), 5.2.5(c) and (e),
5.3.3(b2), (b3) and (b4) and 5.3.4(e) and (g), rules 5.3.4A and
5.3.4B, clauses 5.3.5(e), 5.3.6(a2)(3), 5.3.7(c) and (g)(2)(i), (5)
and (6), 5.3.8(b)(1) and (2)(iv), 5.3.9(a)(2), (b)(4), (c), (c1) and
(f), 5.3.10(b)(3) and (c), 5.3A.3(b)(5) and (6)(xi),
5.3A.4(e)(2)(ii), 5.3A.8(h), 5.3A.9(e), (f) and (h) and 5.3A.10(f),
rule 5.3A.12, clauses 5.3AA(h), (i) and (j), 5.4.3(c) and
5.4.5(e)(4), rule 5.7.3A, clauses 5.7.5(a)(2), 5.12.2(c)(6), (6A)
and (8)(ii), 5.16.3(a)(8) to (11), 5.16.4(b)(4), 5.17.3(a)(7) and
5.18A.3(d)(1), rules 5.20 to 5.22, schedules 5.1a to 5.3a,
schedule 5.4A, paragraphs (a)(9), (i1) and (o)(3),
schedule 5.4B, paragraphs (e) and (e1)(2), schedules 5.5,
5.5.3, 5.5.4 and 5.5.5, schedule 5.6, paragraphs (c2) and (c3)
and schedule 5.9, paragraph (h);
(d) Chapter 5A, clause 5A.A.3;
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(e) Chapter 6, Parts M and N;
(f) Chapters 6A, 6B and 7;
(g) Chapter 8, clauses 8.1.3(b)(5) and (7), 8.6.1(d) and (e),
8.6.2(l), 8.6.6, 8.6.7, 8.7.2(a)(2) and (4) and (b)(2) and 8.7.6
and Parts B, E, G and H;
(h) Chapter 11, Parts A to ZZI, ZZK, ZZL, ZZN (except for
clause 11.86.8), ZZO to ZZT, ZZV and ZZX.
(3) The following provisions of the National Electricity (NT) Rules have
no effect in this jurisdiction until the National Energy Retail Law is
applied as a law of this jurisdiction:
(a) Chapter 5A, clause 5A.C.1(c) and (d), the note to
clause 5A.E.4(c) and clause 5A.F.5(b)(2);
(b) Chapter 6, clause 6.6.1(a1)(4), (c)(6)(iii), (l) and (m).
6 Modification to operation of clause 6.6.1 in relation to local
events
(1) This regulation applies in relation to a positive change event that is
a local event prescribed by regulation 10.
(2) Under clause 6.6.1(c) of the National Electricity (NT) Rules, the
written statement in relation to the positive change event must
specify evidence of:
(a) the amount to which the Distribution Network Service Provider
is entitled under any relevant local support; and
(b) the maximum amount of local support (if any) that the
Distribution Network Service Provider was entitled to request
the retailer to provide under the applicable regulatory
instruments; and
(c) any amount that the Distribution Network Service Provider is
likely to receive on a winding-up of the retailer.
(3) For the purposes of calculating, under clause 6.6.1 of the National
Electricity (NT) Rules, the eligible pass through amount in relation
to the positive change event, the increase in costs is the retailer
insolvency costs excluding:
(a) any amount recovered or recoverable from a retailer or a
guarantor of a retailer under any relevant local support; and
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National Electricity (Northern Territory) (National Uniform Legislation) (Modification)
Regulations 2016 4
(b) amounts that the Distribution Network Service Provider is
likely to receive on a winding-up of the retailer; and
(c) any costs that are recoverable on account of the retailer
insolvency under any retailer of last resort scheme established
under the applicable regulatory instruments.
(4) The amount the AER determines, under clause 6.6.1 of the
National Electricity (NT) Rules, should be passed through to
Distribution Network Users in respect of the positive change event
must be taken to be a cost that can be passed through and not a
revenue impact of the event.
8 Further modifications to operation of Rules
Schedule 2 has effect.
9 Further modifications to operation of Rules commencing on
1 December 2017
Schedule 3 has effect.
9A Further modifications to operation of Rules commencing on
1 July 2019
Schedule 4 has effect.
Part 4 Matters prescribed for National Electricity (NT)
Rules
10 Local event
(1) For clause 6.6.1(a1)(1AA) of the National Electricity (NT) Rules, a
local event is either of the following:
(a) the failure of a retailer during a regulatory control period, to
pay a Distribution Network Service Provider an amount to
which the provider is entitled for the provision of direct control
services, if:
(i) an insolvency official has been appointed in respect of
that retailer; and
(ii) the provider is not entitled to payment of that amount in
full under the terms of any local support in respect of that
retailer;
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Part 5 Expiry of provisions
National Electricity (Northern Territory) (National Uniform Legislation) (Modification)
Regulations 2016 5
(b) a circumstance in which the Power and Water Corporation is
required to pay any amount under a cost recovery scheme
determined by the Utilities Commission under section 44G of
the Electricity Reform Act 2000.
(2) In this regulation:
2014 NT Network Price Determination, see the National
Electricity (NT) Rules, Chapter 10.
local support means credit support as defined in the 2014 NT
Network Price Determination, Part B, Schedule 1, clause 1.1.
(3) An expression used in subregulation (1) that is italicised has the
same meaning as it has in the National Electricity (NT) Rules.
Part 5 Expiry of provisions
11 Expiry of certain provisions
(1) Schedule 2, clauses 64, 65, 71, 76 and 100 expire on 1 July 2019.
(2) The following expire on 1 July 2024:
(a) regulations 6A, 7 and 10A;
(b) Schedule 1, clause 3;
(c) Schedule 2, clauses 46, 48, 58, 59, 66, 67, 73 and 101.
(3) Schedule 2, clauses 77, 78, 80, 82 and 102 expire on 1 July 2029.
(4) The following expire when the National Energy Retail Law is
applied as a law of this jurisdiction:
(a) regulations 6 and 10;
(b) Schedule 2, clauses 57 and 103.
(5) Regulations 2A and 4 expire on the later of the following:
(a) the day on which the National Energy Retail Law is applied as
a law of this jurisdiction;
(b) 1 July 2024.
(6) This Part expires on the later of the following:
(a) the day on which the National Energy Retail Law is applied as
a law of this jurisdiction;
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Part 5 Expiry of provisions
National Electricity (Northern Territory) (National Uniform Legislation) (Modification)
Regulations 2016 6
(b) 1 July 2029.
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Schedule 1 Modifications to National Electricity Regulations
National Electricity (Northern Territory) (National Uniform Legislation) (Modification)
Regulations 2016 7
Schedule 1 Modifications to National Electricity
Regulations
regulation 3
Part 1 Preliminary matters
1 Regulations modified
This Schedule modifies the regulations mentioned in regulation 3.
Part 2 Modifications
2 Regulation 8 modified
After regulation 8(2)
insert
(2A) For the purposes of subregulation (1)(d), the reference to "the
national electricity system" in the national electricity objective stated
in section 7 of the new National Electricity Law must be regarded as
including a reference to one or more, or all, of the local electricity
systems, as the case requires.
3A Schedule 1 modified
Schedule 1, after "clause 7.16.2(c)"
insert
clause 7A.2(a)
clause 7A.3.2(a) – (b)
clause 7A.3.2(d) – (f)
clause 7A.6.1(a)
clause 7A.6.1(c)
clause 7A.6.2 (a)(1) – (11)
clause 7A.6.2(e) – (f)
clause 7A.6.5(a)(1) – (2)
clause 7A.6.6(c)
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clause 7A.6.9(a)
clause 7A.6.9(d) – (e)
clause 7A.6.13(c)(1) – (3)
clause 7A.7.2(b)
clause 7A.7.2(e)
clause 7A.7.2(g) – (h)
clause 7A.7.3(a)
clause 7A.8.3(a)(3) – (4)
clause 7A.8.4
clause 7A.8.9(a) – (c)
clause 7A.9.3
clause 7A.13.2(a)
clause 7A.13.3(a) – (b)
clause 7A.13.3(d)
clause 7A.13.4
4 Schedule 2 modified
Schedule 2, clause 22, at the end
insert
However, this clause has no effect in this jurisdiction.
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Schedule 2 Further modifications to operation of National Electricity Rules
National Electricity (Northern Territory) (National Uniform Legislation) (Modification)
Regulations 2016 9
Schedule 2 Further modifications to operation of National
Electricity Rules
regulation 8
Part 1 Preliminary matters
1 Rules modified
This Schedule modifies the operation of the National Electricity
Rules.
Part 2 Modifications
2 Clauses 1.7.1A and 1.7.1B inserted
After clause 1.7.1
insert
1.7.1A Inconsistency with National Measurement Act
If there is an inconsistency between the Rules and the National
Measurement Act, the National Measurement Act prevails to the
extent of the inconsistency.
1.7.1B Instruments
(a) In an instrument made under the Rules:
(1) a reference to the "National Electricity Law", "Law" or "NEL"
must be regarded as a reference to the National Electricity
(NT) Law; and
(2) a reference to the "National Electricity Rules", "Rules" or
"NER" must be regarded as a reference to the National
Electricity Rules as defined in section 2(1) of the National
Electricity (NT) Law.
(b) Paragraph (a) applies despite any provision to the contrary in an
instrument.
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Regulations 2016 10
(c) For the purposes of the application in this jurisdiction of an
instrument made under the Rules:
(1) the reference to "the national electricity system" in the national
electricity objective stated in section 7 of the Law must be
regarded as a reference to one or more, or all, of the local
electricity systems, as the case requires;
(2) if the context or subject matter indicates or requires, a
reference in the instrument to:
(i) "regulatory control period" must be regarded as including
a reference to the 2009-14 NT regulatory control period
and the 2014-19 NT regulatory control period; and
(ii) "distribution determination" must be regarded as
including a reference to the 2009 NT Network Price
Determination and the 2014 NT Network Price
Determination; and
(3) the AER must interpret the instrument consistently with the
objects of the application Act of this jurisdiction and the
modifications made to the National Electricity Law and the
Rules by or under that Act.
(d) In this clause:
2009 NT Network Price Determination means the "Final
Determination – Networks Pricing: 2009 Regulatory Reset" made
by the Utilities Commission under the Utilities Commission Act
(NT), Electricity Reform Act (NT) and Chapter 6 of the NT Network
Access Code that applied from 1 July 2009 to 30 June 2014.
3 Clause 1.8.1 modified
Clause 1.8.1(b)
omit
of Registered Participants maintained by AEMO
insert
kept by the Utilities Commission under section 37 of the Electricity
Reform Act (NT)
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Schedule 2 Further modifications to operation of National Electricity Rules
National Electricity (Northern Territory) (National Uniform Legislation) (Modification)
Regulations 2016 11
3A Rule 1.9A inserted
After rule 1.9
insert
1.9A NTESMO's costs in connection with these Rules
Note
Costs for NTESMO are to be considered as part of the progressive application of
the Rules in this jurisdiction.
Where, for any provision of these Rules, a corporate entity is both a
Network Service Provider and NTESMO, any costs incurred by that
corporate entity in complying with any requirements imposed on
NTESMO under a provision where this clause applies are not to be
recovered by that corporate entity as a Network Service Provider
under Chapter 6.
4 Rule 1.11 modified
After rule 1.11, heading
insert
Note:
This rule has no effect in this jurisdiction (see regulation 5A of the National
Electricity (Northern Territory) (National Uniform Legislation) (Modification)
Regulations).
5 Chapters 2, 2A, 3 and 4 modified
After Chapters 2, 2A, 3, and 4, headings
insert
Note:
This Chapter has no effect in this jurisdiction (see regulation 5A of the National
Electricity (Northern Territory) (National Uniform Legislation) (Modification)
Regulations). The application of this Chapter will be revisited as part of the
phased implementation of the Rules in this jurisdiction.
-- 17 of 290 --
Schedule 2 Further modifications to operation of National Electricity Rules
National Electricity (Northern Territory) (National Uniform Legislation) (Modification)
Regulations 2016 12
6 Clause 5.1.2 modified
(1) Clause 5.1.2(d), table
omit, insert
Connection Applicant Process
A Registered Participant or a person intending to
become a Registered Participant for a generating
plant connecting to a transmission network or a
person who is covered by an exemption from the
requirement to hold a licence for operating in the
electricity supply industry for a generating plant
connecting to a transmission network
Rule 5.3 applies
A Registered Participant or a person intending to
become a Registered Participant (or a person
pursuant to clause 5.1A.1(c)) for a load
connecting to a transmission network
Rule 5.3 applies
A load connecting to a distribution network where
the Connection Applicant is a Registered
Participant or a person intending to become a
Registered Participant (and is not acting as the
agent of a retail customer)
Rule 5.3 applies
A distribution network connecting to another
distribution network or to a transmission network
where the Connection Applicant is a Registered
Participant, intending to become a Registered
Participant or will obtain an exemption from
registration
Rule 5.3 applies
A Market Network Service Provider or person
intending to register as one seeking connection to
a distribution network or a transmission network
Rule 5.3 applies
An embedded generating unit connecting to a
distribution network where the Connection
Applicant is a Registered Participant or a person
intending to become a Registered Participant
Rules 5.3 and 5.3A apply
(see clause 5.3.1A for the
interaction between the
two rules)
A non-registered embedded generator who
makes an election for rule 5.3A to apply instead
of Chapter 5A or a non-registered embedded
generator above the relevant materiality threshold
Rules 5.3 and 5.3A apply
(see clause 5.3.1A for the
interaction between the
two rules)
-- 18 of 290 --
Schedule 2 Further modifications to operation of National Electricity Rules
National Electricity (Northern Territory) (National Uniform Legislation) (Modification)
Regulations 2016 13
Connection Applicant Process
A Generator wishing to alter a connected
generating plant in the circumstances set out in
clause 5.3.9
Clause 5.3.9 applies
A Connection Applicant for prescribed
transmission services or negotiated transmission
services that do not require the establishment or
modification of a connection or alteration of a
connected generating plant in the circumstances
set out in clause 5.3.9
Rule 5.3 applies as
modified by clause
5.2A.3(c)
An Embedded Generator or Market Network
Service Provider applying for distribution network
user access
Rule 5.3 or 5.3A (as
applicable) and rule
5.3AA apply
A load or generating plant connecting to a
declared shared network
Rule 5.3 as modified by
clause 5.1A.1(d) to (g)
and rule 5.3B apply
A load that is above the relevant materiality
threshold connecting to a distribution network
where the Connection Applicant is not a
Registered Participant and is not intending to
become a Registered Participant (unless it is
acting as the agent of a retail customer)
Rule 5.3 applies
A load that is below the relevant materiality
threshold connecting to a distribution network
where the Connection Applicant is not a
Registered Participant and is not intending to
become a Registered Participant (unless it is
acting as the agent of a retail customer)
A non-registered embedded generator who does
not make an election for Rule 5.3A to apply
instead of Chapter 5A, other than a non-
registered embedded generator above the
relevant materiality threshold
Chapter 5A applies
A retail customer (or a retailer on behalf of that
customer) connecting a micro embedded
generator to a distribution network
Chapter 5A applies
-- 19 of 290 --
Schedule 2 Further modifications to operation of National Electricity Rules
National Electricity (Northern Territory) (National Uniform Legislation) (Modification)
Regulations 2016 14
(2) Clause 5.1.2(f)(1)
omit, insert
(1) the negotiating principles set out in Chapter 6, rather than
schedule 5.11, will apply to negotiations between a
Transmission Network Service Provider and a Connection
Applicant for negotiated transmission services (as if they were
negotiated distribution services);
(3) Clause 5.1.2(f)(3)
omit, insert
(3) disputes between a Transmission Network Service Provider
and a Connection Applicant as to terms and conditions of
access for the provision of prescribed transmission services or
for the provision of negotiated transmission services will be
determined under Chapter 6, rather than rule 5.5 (as if they
were negotiated distribution services).
7 Clause 5.1.3 inserted
After clause 5.1.2
insert
5.1.3 Definitions
In this Chapter:
non-registered embedded generator has the same meaning as
in clause 5A.A.1
relevant materiality threshold means a generation or load
capacity threshold (for a local electricity system or part of a local
electricity system), in MW, specified by a local instrument for the
purposes of this definition.
Note
The requirements of this Chapter 5 relating to the materiality threshold will take
effect in this jurisdiction when a threshold is specified by a local instrument.
-- 20 of 290 --
Schedule 2 Further modifications to operation of National Electricity Rules
National Electricity (Northern Territory) (National Uniform Legislation) (Modification)
Regulations 2016 15
8 Clause 5.1A.2 modified
(1) Clause 5.1A.2(c)
omit, insert
(c) the technical terms and conditions of connection agreements
regarding standards of performance must be established in
accordance with the requirements of jurisdictional electricity
legislation, with the objective of ensuring that the power system
operates securely and reliably and in accordance with any system
standard;
Note
The requirements that will apply under jurisdictional electricity legislation for the
purposes of paragraph (c) will be requirements that correspond to the matters set
out in schedules 5.1, 5.2 and 5.3 in the Rules applying in other participating
jurisdictions. The system standards referred to in paragraph (c) are those that
correspond to the system standards in schedule 5.1a in the Rules applying in
other participating jurisdictions. The application of paragraph (c) will be revisited
as part of the phased implementation of the Rules in this jurisdiction.
(2) Clause 5.1A.2(e)(2)
omit
AEMO
insert
NTESMO
9 Clause 5.1A.3 inserted
After clause 5.1A.2
insert
5.1A.3 Dedicated connection asset service providers
(a) A person must not engage in the activity of owning, controlling or
operating a dedicated connection asset unless the person is a
Transmission Network Service Provider, or a person who holds an
exemption from the requirement to hold a licence under Part 3 of
the Electricity Reform Act 2000 (NT) to own or operate that
dedicated connection asset.
(b) A person who holds an exemption from the requirement to hold a
licence under Part 3 of the Electricity Reform Act 2000 (NT) to own
or operate a large dedicated connection asset must, in relation to
that dedicated connection asset, comply with clause 5.2A(6)(c),
-- 21 of 290 --
Schedule 2 Further modifications to operation of National Electricity Rules
National Electricity (Northern Territory) (National Uniform Legislation) (Modification)
Regulations 2016 16
clause 5.2A.8 and rule 5.5 as if that person were a Dedicated
Connection Asset Service Provider.
(c) A Dedicated Connection Asset Service Provider is:
(1) only required to comply with a rule that is expressed to apply
to a Network Service Provider or a Transmission Network
Service Provider in those capacities where the rule expressly
provides that it applies to a Dedicated Connection Asset
Service Provider; and
(2) required to comply with all rules which are expressed to apply
to a Registered Participant.
(d) A Transmission Network Service Provider is taken to be a
Dedicated Connection Asset Service Provider only in so far as its
activities relate to any of its dedicated connection assets.
10 Clause 5.2.1 modified
Clause 5.2.1(b)(4)
omit
regions or partly combined regions, intra-regional transmission
break-up
insert
network elements, or network break-up,
11 Clause 5.2.2 modified
(1) Clause 5.2.2(a)
omit, insert
(a) If requested to do so by a Transmission Network User, Distribution
Network User, NTESMO or the AER, the Utilities Commission (in
relation to a dedicated connection asset), a Network Service
Provider and a Transmission Network User or Distribution Network
User (as the case may be) must document the terms of any
network connection arrangements made prior to 1 July 2019 and
the resulting document will then be deemed to be a connection
agreement for the purposes of the Rules.
Note
This clause is classified as a civil penalty provision under the National Electricity
(South Australia) Regulations. (See clause 6(1) and Schedule 1 of the National
Electricity (South Australia) Regulations.)
-- 22 of 290 --
Schedule 2 Further modifications to operation of National Electricity Rules
National Electricity (Northern Territory) (National Uniform Legislation) (Modification)
Regulations 2016 17
(2) Clause 5.2.2(b)(1) and (3)
omit
13 December 1998
insert
1 July 2019
12 Clause 5.2.3 modified
(1) After clause 5.2.3, heading
insert
Note
Paragraphs (a) and (k) of this clause have no effect in this jurisdiction (see
regulation 5A of the National Electricity (Northern Territory) (National Uniform
Legislation) (Modification) Regulations 2016). The application of these
paragraphs will be revisited as part of the phased implementation of the Rules in
this jurisdiction.
(2) Clause 5.2.3(b)(1)
omit
schedule 5.1
insert
jurisdictional electricity legislation
(3) Clause 5.2.3(b)
omit
between schedule 5.1
insert
between jurisdictional electricity legislation
(4) Clause 5.2.3(b)(3)
omit
schedule 5.1
insert
the jurisdictional electricity legislation
-- 23 of 290 --
Schedule 2 Further modifications to operation of National Electricity Rules
National Electricity (Northern Territory) (National Uniform Legislation) (Modification)
Regulations 2016 18
(5) After clause 5.2.3(b), note
insert
Note
The requirements that will apply under jurisdictional electricity legislation for the
purposes of paragraph (b) will be requirements that correspond to the matters set
out in schedule 5.1 in the Rules applying in other participating jurisdictions. The
application of paragraph (b) will be revisited as part of the phased implementation
of the Rules in this jurisdiction.
(6) Clause 5.2.3(c)
omit, insert
(c) Where the provisions of the connection agreement vary the
technical requirements set out in jurisdictional electricity legislation,
the relevant Network Service Provider must report on such
variations to NTESMO on an annual basis.
Note
This clause is classified as a civil penalty provision under the National Electricity
(South Australia) Regulations. (See clause 6(1) and Schedule 1 of the National
Electricity (South Australia) Regulations.)
Note
The requirements that will apply under jurisdictional electricity legislation for the
purposes of paragraph (c) will be requirements that correspond to the matters set
out in the schedules to Chapter 5 in the Rules applying in other participating
jurisdictions. The application of paragraph (c) will be revisited as part of the
phased implementation of the Rules in this jurisdiction.
(7) Clause 5.2.3(d)(3)
omit
schedule 5.1
insert
jurisdictional electricity legislation
(8) Clause 5.2.3(d)(9) and (10)
omit (all references)
AEMO
insert
NTESMO
-- 24 of 290 --
Schedule 2 Further modifications to operation of National Electricity Rules
National Electricity (Northern Territory) (National Uniform Legislation) (Modification)
Regulations 2016 19
(9) Clause 5.2.3(d)(11)
omit, insert
(11) provide to NTESMO the information required from Generators
and Customers to support a connection application under
these Rules and jurisdictional electricity legislation; and
(10) After clause 5.2.3(d)(11), note
insert
Note
The requirements that will apply under jurisdictional electricity legislation for the
purposes of paragraph (d)(3) will be requirements that correspond to the matters
set out in schedule 5.1, in the Rules applying in other participating jurisdictions.
The information referred to in paragraph (d)(11) corresponds to the information
required under schedule 5.2 or 5.3 in the Rules applying in other participating
jurisdictions. The application of paragraph (d)(3) and (11) will be revisited as part
of the phased implementation of the Rules in this jurisdiction.
(11) Clause 5.2.3(e)
omit
AEMO
insert
NTESMO
(12) Clause 5.2.3(j)
omit, insert
(j) If in NTESMO's reasonable opinion, there is a risk a Network
Service Provider's plant or equipment will:
(1) adversely affect network capability, power system security,
quality or reliability of supply, inter-regional power transfer
capability; or
(2) adversely affect the use of a network by a Network User,
-- 25 of 290 --
Schedule 2 Further modifications to operation of National Electricity Rules
National Electricity (Northern Territory) (National Uniform Legislation) (Modification)
Regulations 2016 20
NTESMO may request the Network Service Provider to provide
information relating to the protection systems and the control
systems of the equipment, and following such a request, the
Network Service Provider must provide the information to NTESMO
and any other relevant Network Service Provider(s).
Note
This clause is classified as a civil penalty provision under the National Electricity
(South Australia) Regulations. (See clause 6(1) and Schedule 1 of the National
Electricity (South Australia) Regulations.)
Note
The application of paragraph (j) will be revisited as part of the phased
implementation of the Rules in this jurisdiction.
(13) Clause 5.2.3(l)
omit, insert
(l) All information provided to NTESMO and the relevant Network
Service Provider(s) under paragraph (j) must be treated as
confidential information by those recipients.
13 Clause 5.2.4 modified
(1) After clause 5.2.4, heading
insert
Note
Paragraph (d) of this clause has no effect in this jurisdiction (see regulation 5A of
the National Electricity (Northern Territory) (National Uniform Legislation)
(Modification) Regulations 2016). The application of this paragraph will be
revisited as part of the phased implementation of the Rules in this jurisdiction.
(2) Clause 5.2.4(b)(2)
omit
schedule 5.3
insert
any relevant technical requirements in jurisdictional electricity
legislation
-- 26 of 290 --
Schedule 2 Further modifications to operation of National Electricity Rules
National Electricity (Northern Territory) (National Uniform Legislation) (Modification)
Regulations 2016 21
(3) After clause 5.2.4(b)
insert
Note
The requirements that will apply under jurisdictional electricity legislation for the
purposes of paragraph (b)(2) will be requirements that correspond to the matters
set out in schedule 5.3 in the Rules applying in other participating jurisdictions.
The application of paragraph (b)(2) will be revisited as part of the phased
implementation of the Rules in this jurisdiction.
(4) Clause 5.2.4(c)
omit, insert
(c) If in NTESMO's reasonable opinion, there is a risk that a
Customer's plant will:
(1) adversely affect network capability, power system security,
quality or reliability of supply, inter-regional power transfer
capability; or
(2) adversely affect the use of a network by a Network User,
NTESMO may request a Customer to provide information relating
to the protection systems and control systems of the equipment,
and following such a request, the Customer must provide the
information to NTESMO and the relevant Network Service
Provider(s).
Note
This clause is classified as a civil penalty provision under the National Electricity
(South Australia) Regulations. (See clause 6(1) and Schedule 1 of the National
Electricity (South Australia) Regulations.)
Note
The application of paragraph (c) will be revisited as part of the phased
implementation of the Rules in this jurisdiction.
(5) Clause 5.2.4(e)
omit, insert
(e) All information provided to NTESMO and the relevant Network
Service Provider(s) under paragraph (c) must be treated as
confidential information by those recipients.
-- 27 of 290 --
Schedule 2 Further modifications to operation of National Electricity Rules
National Electricity (Northern Territory) (National Uniform Legislation) (Modification)
Regulations 2016 22
14 Clause 5.2.5 modified
(1) After clause 5.2.5, heading
insert
Note
Paragraphs (c) and (e) of this clause have no effect in this jurisdiction (see
regulation 5A of the National Electricity (Northern Territory) (National Uniform
Legislation) (Modification) Regulations 2016). The application of these
paragraphs will be revisited as part of the phased implementation of the Rules in
this jurisdiction.
(2) Clause 5.2.5(b)(2)
omit
Schedule 5.2
insert
any relevant technical requirements in jurisdictional electricity
legislation
(3) After clause 5.2.5(b)
insert
Note
The requirements that will apply under jurisdictional electricity legislation for the
purposes of paragraph (b)(2) will be requirements that correspond to the matters
set out in schedule 5.3 in the Rules applying in other participating jurisdictions.
The application of paragraph (b)(2) will be revisited as part of the phased
implementation of the Rules in this jurisdiction.
(4) Clause 5.2.5(d)
omit, insert
(d) If in NTESMO's reasonable opinion, there is a risk that a
Generator's plant will:
(1) adversely affect network capability, power system security,
quality or reliability of supply, inter-regional power transfer
capability; or
(2) adversely affect the use of a network by a Network User
-- 28 of 290 --
Schedule 2 Further modifications to operation of National Electricity Rules
National Electricity (Northern Territory) (National Uniform Legislation) (Modification)
Regulations 2016 23
NTESMO may request a Generator to provide information relating
to the protection systems and the control systems of the equipment,
and following such a request, the Generator must provide the
information to NTESMO and the relevant Network Service
Provider(s).
Note
This clause is classified as a civil penalty provision under the National Electricity
(South Australia) Regulations. (See clause 6(1) and Schedule 1 of the National
Electricity (South Australia) Regulations.)
Note
The application of paragraph (d) will be revisited as part of the phased
implementation of the Rules in this jurisdiction.
(5) Clause 5.2.5(f)
omit, insert
(f) All information provided to NTESMO and the relevant Network
Service Provider(s) under paragraph (d) must be treated as
confidential information by those recipients.
15 Clause 5.2.7 modified
(1) Clause 5.2.7(a)
omit
Chapter 2
insert
jurisdictional electricity legislation
(2) After clause 5.2.7(a)
insert
Note
The jurisdiction electricity legislation that is relevant to the classification of a
dedicated connection asset is the Electricity Reform Act 2000 (NT) and the
National Electricity (Northern Territory) (National Uniform Legislation) Act 2015.
16 Clause 5.2A.2 modified
(1) Clause 5.2A.2(a)
omit
registered
-- 29 of 290 --
Schedule 2 Further modifications to operation of National Electricity Rules
National Electricity (Northern Territory) (National Uniform Legislation) (Modification)
Regulations 2016 24
insert
responsible
(2) Clause 5.2A.2(a), table heading
omit
Registered
insert
Responsible
(3) Clause 5.2A.2(b)
omit, insert
(b) The intention of this rule 5.2A is that there is a responsible person
for each asset connecting the transmission network to the facilities
of the Transmission Network User.
17 Clause 5.2A.3 modified
(1) Clause 5.2A.3(a), table
omit (all references)
Chapter 6A
insert
Chapter 6
(2) Clause 5.2A.3(a), table, second row, after "Chapter 5"
insert
and economic regulation under Chapter 6
(3) Clause 5.2A.3(c)
omit
rules 5.3, 5.4 and 5.5 will apply with such modifications as is
appropriate to the nature of the service requested
insert
rules 5.3 and 5.4 will apply with such modifications as is appropriate
to the nature of the service requested, together with (if required) the
-- 30 of 290 --
Schedule 2 Further modifications to operation of National Electricity Rules
National Electricity (Northern Territory) (National Uniform Legislation) (Modification)
Regulations 2016 25
provisions of Chapter 6 in relation to any dispute as to terms and
conditions of access (as if the prescribed transmission service or
the negotiated transmission service were a negotiated distribution
service)
18 Clause 5.2A.6 modified
Clause 5.2A.6(a)
omit
the negotiating principles
insert
Chapter 6
19 Clause 5.2A.8 modified
(1) Clause 5.2A.8(d)
omit
Chapter 2
insert
in accordance with jurisdictional electricity legislation
(2) After clause 5.2A.8(d), note
insert
Note
The jurisdiction electricity legislation that is relevant to the classification of a
dedicated connection asset is the Electricity Reform Act 2000 (NT) and the
National Electricity (Northern Territory) (National Uniform Legislation) Act 2015.
20 Clause 5.3.1 modified
(1) Clause 5.3.1(b)
omit, insert
(b) The following persons wishing to establish a connection to a
network must follow the procedures in this rule 5.3:
(1) a Registered Participant;
(2) a person intending to become a Registered Participant;
-- 31 of 290 --
Schedule 2 Further modifications to operation of National Electricity Rules
National Electricity (Northern Territory) (National Uniform Legislation) (Modification)
Regulations 2016 26
(3) a person who is covered by an exemption from the
requirement to hold a licence for operating in the electricity
supply industry for a generating plant connecting to a
transmission network or a load connecting to a transmission
network;
(4) a person seeking to establish a connection to a distribution
network for a load above the relevant materiality threshold.
(2) Clause 5.3.1(d)
omit
AEMO
insert
NTESMO
21 Clause 5.3.1A modified
(1) Clause 5.3.1A(a)
omit
(2) Clause 5.3.1A(c)(2)
omit, insert
(2) person who is required to apply to the Utilities Commission for
an exemption from the requirement to hold a licence for
operating in the electricity supply industry as a Generator in
respect of an embedded generating unit;
(3) Clause 5.3.1A(c)(3)
omit
(c).
insert
(c); or
(4) After clause 5.3.1A(3)
insert
(4) non-registered embedded generator above the relevant
materiality threshold for the relevant local electricity system, or
part of a local electricity system,
-- 32 of 290 --
Schedule 2 Further modifications to operation of National Electricity Rules
National Electricity (Northern Territory) (National Uniform Legislation) (Modification)
Regulations 2016 27
22 Clause 5.3.2 modified
(1) Clause 5.3.2(f)
omit
schedule 5.1, 5.2, 5.3 or 5.3a
insert
jurisdictional electricity legislation
(2) After clause 5.3.2(f), note
insert
Note
The requirements that will apply under jurisdictional electricity legislation for the
purposes of paragraph (f) will be requirements that correspond to the matters set
out in schedules 5.1, 5.2, and 5.3 in the Rules applying in other participating
jurisdictions. The application of paragraph (f) will be revisited as part of the
phased implementation of the Rules in this jurisdiction.
23 Clause 5.3.3 modified
(1) After clause 5.3.3, heading
insert
Note
Paragraphs (b2), (b3) and (b4) of this clause have no effect in this jurisdiction
(see regulation 5A of the National Electricity (Northern Territory) (National
Uniform Legislation) (Modification) Regulations 2016). The application of these
paragraphs will be revisited as part of the phased implementation of the Rules in
this jurisdiction.
(2) Clause 5.3.3(b1)(3), (4), (5) and (6)
omit, insert
(3) the access arrangements specified in the jurisdictional
electricity legislation; and
(3) Clause 5.3.3(b5)
omit, insert
(b5) For a connection point for a proposed new connection of a
generating system or market network service facility, within the time
applicable under paragraph (b1), the Network Service Provider
must provide the Connection Applicant with written details of the
minimum three phase fault level at the connection point.
-- 33 of 290 --
Schedule 2 Further modifications to operation of National Electricity Rules
National Electricity (Northern Territory) (National Uniform Legislation) (Modification)
Regulations 2016 28
(4) Clause 5.3.3(c)(3)
omit
schedule 5.5
insert
jurisdictional electricity legislation
(5) Clause 5.3.3(c)(4)
omit
rules 6.21 and 6A.28
insert
rule 6.21
(6) Clause 5.3.3(c)(5)(i)
omit
AEMO and
(7) After clause 5.3.3(c), note
insert
Note
The type of information that will apply under jurisdictional electricity legislation for
the purposes of paragraph (c)(3) will correspond to the type of information set out
in schedule 5.5 in the Rules applying in other participating jurisdictions. The
application of paragraph (c)(3) will be revisited as part of the phased
implementation of the Rules in this jurisdiction.
24 Clause 5.3.4 modified
(1) After clause 5.3.4, heading
insert
Note
Paragraphs (e) and (g) of this clause have no effect in this jurisdiction (see
regulation 5A of the National Electricity (Northern Territory) (National Uniform
Legislation) (Modification) Regulations 2016). The application of these
paragraphs will be revisited as part of the phased implementation of the Rules in
this jurisdiction.
-- 34 of 290 --
Schedule 2 Further modifications to operation of National Electricity Rules
National Electricity (Northern Territory) (National Uniform Legislation) (Modification)
Regulations 2016 29
(2) Clause 5.3.4(b1)(d)
omit (all references)
or AEMO
25 Clause 5.3.4A modified
After clause 5.3.4A, heading
insert
Note
Clause 5.3.4A has no effect in this jurisdiction (see regulation 5A of the National
Electricity (Northern Territory) (National Uniform Legislation) (Modification)
Regulations 2016). The application of this clause will be revisited as part of the
phased implementation of the Rules in this jurisdiction.
25A Clause 5.3.4B modified
After clause 5.3.4B, heading
insert
Note
Clause 5.3.4B has no effect in this jurisdiction (see regulation 5A of the National
Electricity (Northern Territory) (National Uniform Legislation) (Modification)
Regulations 2016). The application of this clause will be revisited as part of the
phased implementation of the Rules in this jurisdiction.
25B Clause 5.3.5 modified
(1) After clause 5.3.5, heading
insert
Note
Paragraph (e) of this clause has no effect in this jurisdiction (see regulation 5A of
the National Electricity (Northern Territory) (National Uniform Legislation)
(Modification) Regulations 2016). The application of this paragraph will be
revisited as part of the phased implementation of the Rules in this jurisdiction.
(2) Clause 5.3.5(a)
omit, insert
(a) The Network Service Provider to whom the application to connect is
submitted must proceed to prepare an offer to connect in response
in accordance with technical standards set out in jurisdictional
electricity legislation.
-- 35 of 290 --
Schedule 2 Further modifications to operation of National Electricity Rules
National Electricity (Northern Territory) (National Uniform Legislation) (Modification)
Regulations 2016 30
(3) Clause 5.3.5(d) and (g)
omit (all references)
AEMO
insert
NTESMO
25C Clause 5.3.6 modified
(1) After clause 5.3.6, heading
insert
Note
Paragraph (a2)(3) of this clause has no effect in this jurisdiction (see
regulation 5A of the National Electricity (Northern Territory) (National Uniform
Legislation) (Modification) Regulations 2016). The application of paragraphs (a1)
and (a2)(3) will be revisited as part of the phased implementation of the Rules in
this jurisdiction.
(2) Clause 5.3.6(a1)
omit, insert
(a1) The Network Service Provider may amend the time period referred
to in paragraph (a)(1) to allow for any additional time taken in
excess of the period allowed in the preliminary program for the
negotiation of access standards, where allowed under jurisdictional
electricity legislation.
(3) Clause 5.3.6(b)(1)
omit, insert
(1) each technical requirement identified by the Network Service
Provider under clause 5.3.3(b1); and
(4) Clause 5.3.6(b1)
omit
the applicable minimum access standards
insert
allowed under jurisdictional electricity legislation
-- 36 of 290 --
Schedule 2 Further modifications to operation of National Electricity Rules
National Electricity (Northern Territory) (National Uniform Legislation) (Modification)
Regulations 2016 31
(5) Clause 5.3.6(b2)(3)
omit
the automatic access standard or the negotiated access standard
as determined in accordance with clause 5.3.4A
insert
the access standards determined in accordance with jurisdictional
electricity legislation
(6) Clause 5.3.6(c)
omit, insert
(c) The offer to connect must be fair and reasonable and must be
consistent with the safe and reliable operation of the power system
in accordance with the Rules and any relevant jurisdictional
electricity legislation. Without limitation, unless the parties otherwise
agree, to be fair and reasonable an offer to connect must offer
connection and network services consistent with any relevant
jurisdictional electricity legislation and must not impose conditions
on the Connection Applicant which are more onerous than those
contemplated in relevant jurisdictional electricity legislation.
Note
This clause is classified as a civil penalty provision under the National Electricity
(South Australia) Regulations. (See clause 6(1) and Schedule 1 of the National
Electricity (South Australia) Regulations.)
Note
The requirements that will apply under jurisdictional electricity legislation for the
purposes of paragraph (c) will be requirements that correspond to the matters set
out in schedules 5.1, 5.2 and 5.3 in the Rules applying in other participating
jurisdictions. The application of paragraph (c) will be revisited as part of the
phased implementation of the Rules in this jurisdiction.
(7) Clause 5.3.6(g)
omit, insert
(g) An offer to connect must define the basis for determining the
transmission service charges in accordance with Chapter 6,
including the prudential requirements set out in that Chapter, as if
the transmission service charges were distribution service charges.
-- 37 of 290 --
Schedule 2 Further modifications to operation of National Electricity Rules
National Electricity (Northern Territory) (National Uniform Legislation) (Modification)
Regulations 2016 32
25D Clause 5.3.7 modified
(1) After clause 5.3.7, heading
insert
Note
Paragraphs (c) and (g)(2)(i), (5) and (6) of this clause have no effect in this
jurisdiction (see regulation 5A of the National Electricity (Northern Territory)
(National Uniform Legislation) (Modification) Regulations 2016). The application
of these paragraphs will be revisited as part of the phased implementation of the
Rules in this jurisdiction.
(2) Clause 5.3.7(b)
omit
schedules 5.2, 5.3 and 5.3a
insert
accordance with jurisdictional electricity legislation
(3) After clause 5.3.7(b)
insert
Note
The requirements that will apply under jurisdictional electricity legislation for the
purposes of paragraph (b) will be requirements that correspond to the matters set
out in schedules 5.2 and 5.3 in the Rules applying in other participating
jurisdictions. The application of paragraph (b) will be revisited as part of the
phased implementation of the Rules in this jurisdiction.
(4) Clause 5.3.7(d)
omit
or any system strength connection works
(5) Clause 5.3.7(g) and (h)
omit (all references)
AEMO
insert
NTESMO
-- 38 of 290 --
Schedule 2 Further modifications to operation of National Electricity Rules
National Electricity (Northern Territory) (National Uniform Legislation) (Modification)
Regulations 2016 33
(6) Clause 5.3.7(h)
omit
schedule 7.4
insert
schedule 7A.4
25E Clause 5.3.8 modified
(1) After clause 5.3.8, heading
insert
Note
Paragraph (b)(1) and (2)(iv) of this clause has no effect in this jurisdiction (see
regulation 5A of the National Electricity (Northern Territory) (National Uniform
Legislation) (Modification) Regulations 2016). The application of these provisions
will be revisited as part of the phased implementation of the Rules in this
jurisdiction.
(2) Clause 5.3.8(b) and (f)
omit (all references)
AEMO
insert
NTESMO
(3) Clause 5.3.8(b)(2)(iii)
omit
or system strength connection works
25F Clause 5.3.9 modified
(1) After clause 5.3.9, heading
insert
Note
Paragraphs (a)(2), (b)(4), (c), (c1) and (f) of this clause have no effect in this
jurisdiction (see regulation 5A of the National Electricity (Northern Territory)
(National Uniform Legislation) (Modification) Regulations 2016). The application
of these paragraphs will be revisited as part of the phased implementation of the
Rules in this jurisdiction.
-- 39 of 290 --
Schedule 2 Further modifications to operation of National Electricity Rules
National Electricity (Northern Territory) (National Uniform Legislation) (Modification)
Regulations 2016 34
(2) Clause 5.3.9(a)
omit, insert
(a) This clause 5.3.9 applies where a Generator proposes to alter a
connected generating system or a generating system where that
alteration would affect performance standards in an existing
connection agreement and that alteration:
(1) will affect the performance of the generating system relative to
any of the technical requirements set out in jurisdictional
electricity legislation within the constraints allowed under
jurisdictional electricity legislation; or
(2) will, in AEMO's reasonable opinion, have an adverse system
strength impact; or
(3) will, in NTESMO's reasonable opinion, adversely affect
network capability, power system security, quality or reliability
of supply, inter-regional power transfer capability or the use of
a network by another Network User.
Note
The requirements that will apply under jurisdictional electricity legislation for the
purposes of paragraph (a)(1) will be requirements that correspond to the matters
set out in clauses S5.2.5 to 5.2.8 in the Rules applying in other participating
jurisdictions. The application of paragraph (a)(1) will be revisited as part of the
phased implementation of the Rules in this jurisdiction.
(3) Clause 5.3.9(b)
omit
AEMO
insert
NTESMO
(4) Clause 5.3.9(b)(2)
omit
in accordance with the Power System Model Guidelines, Power
System Design Data Sheet and Power Setting Data Sheet
-- 40 of 290 --
Schedule 2 Further modifications to operation of National Electricity Rules
National Electricity (Northern Territory) (National Uniform Legislation) (Modification)
Regulations 2016 35
(5) Clause 5.3.9(d)
omit, insert
(d) Without limiting paragraph (a), a proposed alteration to the following
equipment is deemed to affect the performance of the generating
system relative to technical requirements, thereby necessitating a
submission under subparagraph (b)(3), unless NTESMO and the
Network Service Provider otherwise agree:
(1) machinery windings;
(2) power converter;
(3) reactive compensation plant;
(4) excitation control system;
(5) voltage control system;
(6) governor control system;
(7) power control system;
(8) protection system;
(9) auxiliary supplies;
(10) remote control and monitoring system.
(6) Clause 5.3.9(e)
omit
other Network Service Providers and AEMO
insert
and other Network Service Providers
(7) Clause 5.3.9(g) and (h)
omit (all references)
AEMO
insert
NTESMO
-- 41 of 290 --
Schedule 2 Further modifications to operation of National Electricity Rules
National Electricity (Northern Territory) (National Uniform Legislation) (Modification)
Regulations 2016 36
25G Clause 5.3.10 modified
(1) After clause 5.3.10, heading
insert
Note
Paragraphs (b)(3) and (c) of this clause have no effect in this jurisdiction (see
regulation 5A of the National Electricity (Northern Territory) (National Uniform
Legislation) (Modification) Regulations 2016). The application of these
paragraphs will be revisited as part of the phased implementation of the Rules in
this jurisdiction.
(2) Clause 5.3.10(a) and (b)
omit, insert
(a) A person to whom clause 5.3.9 applies must not commission
altered generating plant until the Network Service Provider has
advised the Generator that it is satisfied in accordance with
paragraph (b).
Note
This clause is classified as a civil penalty provision under the National Electricity
(South Australia) Regulations. (See clause 6(1) and Schedule 1 of the National
Electricity (South Australia) Regulations.)
(b) In relation to altered generating plant, the Network Service Provider
must be satisfied that:
(1) the relevant person has complied with clause 5.3.9;
(2) each amended performance standard that has been submitted
to the Network Service Provider meets the relevant technical
requirements under jurisdictional electricity legislation; and
(3) any system strength remediation scheme satisfies
clause 5.3.4B.
(3) Clause 5.3.10(c)
omit
AEMO
insert
NTESMO
-- 42 of 290 --
Schedule 2 Further modifications to operation of National Electricity Rules
National Electricity (Northern Territory) (National Uniform Legislation) (Modification)
Regulations 2016 37
25H Clause 5.3.11 modified
(1) Clause 5.3.11(a) and (b)
omit (all references)
AEMO
insert
NTESMO
(2) After clause 5.3.11(a)
insert
(a1) A request from a Network Service Provider to change normal
voltage must be assessed in accordance with the Rules
consultation procedures.
(3) After clause 5.3.11(b)
insert
Note
NTESMO's reasonable costs in assessing requests under this clause will be
revisited as part of the phased implementation of the Rules in this jurisdiction.
25I Clause 5.3A.1 modified
(1) Clause 5.3A.1(c)(1)(ii)
omit, insert
(ii) person who is required to apply to the Utilities
Commission for an exemption from the requirement to
hold a licence for operating in the electricity industry as a
Generator in respect of an embedded generating unit;
(2) Clause 5.3A.1(c)(1)(iii)
omit
clause 5A.A.2(c),
insert
clause 5A.A.2(c); or
-- 43 of 290 --
Schedule 2 Further modifications to operation of National Electricity Rules
National Electricity (Northern Territory) (National Uniform Legislation) (Modification)
Regulations 2016 38
(3) After clause 5.3A.1(c)(1)(iii)
insert
(iv) non-registered embedded generator above the relevant
materiality threshold for the local electricity system (or
part of the local electricity system),
25J Clause 5.3A.3 modified
(1) After clause 5.3A.3, heading
insert
Note
Paragraph (b)(5) and (6)(xi) of this clause has no effect in this jurisdiction (see
regulation 5A of the National Electricity (Northern Territory) (National Uniform
Legislation) (Modification) Regulations 2016). The application of these provisions
will be revisited as part of the phased implementation of the Rules in this
jurisdiction.
(2) Clause 5.3A.3(b)(1)(vi)
omit, insert
(vi) the process for negotiating any access standards, where
allowed under jurisdictional electricity legislation and a
summary of the factors the Distribution Network Service
Provider takes into account when considering proposed
changes to access standards; and
(3) Clause 5.3A.3(b)(6)(x)
omit
requirements; and
insert
requirements;
(4) After clause 5.3A.3(b)(6)(xi)
insert
(xii) other technical matters relevant to any access standard
under jurisdictional electricity legislation; and
-- 44 of 290 --
Schedule 2 Further modifications to operation of National Electricity Rules
National Electricity (Northern Territory) (National Uniform Legislation) (Modification)
Regulations 2016 39
25K Clause 5.3A.4 modified
After clause 5.3A.4, heading
insert
Note
Paragraph (e)(2)(ii) of this clause has no effect in this jurisdiction (see
regulation 5A of the National Electricity (Northern Territory) (National Uniform
Legislation) (Modification) Regulations 2016). The application of this paragraph
will be revisited as part of the phased implementation of the Rules in this
jurisdiction.
25L Clause 5.3A.8 modified
After clause 5.3A.8, heading
insert
Note
Paragraph (h) of this clause has no effect in this jurisdiction (see regulation 5A of
the National Electricity (Northern Territory) (National Uniform Legislation)
(Modification) Regulations 2016). The application of this paragraph will be
revisited as part of the phased implementation of the Rules in this jurisdiction.
25M Clause 5.3A.9 modified
(1) After clause 5.3A.9, heading
insert
Note
Paragraphs (e), (f) and (h) of this clause have no effect in this jurisdiction (see
regulation 5A of the National Electricity (Northern Territory) (National Uniform
Legislation) (Modification) Regulations 2016). The application of these
paragraphs will be revisited as part of the phased implementation of the Rules in
this jurisdiction.
(2) Clause 5.3A.9(a)
omit
clause 5.3.4A and clause 5.3.4B
insert
and clause 5.3.4A
-- 45 of 290 --
Schedule 2 Further modifications to operation of National Electricity Rules
National Electricity (Northern Territory) (National Uniform Legislation) (Modification)
Regulations 2016 40
25N Clause 5.3A.10 modified
(1) After clause 5.3A.10, heading
insert
Note
Paragraph (f) of this clause has no effect in this jurisdiction (see regulation 5A of
the National Electricity (Northern Territory) (National Uniform Legislation)
(Modification) Regulations 2016). The application of this paragraph will be
revisited as part of the phased implementation of the Rules in this jurisdiction.
(2) Clause 5.3A.10(a)
omit, insert
(a) The Distribution Network Service Provider to whom the application
to connect is submitted under clause 5.3A.9(a) in accordance with
the technical requirements set out under jurisdictional electricity
legislation must proceed to prepare an offer to connect in response.
(3) Clause 5.3A.10(b) and (e)
omit (all references)
AEMO
insert
NTESMO
25O Clause 5.3A.12 modified
After clause 5.3A.12, heading
insert
Note
This clause 5.3A.12 has no effect in this jurisdiction (see regulation 5A of the
National Electricity (Northern Territory) (National Uniform Legislation)
(Modification) Regulations 2016). The application of this clause will be revisited
as part of the phased implementation of the Rules in this jurisdiction.
-- 46 of 290 --
Schedule 2 Further modifications to operation of National Electricity Rules
National Electricity (Northern Territory) (National Uniform Legislation) (Modification)
Regulations 2016 41
25P Rule 5.3AA modified
(1) After rule 5.3AA, heading
insert
Note
Paragraphs (h), (i) and, (j) of this rule have no effect in this jurisdiction (see
regulation 5A of the National Electricity (Northern Territory) (National Uniform
Legislation) (Modification) Regulations 2016). The application of these
paragraphs will be revisited as part of the phased implementation of the Rules in
this jurisdiction.
(2) Rule 5.3AA(f)(4)(ii)(B)
omit
during a trading interval
25Q Clause 5.4.3 modified
After clause 5.4.3, heading
insert
Note
Paragraph (c) of this clause has no effect in this jurisdiction (see regulation 5A of
the National Electricity (Northern Territory) (National Uniform Legislation)
(Modification) Regulations 2016). The application of this paragraph will be
revisited as part of the phased implementation of the Rules in this jurisdiction.
25R Clause 5.4.5 modified
After clause 5.4.5, heading
insert
Note
Paragraph (e)(4) of this clause has no effect in this jurisdiction (see regulation 5A
of the National Electricity (Northern Territory) (National Uniform Legislation)
(Modification) Regulations 2016). The application of this paragraph will be
revisited as part of the phased implementation of the Rules in this jurisdiction.
25S Clause 5.5.1 modified
Clause 5.5.1(c)
omit, insert
(b1) Despite paragraph (b), for this jurisdiction, this rule 5.5 only applies
to any dispute which may arise between a Dedicated Connection
Asset Service Provider for a large dedicated connection asset (a
-- 47 of 290 --
Schedule 2 Further modifications to operation of National Electricity Rules
National Electricity (Northern Territory) (National Uniform Legislation) (Modification)
Regulations 2016 42
provider) and a person seeking large DCA services (an applicant)
as to terms and conditions of access, for the provision of large DCA
services (a large DCA services access dispute).
(c) For the purposes of large DCA services, the terms and conditions
of access are the price of, and the other terms and conditions for,
the provision of those large DCA services, as determined under the
access policy.
25T Clause 5.6.1 modified
(1) Clause 5.6.1(a)
omit
Tasmania; and
insert
Tasmania and the Northern Territory;
(2) Clause 5.6.1(b)
omit
Tasmania.
insert
Tasmania; and
(3) After clause 5.6.1(b)
insert
(c) 1 July 2019 in the case of installations located in the Northern
Territory.
25U Clause 5.6.2 modified
Clause 5.6.2(a)(1)
omit
AEMO
insert
NTESMO
-- 48 of 290 --
Schedule 2 Further modifications to operation of National Electricity Rules
National Electricity (Northern Territory) (National Uniform Legislation) (Modification)
Regulations 2016 43
25V Clause 5.7.1 modified
(1) Clause 5.7.1(d)
omit, insert
(d) Neither a Registered Participant nor NTESMO may carry out an
inspection under this rule 5.7 within 6 months of any previous
inspection except for the purpose of verifying the performance of
corrective action claimed to have been carried out in respect of a
non-conformance observed and documented on the previous
inspection or (in the case of NTESMO) for the purpose of reviewing
an operating incident in accordance with any requirements under
jurisdictional electricity legislation.
Note
The requirements that will apply under jurisdictional electricity legislation for the
purposes of paragraph (d) will be requirements that correspond to the matters set
out in clause 4.8.15 in the Rules applying in other participating jurisdictions. The
application of paragraph (d) will be revisited as part of the phased implementation
of the Rules in this jurisdiction.
(2) Clause 5.7.1(h)
omit, insert
(h) NTESMO or any of its representatives may, in accordance with this
rule 5.7, inspect a facility of a Registered Participant and the
operation and maintenance of that facility in order to:
(1) assess compliance by the relevant Registered Participant with
its operational obligations under jurisdictional electricity
legislation;
(2) investigate any possible past or potential threat to power
system security; or
(3) conduct any periodic familiarisation or training associated with
the operational requirements of the facility.
Note
The operational obligations that will apply under jurisdictional electricity
legislation for the purposes of paragraph (h)(1) will be operational obligations that
correspond to those in Chapters 3 and 4 of the Rules applying in other
participating jurisdictions. The application of paragraph (h)(1) be revisited as part
of the phased implementation of the Rules in this jurisdiction.
-- 49 of 290 --
Schedule 2 Further modifications to operation of National Electricity Rules
National Electricity (Northern Territory) (National Uniform Legislation) (Modification)
Regulations 2016 44
(3) Clause 5.7.1(l)
omit (all references)
AEMO
insert
NTESMO
25W Clause 5.7.2 modified
(1) Clause 5.7.2(b) and (i)
omit (all references)
AEMO
insert
NTESMO
(2) Clause 5.7.2(g)
omit
A Transmission Provider must give AEMO
insert
A Network Service Provider must give NTESMO
25X Clause 5.7.3 modified
(1) After clause 5.7.3, heading
insert
Note
The application of paragraphs (a)(1), (c), (d) and (f)(1) of this clause will be
revisited as part of the phased implementation of the Rules in this jurisdiction.
-- 50 of 290 --
Schedule 2 Further modifications to operation of National Electricity Rules
National Electricity (Northern Territory) (National Uniform Legislation) (Modification)
Regulations 2016 45
(2) Clause 5.7.3(a)
omit, insert
(a) Each Generator must, in accordance with the time frames specified
by NTESMO, provide evidence to any relevant Network Service
Provider with which that Generator has a connection agreement
and to NTESMO, that its generating system complies with:
(1) the applicable technical requirements under jurisdictional
electricity legislation; and
(2) the relevant connection agreement including the performance
standards.
Note
This clause is classified as a civil penalty provision under the National Electricity
(South Australia) Regulations. (See clause 6(1) and Schedule 1 of the National
Electricity (South Australia) Regulations.)
Note
The requirements that will apply under jurisdictional electricity legislation for the
purposes of paragraph (a)(1) will be requirements that correspond to the matters
set out in clause S5.2.5 as applying in other participating jurisdictions.
(3) Clause 5.7.3(c)
omit
of clause S5.2.5
insert
under jurisdictional electricity legislation
(4) Clause 5.7.3(c)(1) and (2)
omit (all references)
AEMO
insert
NTESMO
-- 51 of 290 --
Schedule 2 Further modifications to operation of National Electricity Rules
National Electricity (Northern Territory) (National Uniform Legislation) (Modification)
Regulations 2016 46
(5) After clause 5.7.3(c), note
insert
Note
The requirements that will apply under jurisdictional electricity legislation for the
purposes of paragraph (c) will be requirements that correspond to the matters set
out in clause S5.2.5 as applying in other participating jurisdictions.
(6) Clause 5.7.3(d), (e) and (g)
omit (all references)
AEMO
insert
NTESMO
(7) Clause 5.7.3(d)
omit
of clause S5.2.5
insert
under jurisdictional electricity legislation
(8) After clause 5.7.3(d), note
insert
Note
The requirements that will apply under jurisdictional electricity legislation for the
purposes of paragraph (d) will be requirements that correspond to the matters set
out in clause S5.2.5 as applying in other participating jurisdictions.
(9) Clause 5.7.3(f)
omit, insert
(f) If NTESMO:
(1) is satisfied that a generating system is not complying with the
relevant performance standards for that system in respect of
one or more of the technical requirements set out in
jurisdictional electricity legislation and the relevant connection
agreement; and
-- 52 of 290 --
Schedule 2 Further modifications to operation of National Electricity Rules
National Electricity (Northern Territory) (National Uniform Legislation) (Modification)
Regulations 2016 47
(2) holds the reasonable opinion that the performance of the
generating system is or will impede NTESMO's ability to carry
out its role in relation to power system security,
NTESMO may direct the relevant Generator to operate the
generating system at a particular generated output or in a particular
mode until the relevant Generator submits evidence reasonably
satisfactory to NTESMO that the generating system is complying
with the relevant performance standard.
Note
The requirements that will apply under jurisdictional electricity legislation for the
purposes of paragraph (f)(1) will be requirements that correspond to the matters
set out in clause S5.2.4, S5.2.5, S5.2.6, S5.2.7 or S5.2.8 as applying in other
participating jurisdictions.
25Y Clause 5.7.3A modified
After clause 5.7.3A, heading
insert
Note
This clause has no effect in this jurisdiction (see regulation 5A of the National
Electricity (Northern Territory) (National Uniform Legislation) (Modification)
Regulations 2016). The application of this clause will be revisited as part of the
phased implementation of the Rules in this jurisdiction.
25Z Clause 5.7.4 modified
(1) After clause 5.7.4, heading
insert
Note
The application of paragraphs (a1) and (a2)(3) of this clause will be revisited as
part of the phased implementation of the Rules in this jurisdiction.
(2) Clause 5.7.4(a1)
omit
their performance requirements under schedule 5.1
insert
any performance requirements under jurisdictional electricity
legislation
-- 53 of 290 --
Schedule 2 Further modifications to operation of National Electricity Rules
National Electricity (Northern Territory) (National Uniform Legislation) (Modification)
Regulations 2016 48
(3) After clause 5.7.4(a1), note
insert
Note
The requirements that will apply under jurisdictional electricity legislation for the
purposes of paragraph (a1) will be requirements that correspond to the matters
set out in Schedule 5.1 as applying in other participating jurisdictions.
(4) Clause 5.7.4(a2)(3)
omit
of schedule 5.3
insert
under jurisdictional electricity legislation
(5) After clause 5.7.4(a2)
insert
Note
The requirements that will apply under jurisdictional electricity legislation for the
purposes of paragraph (a2)(3) will be requirements that correspond to the
matters set out in Schedule 5.1 as applying in other participating jurisdictions.
(6) Clause 5.7.4(a3)
omit
AEMO
insert
NTESMO
25ZA Clause 5.7.5 modified
(1) After clause 5.7.5, heading
insert
Note
Paragraph (a)(2) of this clause has no effect in this jurisdiction (see regulation 5A
of the National Electricity (Northern Territory) (National Uniform Legislation)
(Modification) Regulations 2016). The application of this paragraph will be
revisited as part of the phased implementation of the Rules in this jurisdiction.
-- 54 of 290 --
Schedule 2 Further modifications to operation of National Electricity Rules
National Electricity (Northern Territory) (National Uniform Legislation) (Modification)
Regulations 2016 49
(2) Clause 5.7.5(d) and (e)
omit (all references)
AEMO's
insert
NTESMO's
(3) Clause 5.7.5(e), (f), (g), (h) and (i)
omit (all references)
AEMO
insert
NTESMO
25ZB Clause 5.7.6 modified
(1) After clause 5.7.6, heading
insert
Note
The application of this clause will be revisited as part of the phased
implementation of the Rules in this jurisdiction.
(2) Clause 5.7.6(a)
omit
to determine analytic parameters for modelling purposes or
(3) Clause 5.7.6(b)
omit, insert
(b) If NTESMO reasonably considers that available information,
including results from a previous test of a generating unit or
generating system, are inadequate, NTESMO may direct a Network
Service Provider to require a Generator to conduct a test under
paragraph (a), and NTESMO may witness such a test.
(4) Clause 5.7.6(d), after "that are due to take place,"
insert
as instructed or approved by NTESMO,
-- 55 of 290 --
Schedule 2 Further modifications to operation of National Electricity Rules
National Electricity (Northern Territory) (National Uniform Legislation) (Modification)
Regulations 2016 50
(5) Clause 5.7.6(f1)
omit
, including model source code provided to AEMO under
clause S5.2.4(b)(6)
(6) Clause 5.7.6(h)
omit, insert
(h) A Generator must provide the test records obtained from a test
under paragraph (a) to the Network Service Provider.
(7) Clause 5.7.6(i)
omit
omit
AEMO
insert
NTESMO
25ZC Clause 5.8.2 modified
Clause 5.8.2
omit
AEMO
insert
NTESMO
25ZD Clause 5.8.3 modified
(1) After clause 5.8.3, heading
insert
Note
The application of this clause will be revisited as part of the phased
implementation of the Rules in this jurisdiction.
-- 56 of 290 --
Schedule 2 Further modifications to operation of National Electricity Rules
National Electricity (Northern Territory) (National Uniform Legislation) (Modification)
Regulations 2016 51
(2) Clause 5.8.3(b)(1) and (2) and (d)
omit (all references)
AEMO
insert
NTESMO
25ZE Clause 5.8.4 modified
Clause 5.8.4(a), (c), (d) and (e)
omit (all references)
AEMO
insert
NTESMO
25ZF Clause 5.8.5 modified
Clause 5.8.5(a) and (e)
omit (all references)
AEMO
insert
NTESMO
25ZG Clause 5.9.2 modified
Clause 5.9.2(b)
omit
AEMO
insert
NTESMO
-- 57 of 290 --
Schedule 2 Further modifications to operation of National Electricity Rules
National Electricity (Northern Territory) (National Uniform Legislation) (Modification)
Regulations 2016 52
25ZH Clause 5.9.3 modified
(1) Clause 5.9.3(a) and (c)
omit (all references)
AEMO
insert
NTESMO
(2) Clause 5.9.3(b)
omit, insert
(b) In all cases of disconnection by a Network Service Provider at
NTESMO's direction during an emergency in accordance with
clause 5.9.5, NTESMO must undertake a review under any relevant
jurisdictional electricity legislation and NTESMO must then provide
a report to the Registered Participant, the AEMC and the AER
advising of the circumstances requiring such action.
Note
The requirements that will apply under jurisdictional electricity legislation for the
purposes of paragraph (b) will be requirements that correspond to the matters set
out in clause 4.8.15 in the Rules applying in other participating jurisdictions. The
application of paragraph (b) will be revisited as part of the phased implementation
of the Rules in this jurisdiction.
(3) Clause 5.9.3(d)
omit, insert
(d) A Registered Participant's facilities or market load may be
disconnected from the network under an emergency frequency
control arrangement if this is permitted under jurisdictional
electricity legislation.
25ZI Clause 5.9.4 modified
Clause 5.9.4(a), (b) and (d)
omit (all references)
AEMO
insert
NTESMO
-- 58 of 290 --
Schedule 2 Further modifications to operation of National Electricity Rules
National Electricity (Northern Territory) (National Uniform Legislation) (Modification)
Regulations 2016 53
25ZJ Clause 5.9.4A modified
Clause 5.9.4A
omit
AEMO
insert
NTESMO
25ZK Clause 5.9.5 modified
(1) Clause 5.9.5(a) and (b)
omit (all references)
AEMO
insert
NTESMO
(2) Clause 5.9.5(a)(2)
omit
AEMO's
insert
NTESMO's
25ZL Clause 5.9.6 modified
(1) Clause 5.9.6(a) and (c)
omit (all references)
AEMO
insert
NTESMO
-- 59 of 290 --
Schedule 2 Further modifications to operation of National Electricity Rules
National Electricity (Northern Territory) (National Uniform Legislation) (Modification)
Regulations 2016 54
(2) Clause 5.9.6(a)(4)
omit, insert
(4) NTESMO determines that the requirements under
jurisdictional electricity legislation for reconnection following
disconnection under an emergency frequency control
arrangement are satisfied.
(3) Clause 5.9.6(b)
omit, insert
(b) In carrying out its obligations under clause 5.9.6(a), NTESMO must,
to the extent practicable, arrange for the implementation of an
equitable sharing of the reconnection of facilities across the
relevant local electricity system up to the power transfer capability
of the network and, in performing these obligations, both NTESMO
and the relevant Network Service Provider must, to the extent
practicable, give priority to reconnection of sensitive loads.
25ZM Clause 5.10.1 modified
Clause 5.10.1(j2), note
omit
25ZN Clause 5.10.2 modified
Clause 5.10.2, definition reliability corrective action
omit, insert
reliability corrective action means investment by a Transmission
Network Service Provider or a Distribution Network Service
Provider in respect of its transmission network or distribution
network for the purpose of meeting the service standards linked to
the technical requirements of jurisdictional electricity legislation or in
applicable regulatory instruments and which may consist of network
options or non-network options.
Note
In the definition of reliability corrective action, the reference to the technical
requirements of jurisdictional electricity legislation will be requirements that
correspond to the matters set out in Schedule 5.1 in the Rules applying in other
participating jurisdictions. This definition will be revisited as part of the phased
implementation of the Rules in this jurisdiction.
-- 60 of 290 --
Schedule 2 Further modifications to operation of National Electricity Rules
National Electricity (Northern Territory) (National Uniform Legislation) (Modification)
Regulations 2016 55
25ZO Clause 5.11.1 modified
Clause 5.11.1(d)
omit
AEMO
insert
NTESMO
25ZP Clause 5.11.2 modified
(1) After clause 5.11.2, heading
insert
Note
The application of paragraph (b) of this clause will be revisited as part of the
phased implementation of the Rules in this jurisdiction.
(2) Clause 5.11.2(b)
omit, insert
(b) if the analysis required by paragraph (a) indicates that any relevant
technical limits of the transmission or distribution systems will be
exceeded, either in normal conditions or following the contingencies
specified in jurisdictional electricity legislation, notify any affected
Registered Participants and NTESMO of these limitations; and
Note
The contingencies in jurisdictional electricity legislation referred to in
paragraph (b) will be contingencies that correspond to the matters set out in
Schedule 5.1 in the Rules applying in other participating jurisdictions. The
specification of contingencies will be revisited as part of the phased
implementation of the Rules in this jurisdiction.
(3) Clause 5.11.2(c)
omit
AEMO
insert
NTESMO
-- 61 of 290 --
Schedule 2 Further modifications to operation of National Electricity Rules
National Electricity (Northern Territory) (National Uniform Legislation) (Modification)
Regulations 2016 56
25ZQ Clause 5.12.1 modified
Clause 5.12.1(b)(3)
omit
25ZR Clause 5.12.2 modified
(1) After clause 5.12.2, heading
insert
Note
Paragraph (c)(6), (6A) and (8)(ii) of this clause has no effect in this jurisdiction
(see regulation 5A of the National Electricity (Northern Territory) (National
Uniform Legislation) (Modification) Regulations 2016). The application of these
provisions, the rest of paragraph (c)(8), and paragraph (c)(9) and (10), will be
revisited as part of the phased implementation of the Rules in this jurisdiction.
(2) Clause 5.12.2(a) and (b)
omit, insert
(a) By 31 December each year all Transmission Network Service
Providers must publish a Transmission Annual Planning Report
setting out the results of the annual planning review conducted in
accordance with clause 5.12.1.
(b) A Network Service Provider must publish its Transmission Annual
Planning Report in the same document as its Distribution Annual
Planning Report.
(3) Clause 5.12.2(c)(9)
omit
clause S5.1.8
insert
jurisdictional electricity legislation
(4) Clause 5.12.2(c)(10)
omit
clause S5.1.10
insert
jurisdictional electricity legislation
-- 62 of 290 --
Schedule 2 Further modifications to operation of National Electricity Rules
National Electricity (Northern Territory) (National Uniform Legislation) (Modification)
Regulations 2016 57
(5) After clause 5.12.2(c)
insert
Note
The emergency controls in jurisdictional electricity legislation referred to in
subparagraph (9) will be emergency controls that correspond to clause S5.1.8 in
the Rules applying in other participating jurisdictions. The facilities in jurisdictional
electricity legislation referred to in subparagraph (10) will be facilities that
correspond to clause S5.1.10 in the Rules applying in other participating
jurisdictions.
25ZS Clause 5.13.1 modified
Clause 5.13.1(g)
omit
31 August 2013
insert
31 August 2020
25ZT Clause 5.13.2 modified
Clause 5.13.2(b), note
omit, insert
Note
Under clause 5.12.2(b), a Network Service Provider may publish its Transmission
Annual Planning Report in the same document as its Distribution Annual
Planning Report under this clause 5.13.2.
25ZU Clause 5.13.3 modified
After clause 5.13.3(d)
insert
(e) For the application of these Rules in this jurisdiction:
(1) a system limitation template developed and published by the
AER and in operation immediately before 1 July 2019 is taken
to have been developed and published by the AER on
1 July 2019; and
(2) the AER is taken to have complied with the requirements of
paragraphs (a) and (c) in developing and publishing the
system limitation template.
-- 63 of 290 --
Schedule 2 Further modifications to operation of National Electricity Rules
National Electricity (Northern Territory) (National Uniform Legislation) (Modification)
Regulations 2016 58
25ZV Rule 5.13A modified
Rule 5.13A(a), definition ten year zone substation report
omit
the commencement of this rule 5.13A
insert
1 July 2019
25ZW Clause 5.14.1 modified
Clause 5.14.1(c), after "dual function assets"
insert
or transmission assets that are regulated under Chapter 6
25ZX Clause 5.14B.1 modified
Clause 5.14B.1, at the end
insert
Note
Section 12A of the National Electricity (Northern Territory) (National Uniform
Legislation) Act 2015 applies to an instrument or decision made by the AER after
the enactment of that Act and before the day on which this clause commences
operation in the Northern Territory, in circumstances set out in that section. The
TAPR Guidelines made and published by the AER under this clause constitute
an instrument to which section 12A applies. Accordingly, for the purposes of this
clause as it applies as part of the NT national electricity legislation of the
Northern Territory, the TAPR Guidelines are taken to be valid and to have effect
from 1 July 2019.
25ZY Clause 5.15.1 modified
Clause 5.15.1
omit
National Electricity Market
25ZZ Clause 5.15.2 modified
Clause 5.15.2(b)(4)
omit
intra-regional or inter-regional trading of electricity
-- 64 of 290 --
Schedule 2 Further modifications to operation of National Electricity Rules
National Electricity (Northern Territory) (National Uniform Legislation) (Modification)
Regulations 2016 59
insert
trading of electricity within a local electricity system
25ZZA Clause 5.16.1 modified
(1) Clause 5.16.1(b)
omit
or the provision of inertia network services required under
clause 5.20B.4 or the provision of system strength services
required under clause 5.20C.3
(2) Clause 5.16.1(c)(4)(vii)
omit
ancillary services
insert
ancillary services
25ZZB Clause 5.16.2 modified
After clause 5.16.2(a)
insert
Note
Section 12A of the National Electricity (Northern Territory) (National Uniform
Legislation) Act 2015 applies to an instrument or decision made by the AER after
the enactment of that Act and before the day on which this clause commences
operation in the Northern Territory, in circumstances set out in that section.
Guidelines developed and published by the AER under paragraph (a) constitute
an instrument to which section 12A applies. Accordingly, for the purposes of this
clause as it applies as part of the NT national electricity legislation of the
Northern Territory, these guidelines are taken to be valid and to have effect from
1 July 2019.
25ZZC Clause 5.16.3 modified
After clause 5.16.3, heading
insert
Note
Paragraph (a)(8) to (11) of this clause has no effect in this jurisdiction (see
regulation 5A of the National Electricity (Northern Territory) (National Uniform
Legislation) (Modification) Regulations 2016). The application of these provisions
will be revisited as part of the phased implementation of the Rules in this
jurisdiction.
-- 65 of 290 --
Schedule 2 Further modifications to operation of National Electricity Rules
National Electricity (Northern Territory) (National Uniform Legislation) (Modification)
Regulations 2016 60
25ZZD Clause 5.16.4 modified
(1) After clause 5.16.4, heading
insert
Note
Paragraph (b)(4) of this clause has no effect in this jurisdiction (see regulation 5A
of the National Electricity (Northern Territory) (National Uniform Legislation)
(Modification) Regulations 2016). The application of this paragraph will be
revisited as part of the phased implementation of the Rules in this jurisdiction.
(2) Clause 5.16.4(a), (c), (d)(1), (e), (f), (g), (j), (o)(1), (p), (q), (r), (s),
(t), (u), (w)(1) and (x)
omit (all references)
AEMO
insert
NTESMO
25ZZE Clause 5.16.5 modified
Clause 5.16.5(a)
omit
AEMO
insert
NTESMO
25ZZF Clause 5.17.1 modified
Clause 5.17.1(b), (c)(4)(vi) and (c)(9)(v)
omit (all references)
National Electricity Market
insert
local electricity system
-- 66 of 290 --
Schedule 2 Further modifications to operation of National Electricity Rules
National Electricity (Northern Territory) (National Uniform Legislation) (Modification)
Regulations 2016 61
25ZZG Clause 5.17.2 modified
(1) After clause 5.17.2(a)
insert
Note
Section 12A of the National Electricity (Northern Territory) (National Uniform
Legislation) Act 2015 applies to an instrument or decision made by the AER after
the enactment of that Act and before the day on which this clause commences
operation in the Northern Territory, in circumstances set out in that section.
Guidelines developed and published by the AER under paragraph (a) constitute
an instrument to which section 12A applies. Accordingly, for the purposes of this
clause as it applies as part of the NT national electricity legislation of the
Northern Territory, these guidelines are taken to be valid and to have effect from
1 July 2019.
(2) Clause 5.17.2(b)(2)(iii)
omit
National Electricity Market
insert
local electricity system
25ZZH Clause 5.17.3 modified
After clause 5.17.3, heading
insert
Note
Paragraph (a)(7) of this clause has no effect in this jurisdiction (see regulation 5A
of the National Electricity (Northern Territory) (National Uniform Legislation)
(Modification) Regulations 2016). The application of this paragraph will be
revisited as part of the phased implementation of the Rules in this jurisdiction.
25ZZI Clause 5.17.4 modified
(1) After clause 5.17.4, heading
insert
Note
The application of paragraph (e)(4)(iv) of this clause will be revisited as part of
the phased implementation of the Rules in this jurisdiction.
-- 67 of 290 --
Schedule 2 Further modifications to operation of National Electricity Rules
National Electricity (Northern Territory) (National Uniform Legislation) (Modification)
Regulations 2016 62
(2) Clause 5.17.4(a)(1), (h) and (k)(1)
omit (all references)
AEMO
insert
NTESMO
(3) Clause 5.17.4(e)(4)(iv)
omit
clause 4.6.1
insert
jurisdictional electricity legislation
(4) After clause 5.17.4(e)(4)
insert
Note
The power system fault levels in jurisdictional electricity legislation referred to in
subparagraph (4)(iv) will be power system fault levels that correspond to
clause 4.6.1 in the Rules applying in other participating jurisdictions.
25ZZJ Clause 5.17.5 modified
Clause 5.17.5(a)
omit
AEMO
insert
NTESMO
25ZZK Rule 5.18 modified
After rule 5.18, heading
insert
Note
The application of paragraph (c) of this rule will be revisited as part of the phased
implementation of the Rules in this jurisdiction.
-- 68 of 290 --
Schedule 2 Further modifications to operation of National Electricity Rules
National Electricity (Northern Territory) (National Uniform Legislation) (Modification)
Regulations 2016 63
25ZZL Rule 5.18A modified
Rule 5.18A, heading
omit
Large generator connections
insert
Generator connections
25ZZM Clause 5.18A.1 modified
Clause 5.18A.1(a), definition large generator connection
omit, insert
large generator connection means generating units that are
owned, operated or controlled by a Generator, are connected to the
Transmission Network Service Provider's network, and are above
the relevant materiality threshold.
25ZZN Clause 5.18A.2 modified
(1) Clause 5.18A.2, heading
omit, insert
Register of generator connections
(2) Clause 5.18A.2(a)
omit, insert
(a) A Transmission Network Service Provider must establish, maintain
and publish, on its website, a register of information regarding
Generator connections on its network (a connections register),
including but not limited to the following information in respect of
each Generator connection:
(1) location of the connection point for the Generator connection;
(2) person who is licensed by the Utilities Commission as a
Generator in respect of the Generator connection at that
connection point;
(3) technology of the generating units (for example, hydro, open
cycle gas turbine, and steam sub-critical);
-- 69 of 290 --
Schedule 2 Further modifications to operation of National Electricity Rules
National Electricity (Northern Territory) (National Uniform Legislation) (Modification)
Regulations 2016 64
(4) aggregate nameplate rating capacity of all connected
generating units;
(5) date of cessation of a person's licence as Generator in respect
of the Generator connection, or date of cessation of an
exemption to hold such a licence applying in relation to a
person, where relevant; and
(6) in the case of a large generator connection, the impact
assessment of that large generator connection, prepared in
accordance with clause 5.18A.3 (if any).
(3) Clause 5.18A.2(c)
omit, insert
(c) The Transmission Network Service Provider must:
(1) include in the first connections register the details contained in
subparagraphs (a)(1) to (5), for all Generator connections on
its network with a commissioning date after 1 July 2019; and
(2) by the TAPR date each year, update the connections register
to include:
(i) the details contained in subparagraphs (a)(1) to (6) for
all new Generator connections on its network; and
(ii) updated information for all Generator connections
contained in the connections register where the
information listed in subparagraphs (a)(1)-(5) has
changed.
25ZZO Clause 5.18A.3 modified
(1) After clause 5.18A.3, heading
insert
Note
Paragraph (d)(1) of this clause has no effect in this jurisdiction (see regulation 5A
of the National Electricity (Northern Territory) (National Uniform Legislation)
(Modification) Regulations 2016). The application of this paragraph will be
revisited as part of the phased implementation of the Rules in this jurisdiction.
-- 70 of 290 --
Schedule 2 Further modifications to operation of National Electricity Rules
National Electricity (Northern Territory) (National Uniform Legislation) (Modification)
Regulations 2016 65
(2) Clause 5.18A.3(a)
omit, insert
(a) Following the commissioning date of a new large generator
connection on a Transmission Network Service Provider's network,
the Transmission Network Service Provider must:
(1) determine whether that large generator connection is likely to
have a material impact on its transmission network; and
(2) if the Transmission Network Service Provider determines that
large generator connection is likely to have a material impact
on its transmission network, prepare an assessment of the
impact of that large generator connection on its network by the
assessment date (impact assessment)
(a1) If the Transmission Network Service Provider determines that that
large generator connection is not likely to have a material impact on
its transmission network, the Transmission Network Service
Provider must outline the reasons for determining such impacts to
be immaterial.
25ZZP Clause 5.18B.1 modified
Clause 5.18B.1(a), definition completed embedded generation
projects
omit, insert
completed embedded generation projects means all embedded
generating units owned, operated or controlled by a Generator that
are connected to the Distribution Network Service Provider's
network.
25ZZQ Rule 5.20 modified
After rule 5.20, heading
insert
Note
This rule has no effect in this jurisdiction (see regulation 5A of the National
Electricity (Northern Territory) (National Uniform Legislation) (Modification)
Regulations 2016).
-- 71 of 290 --
Schedule 2 Further modifications to operation of National Electricity Rules
National Electricity (Northern Territory) (National Uniform Legislation) (Modification)
Regulations 2016 66
25ZZR Rules 5.20A, 5.20B and 5.20C modified
After rules 5.20A, 5.20B and 5.20C, headings
insert
Note
This rule has no effect in this jurisdiction (see regulation 5A of the National
Electricity (Northern Territory) (National Uniform Legislation) (Modification)
Regulations 2016). The application of this rule will be revisited as part of the
phased implementation of the Rules in this jurisdiction.
25ZZS Rules 5.21 and 5.22 modified
After rules 5.21 and 5.22, headings
insert
Note
This rule has no effect in this jurisdiction (see regulation 5A of the National
Electricity (Northern Territory) (National Uniform Legislation) (Modification)
Regulations 2016).
25ZZT Schedules 5.1a to 5.3a modified
After schedules 5.1a, 5.1, 5,2, 5.3 and 5.3a, headings
insert
Note
This schedule has no effect in this jurisdiction (see regulation 5A of the National
Electricity (Northern Territory) (National Uniform Legislation) (Modification)
Regulations 2016). The application of this schedule will be revisited as part of
the phased implementation of the Rules in this jurisdiction.
25ZZU Schedule 5.4A modified
(1) After schedule 5.4A, heading and note
insert
Note
Paragraphs (a)(9), (i1) and (o)(3) of this schedule have no effect in this
jurisdiction (see regulation 5A of the National Electricity (Northern Territory)
(National Uniform Legislation) (Modification) Regulations 2016). The application
of these paragraphs will be revisited as part of the phased implementation of the
Rules in this jurisdiction.
-- 72 of 290 --
Schedule 2 Further modifications to operation of National Electricity Rules
National Electricity (Northern Territory) (National Uniform Legislation) (Modification)
Regulations 2016 67
(2) Schedule 5.4A(c)
omit, insert
(c) information relevant to each technical requirement of the proposed
plant under jurisdictional electricity legislation and the normal
voltage level, if it is expected to change from the nominal voltage
level;
25ZZV Schedule 5.4B modified
(1) After schedule 5.4B, heading
insert
Note
Paragraphs (e) and (e1)(2) of this schedule have no effect in this jurisdiction (see
regulation 5A of the National Electricity (Northern Territory) (National Uniform
Legislation) (Modification) Regulations 2016). The application of paragraphs (b),
(e) and (e1) of this schedule will be revisited as part of the phased
implementation of the Rules in this jurisdiction.
(2) Schedule 5.4B(b)
omit, insert
(b) written details of each technical requirement relevant to the
proposed plant under jurisdictional electricity legislation;
(3) Schedule 5.4B(g)
omit
rules 6.21 and 6A.28
insert
rule 6.21
25ZZW Schedules 5.5, 5.5.3, 5.5.4 and 5.5.5 modified
After Schedules 5.5, 5.5.3, 5.5.4 and 5.5.5, headings
insert
Note
This schedule has no effect in this jurisdiction (see regulation 5A of the National
Electricity (Northern Territory) (National Uniform Legislation) (Modification)
Regulations 2016).
-- 73 of 290 --
Schedule 2 Further modifications to operation of National Electricity Rules
National Electricity (Northern Territory) (National Uniform Legislation) (Modification)
Regulations 2016 68
25ZZX Schedule 5.6 modified
(1) After schedule 5.6, heading
insert
Note
Paragraphs (c2) and (c3) of this schedule have no effect in this jurisdiction (see
regulation 5A of the National Electricity (Northern Territory) (National Uniform
Legislation) (Modification) Regulations 2016). The application of paragraphs (c),
(c1) and (c3) of this schedule will be revisited as part of the phased
implementation of the Rules in this jurisdiction.
(2) Schedule 5.6, Part A(c1)
omit, insert
(c1) details of each access standard agreed between the Network
Service Provider and the Registered Participant and all related
conditions of agreement resulting from the application of the access
provisions contained in jurisdictional electricity legislation;
Note
The access provisions in jurisdictional electricity legislation referred to in
paragraph (c1) will be access provisions that correspond to schedules 5.1, 5.2
or 5.3 in the Rules applying in other participating jurisdictions.
25ZZY Schedule 5.8 modified
(1) After schedule 5.8, heading and note
insert
Note
The application of paragraph (m) of this schedule will be revisited as part of the
phased implementation of the Rules in this jurisdiction.
(2) Schedule 5.8(m)
omit, insert
(m) information on the Distribution Network Service Provider's
investments in metering or information technology and
communication systems which occurred in the preceding year, and
planned investments in metering or information technology and
communication systems related to management of network assets
in the forward planning period; and
-- 74 of 290 --
Schedule 2 Further modifications to operation of National Electricity Rules
National Electricity (Northern Territory) (National Uniform Legislation) (Modification)
Regulations 2016 69
25ZZZ Schedule 5.9 modified
After schedule 5.9, heading and note
insert
Note
Paragraph (h) of this schedule has no effect in this jurisdiction (see regulation 5A
of the National Electricity (Northern Territory) (National Uniform Legislation)
(Modification) Regulations 2016). The application of paragraph (h) of this
schedule will be revisited as part of the phased implementation of the Rules in
this jurisdiction.
25ZZZA Schedule 5.11 modified
(1) After schedule 5.11, heading
insert
The following provisions apply to the operation of this schedule:
(a) principles (1), (4), (8), (9) and (10) have no effect in this
jurisdiction;
(b) principles (2), (3), (5), (6) and (7) only have effect for the
purposes of schedule 12;
(c) principles (11), (12) and (13) only have effect for the purposes
of Chapter 6, in relation to negotiated transmission services.
(2) Schedule 5.11, paragraph 3
omit, insert
3 If the negotiated transmission service is the provision of a
shared transmission service that exceeds the network
performance requirements (if any) which that shared
transmission service is required to meet under any
jurisdictional electricity legislation, then the differential
between the price for that service and the price for the shared
transmission service which meets (but does not exceed) the
network performance requirements under any jurisdictional
electricity legislation should reflect the increase in the
Transmission Network Service Provider's incremental cost of
providing that service.
(3) Schedule 5.11, paragraph 8, after "principles (1) to (7)"
insert
(other than principles (1) and (4))
-- 75 of 290 --
Schedule 2 Further modifications to operation of National Electricity Rules
National Electricity (Northern Territory) (National Uniform Legislation) (Modification)
Regulations 2016 70
25ZZZB Schedule 5.12 modified
Schedule 5.12, paragraph 1, after "schedule 5.11"
insert
(other than principle 4)
26 Clause 5A.A.1 modified
Clause 5A.A.1, definition confidential information
omit (all references)
AEMO
insert
NTESMO
27 Clause 5A.A.2 modified
Clause 5A.A.2(a)
omit
an Intending Participant unless the Registered Participant or
Intending Participant
insert
a person intending to become a Registered Participant unless the
Registered Participant or person intending to become a Registered
Participant
28 Clause 5A.A.3 modified
After clause 5A.A.3, heading
insert
Note
Clause 5A.A.3 has no effect in this jurisdiction (see regulation 5A of the National
Electricity (Northern Territory) (National Uniform Legislation) (Modification)
Regulations). The application of clause 5A.A.3 will be revisited as part of the
phased implementation of the Rules in this jurisdiction.
-- 76 of 290 --
Schedule 2 Further modifications to operation of National Electricity Rules
National Electricity (Northern Territory) (National Uniform Legislation) (Modification)
Regulations 2016 71
30 Clause 5A.B.3 modified
After clause 5A.B.3(b)
insert
(ba) For the purposes of paragraph (b)(1), the AER must regard the
reference to "the national electricity system" in the national
electricity objective stated in section 7 of the Law as including a
reference to one or more, or all, of the local electricity systems, as
the case requires.
31 Clause 5A.B.5 modified
After clause 5A.B.5(b)
insert
(ba) For the purposes of paragraph (b), the AER must regard the
reference to "the national electricity system" in the national
electricity objective stated in section 7 of the Law as including a
reference to one or more, or all, of the local electricity systems, as
the case requires.
33 Clause 5A.C.1 modified
After clause 5A.C.1, heading
insert
Note
Clause 5A.C.1(c) and (d) has no effect in this jurisdiction until the National
Energy Retail Law is applied as a law of this jurisdiction (see regulation 5A of the
National Electricity (Northern Territory) (National Uniform Legislation)
(Modification) Regulations).
34 Clause 5A.D.1A modified
(1) Clause 5A.D.1A
insert
relevant materiality threshold has the same meaning as in
clause 5.1.3.
(2) Clause 5A.D.1A, definition completed non-registered embedded
generation projects, after "Distribution Network Service Provider's
network"
insert
and that are below the relevant materiality threshold
-- 77 of 290 --
Schedule 2 Further modifications to operation of National Electricity Rules
National Electricity (Northern Territory) (National Uniform Legislation) (Modification)
Regulations 2016 72
38 Clause 5A.E.3 modified
After clause 5A.E.3(g)
insert
(ga) For the application of these Rules in this jurisdiction:
(1) the connection charge guidelines that are in force in the other
participating jurisdictions on 1 July 2017 are taken:
(i) to be the connection charge guidelines in force in this
jurisdiction (subject to any amendment or replacement
under these Rules); and
(ii) to have been developed and published by the AER on
1 July 2017; and
(2) the AER is taken to have complied with the requirements of
paragraphs (e), (f) and (g) in developing and publishing the
connection charge guidelines.
39 Clause 5A.E.4 modified
After clause 5A.E.4, heading
insert
Note
The note to clause 5A.E.4(c) has no effect in this jurisdiction until the National
Energy Retail Law is applied as a law of this jurisdiction. The remaining
provisions of clause 5A.E.4 have no effect in this jurisdiction until 1 July 2019
(see regulation 5A of the National Electricity (Northern Territory) (National
Uniform Legislation) (Modification) Regulations).
41 Clause 5A.F.5 modified
After clause 5A.F.5, heading
insert
Note
Clause 5A.F.5(b)(2) has no effect in this jurisdiction until the National Energy
Retail Law is applied as a law of this jurisdiction (see regulation 5A of the
National Electricity (Northern Territory) (National Uniform Legislation)
(Modification) Regulations).
-- 78 of 290 --
Schedule 2 Further modifications to operation of National Electricity Rules
National Electricity (Northern Territory) (National Uniform Legislation) (Modification)
Regulations 2016 73
42 Rules 6.0 and 6.0A inserted
After Chapter 6, Part A, heading
insert
6.0 Operation of Chapter 6 in this jurisdiction
(a) This rule applies if a Distribution Network Service Provider owns,
controls or operates more than one distribution system in this
jurisdiction.
(b) Despite any other provision of this Chapter:
(1) for all of those distribution systems there must be, in respect
of a particular regulatory control period, only one:
(i) draft distribution determination and final distribution
determination;
(ii) framework and approach paper;
(iii) building block proposal and building block determination;
(iv) regulatory proposal;
(v) proposed and final tariff structure statement; and
(vi) regulatory asset base value; and
(2) all of those distribution systems must be treated as a single
distribution system for the purposes of clause 6.5.1 and
schedule 6.2.
6.0A Interpretation
(a) This rule applies in relation to the following:
(1) the provisions of this Chapter;
(2) the provisions of Chapters 11 and 11A, to the extent the
provisions operate in relation to this Chapter;
(3) an instrument made under or for the purposes of this Chapter;
and
(4) the definitions in Chapter 10, to the extent the definitions are
mentioned in a provision or instrument mentioned in
subparagraph (1), (2) or (3).
-- 79 of 290 --
Schedule 2 Further modifications to operation of National Electricity Rules
National Electricity (Northern Territory) (National Uniform Legislation) (Modification)
Regulations 2016 74
(b) Unless the context or subject matter otherwise indicates or
requires:
(1) a prescribed transmission service will be taken to be a direct
control service under a provision or instrument mentioned in
paragraph (a); and
(2) a negotiated transmission service will be taken to be a
negotiated distribution service under a provision or instrument
mentioned in paragraph (a).
(c) Unless the context or subject matter otherwise indicates or
requires, in a provision or instrument mentioned in paragraph (a):
(1) a reference to a "distribution network" must be regarded as
including a reference to a "transmission network";
(2) a reference to a "distribution system" must be regarded as
including a reference to a "transmission system";
(3) a reference to a "Distribution Network User" must be regarded
as including a reference to a "Transmission Network User;
(4) a reference to a "Distribution Network Service Provider" must
be regarded as including a reference to a "Transmission
Network Service Provider";
(5) a reference to a "distribution service" must be regarded as
including a reference to a "transmission service";
(6) a reference to an "embedded generating unit" must be
regarded as a reference to a "generating unit";
(7) a reference to an "Embedded Generator" must be regarded as
a reference to a "Generator"; and
(8) a reference to a "Distribution Customer" must be regarded as
including a reference to a "Transmission Customer".
43 Clause 6.1.3 modified
(1) Clause 6.1.3(a)(2)
omit
Chapters 4, 5, this Chapter 6 and Chapter 7A of the Rules
insert
Chapters 5, 6 and 7A of the Rules and under jurisdictional
electricity legislation
-- 80 of 290 --
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Regulations 2016 75
(2) After clause 6.1.3(a)
insert
Note:
The terms and conditions of access in jurisdiction electricity legislation will be
terms and conditions that correspond to matters set out in Chapter 4 of the Rules
applying in other participating jurisdictions. The application of paragraph (a) will
be revisited as part of the phased implementation of the Rules in this jurisdiction.
44 Clause 6.2.1 modified
Clause 6.2.1, note
omit
Chapter 5A
insert
Chapters 5 and 5A
(3) Clause 6.2.5(d)(3)
omit, insert
(2A) for a distribution determination for a Distribution Network
Service Provider in this jurisdiction that will apply during the
1st regulatory control period – the regulatory arrangements in
the 2014 NT Network Price Determination); and
(3) for a distribution determination for a Distribution Network
Service Provider in this jurisdiction that will apply after the
1st regulatory control period – the regulatory arrangements (if
any) applicable to the relevant service immediately before the
commencement of the distribution determination; and
(4) Clause 6.2.5(d), at the end
insert
Note:
The modifications to this paragraph expire on 1 July 2024.
-- 81 of 290 --
Schedule 2 Further modifications to operation of National Electricity Rules
National Electricity (Northern Territory) (National Uniform Legislation) (Modification)
Regulations 2016 76
47 Clause 6.4.1 modified
After clause 6.4.1(c)
insert
(ca) For the application of these Rules in this jurisdiction:
(1) the post-tax revenue model that is in force in the other
participating jurisdictions on 1 July 2016 is taken:
(i) to be the post-tax revenue model in force in this
jurisdiction (subject to any amendment or replacement
under these Rules); and
(ii) to have been prepared and published by the AER on
1 July 2016; and
(2) the AER is taken to have complied with the requirements of
paragraphs (a) and (c) in preparing and publishing the post-
tax revenue model.
49 Clause 6.4.4 modified
After clause 6.4.4(e)
insert
(ea) For the application of these Rules in this jurisdiction:
(1) the Shared Asset Guidelines that are in force in the other
participating jurisdictions on 1 July 2016 are taken:
(i) to be the Shared Asset Guidelines in force in this
jurisdiction (subject to any amendment or replacement
under these Rules); and
(ii) to have been made and published by the AER on
1 July 2016; and
(2) the AER is taken to have complied with the requirements of
paragraph (d) in making and publishing the Shared Asset
Guidelines.
-- 82 of 290 --
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Regulations 2016 77
50 Clause 6.4.5 modified
After clause 6.4.5(b)
insert
(ba) For the application of these Rules in this jurisdiction:
(1) the Expenditure Forecast Assessment Guidelines that are in
force in the other participating jurisdictions on 1 July 2016 are
taken:
(i) to be the Expenditure Forecast Assessment Guidelines
in force in this jurisdiction (subject to any amendment or
replacement under these Rules); and
(ii) to have been developed and published by the AER on
1 July 2016; and
(2) the AER is taken to have complied with the requirements of
paragraph (a) in developing and publishing the Expenditure
Forecast Assessment Guidelines.
51 Rule 6.4A modified
After rule 6.4A(c)
insert
(ca) For the application of these Rules in this jurisdiction:
(1) the Capital Expenditure Incentive Guidelines that are in force
in the other participating jurisdictions on 1 July 2016 are taken:
(i) to be the Capital Expenditure Incentive Guidelines in
force in this jurisdiction (subject to any amendment or
replacement under these Rules); and
(ii) to have been made and published by the AER on
1 July 2016; and
(2) the AER is taken to have complied with the requirements of
paragraph (b) in making and publishing the Capital
Expenditure Incentive Guidelines.
-- 83 of 290 --
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Regulations 2016 78
52 Clause 6.5.1 modified
After clause 6.5.1(d)
insert
(da) For the application of these Rules in this jurisdiction:
(1) the roll forward model that is in force in the other participating
jurisdictions on 1 July 2016 is taken:
(i) to be the roll forward model in force in this jurisdiction
(subject to any amendment or replacement under these
Rules); and
(ii) to have been developed and published by the AER on
1 July 2016; and
(2) the AER is taken to have complied with the requirements of
paragraphs (b), (d) and (e) in developing and publishing the
roll forward model.
53 Clause 6.5.2 modified
After clause 6.5.2(q)
insert
(qa) For the application of these Rules in this jurisdiction:
(1) the Rate of Return Guidelines that are in force in the other
participating jurisdictions on 1 July 2016 are taken:
(i) to be the Rate of Return Guidelines in force in this
jurisdiction (subject to any amendment or replacement
under these Rules); and
(ii) to have been made and published by the AER on
1 July 2016; and
(2) the AER is taken to have complied with the requirements of
paragraphs (m) and (n) in making and publishing the Rate of
Return Guidelines; and
(3) despite paragraph (p)(1), the AER need only review the Rate
of Return Guidelines when it is required to review the
Guidelines in the other participating jurisdictions.
-- 84 of 290 --
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Regulations 2016 79
54 Clause 6.5.8 modified
After clause 6.5.8(d)
insert
(da) For the application of these Rules in this jurisdiction:
(1) the efficiency benefit sharing scheme that is in force in the
other participating jurisdictions on 1 July 2016 is taken:
(i) to be the efficiency benefit sharing scheme in force in
this jurisdiction (subject to any amendment or
replacement under these Rules); and
(ii) to have been developed and published by the AER on
1 July 2016; and
(2) the AER is taken to have complied with the requirements of
paragraphs (a) and (c) in developing and publishing the
efficiency benefit sharing scheme.
55 Clause 6.5.8A modified
After clause 6.5.8A(e)
insert
(ea) For the application of these Rules in this jurisdiction:
(1) the capital expenditure sharing scheme that is in force in the
other participating jurisdictions on 1 July 2016 is taken:
(i) to be the capital expenditure sharing scheme in force in
this jurisdiction (subject to any amendment or
replacement under these Rules); and
(ii) to have been developed by the AER on 1 July 2016; and
(2) the AER is taken to have complied with the requirements of
paragraphs (b), (c) and (d) in developing the capital
expenditure sharing scheme.
-- 85 of 290 --
Schedule 2 Further modifications to operation of National Electricity Rules
National Electricity (Northern Territory) (National Uniform Legislation) (Modification)
Regulations 2016 80
56 Clause 6.6.1 modified
After clause 6.6.1, heading
insert
Note:
Clause 6.6.1(a1)(4), (c)(6)(iii), (l) and (m) have no effect in this jurisdiction until
the National Energy Retail Law is applied as a law of this jurisdiction (see
regulation 5A of the National Electricity (Northern Territory) (National Uniform
Legislation) (Modification) Regulations).
57 Clause 6.6.1 modified (expires when NERL applied)
Before clause 6.6.1(a1)(1)
insert
(1AA) a local event prescribed by the National Electricity
(Northern Territory) (National Uniform Legislation)
(Modification) Regulations;
Notes:
1 See Part 3 of the National Electricity (Northern Territory) (National Uniform
Legislation) (Modification) Regulations for modifications to the operation of
this clause 6.6.1 in relation to a local event.
2 Subparagraph (1AA) expires when the National Energy Retail Law is applied
as a law of this jurisdiction.
60 Clause 6.6.2 modified
After clause 6.6.2(c)
insert
(ca) For the application of these Rules in this jurisdiction:
(1) the service target performance incentive scheme that is in
force in the other participating jurisdictions on 1 July 2016 is
taken:
(i) to be the service target performance incentive scheme in
force in this jurisdiction (subject to any amendment or
replacement under these Rules); and
(ii) to have been developed and published by the AER on
1 July 2016; and
(2) the AER is taken to have complied with the requirements of
paragraphs (a) and (b) in developing and publishing the
service target performance incentive scheme.
-- 86 of 290 --
Schedule 2 Further modifications to operation of National Electricity Rules
National Electricity (Northern Territory) (National Uniform Legislation) (Modification)
Regulations 2016 81
61 Clause 6.6.3 modified
Clause 6.6.3(c)(3)
omit
in the market
insert
via a transmission or distribution system in this jurisdiction
62 Clause 6.6.4 modified
After clause 6.6.4(a)
insert
(ab) For the purposes of paragraph (a), the AER must regard the
reference to "the national electricity system" in the national
electricity objective stated in section 7 of the Law as including a
reference to one or more, or all, of the local electricity systems, as
the case requires.
63 Clause 6.6A.1 modified
Clause 6.6A.1(b)(2)(iii)
omit
$30
insert
$15
63A Clause 6.7.1 modified
(1) Clause 6.7.1(3)
omit, insert
(3) if the negotiated distribution service is the provision of a
shared distribution service that exceeds the network
performance requirements (if any) which that shared
distribution service is required to meet under any jurisdictional
electricity legislation, then the differential between the price for
that service and the price for the shared distribution service
which meets (but does not exceed) the network performance
requirements under any jurisdictional electricity legislation
should reflect the increase in the Distribution Network Service
-- 87 of 290 --
Schedule 2 Further modifications to operation of National Electricity Rules
National Electricity (Northern Territory) (National Uniform Legislation) (Modification)
Regulations 2016 82
Provider's incremental cost of providing that service;
(2) Clause 6.7.1(4)
omit
schedules 5.1a and 5.1
insert
jurisdictional electricity legislation
(3) After clause 6.7.1(4)
insert
Note:
The performance requirements in jurisdiction electricity legislation will be
performance requirements that correspond to matters set out in schedules 5.1a
and 5.1 of the Rules applying in other participating jurisdictions.
(4) Clause 6.7.1(8)(A)
omit
negotiated distribution services which would have been negotiated
distribution services regardless of the operation of clause 6.24.2(c)
insert
distribution services
(5) After clause 6.7.1(11)
insert
(12) in relation to negotiated transmission services that are taken
to be negotiated distribution services, principles (11), (12) and
(13) in schedule 5.11 that apply for the purposes of this
Chapter.
63B Clause 6.7.2 modified
(1) Clause 6.7.2(b)(1)
omit
which would have been negotiated distribution services regardless
of the operation of clause 6.24.2(c)
-- 88 of 290 --
Schedule 2 Further modifications to operation of National Electricity Rules
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Regulations 2016 83
(2) Clause 6.7.2(b)(2)
omit, insert
(2) rules 5.3 and 5.3A, when negotiating for the provision of
connection services and the associated connection service
charges in respect of the provision of negotiated transmission
services that are taken to be negotiated distribution services;
(3) Clause 6.7.2(b)(3)
omit
which would have been negotiated distribution services regardless
of the operation of clause 6.24.2(c)
63C Clause 6.7.5 modified
(1) Clause 6.7.5(d)(1)
omit
which would have been negotiated distribution services regardless
of the operation of clause 6.24.2(c)
(2) Clause 6.7.5(d)(2)
omit, insert
(2) rules 5.3 and 5.3A, insofar as the negotiating framework
applies to negotiated transmission services that are taken to
be negotiated distribution services,
68 Rule 6.14A modified
After rule 6.14A(d)
insert
(da) For the application of these Rules in this jurisdiction:
(1) the Distribution Confidentiality Guidelines that are in force in
the other participating jurisdictions on 1 July 2016 are taken:
(i) to be the Distribution Confidentiality Guidelines in force
in this jurisdiction (subject to any amendment or
replacement under these Rules); and
(ii) to have been made and published by the AER on
1 July 2016; and
-- 89 of 290 --
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National Electricity (Northern Territory) (National Uniform Legislation) (Modification)
Regulations 2016 84
(2) the AER is taken to have complied with the requirements of
paragraphs (a) and (b) in making and publishing the
Distribution Confidentiality Guidelines.
69 Clause 6.15.3 modified
After clause 6.15.3(e)
insert
(ea) For the application of these Rules in this jurisdiction:
(1) the Cost Allocation Guidelines that are in force in the other
participating jurisdictions on 1 July 2016 are taken:
(i) to be the Cost Allocation Guidelines in force in this
jurisdiction (subject to any amendment or replacement
under these Rules); and
(ii) to have been made and published by the AER on
1 July 2016; and
(2) the AER is taken to have complied with the requirements of
paragraphs (a), (b) and (e) in making and publishing the Cost
Allocation Guidelines.
70 Clause 6.15.4 modified
Clause 6.15.4(a)
omit, insert
(a) Each Distribution Network Service Provider in this jurisdiction must
submit to the AER for its approval a document setting out its
proposed Cost Allocation Method within 6 months of being required
to do so by the AER.
-- 90 of 290 --
Schedule 2 Further modifications to operation of National Electricity Rules
National Electricity (Northern Territory) (National Uniform Legislation) (Modification)
Regulations 2016 85
72 Clause 6.17.1B inserted
Before clause 6.17.2
insert
6.17.1B Application of Distribution Ring-Fencing Guidelines in this
jurisdiction
Despite clause 6.17.1, in this jurisdiction:
(a) the following provisions of the Distribution Ring-Fencing
Guidelines have no effect:
(1) clause 1.1.1, all words from "For the avoidance" to
"DNSPs.";
(2) clause 1.4, definition non-distribution services; and
(3) clauses 3.1, 4.2.1, 4.2.2 and 4.2.3; and
(b) a reference in the Distribution Ring-Fencing Guidelines to
"non-distribution services" must be regarded as a reference
to "other services"; and
(c) a reference in clause 3.2.1(a) of the Distribution Ring-Fencing
Guidelines and the note to that paragraph to "affiliated
entities" must be regarded as a reference to "related
electricity service providers"; and
(d) a reference in clause 6.2.1(b)(iv) of the Distribution Ring-
Fencing Guidelines to "affiliated entity" must be regarded as
a reference to "related electricity service provider".
Note:
This clause, and the operation of the Distribution Ring-Fencing Guidelines in this
jurisdiction, will be revisited in the event of the introduction of contestable
services (including contestable metering services) in this jurisdiction.
74 Clause 6.18.9 modified
After clause 6.18.9, heading
insert
Note:
Clause 6.18.9(a)(3) has no effect in this jurisdiction until 1 July 2019 (see
regulation 5A of the National Electricity (Northern Territory) (National Uniform
Legislation) (Modification) Regulations).
-- 91 of 290 --
Schedule 2 Further modifications to operation of National Electricity Rules
National Electricity (Northern Territory) (National Uniform Legislation) (Modification)
Regulations 2016 86
75 Chapter 6, Parts M and N modified
After Chapter 6, Parts M and N headings
insert
Note:
This Part has no effect in this jurisdiction. The application of this Part will be
revisited as part of the phased implementation of the Rules in this jurisdiction.
75A Rule 6.20.1 modified
(1) Clause 6.20.1(a)(2)
omit
a metrology procedure or, in the absence of a metrology procedure
allowing such a determination to be made, by meter
insert
schedule 7A.7
(2) Clause 6.20.1(b)
omit
(other than a Market Customer) incurs distribution service charges,
the Distribution Network Service Provider must bill the Market
Customer
insert
(other than a Distribution Customer who is financially responsible
for its own connection point) incurs distribution service charges, the
Distribution Network Service Provider must bill the retailer
(3) Clause 6.20.1(c)
omit
Market Customer
insert
retailer
-- 92 of 290 --
Schedule 2 Further modifications to operation of National Electricity Rules
National Electricity (Northern Territory) (National Uniform Legislation) (Modification)
Regulations 2016 87
(4) Clause 6.20.1(e)(1)
omit
that are Market Generators
insert
other than Embedded Generators whose sent out generation is not
purchased in its entirety by a Retailer or Customer located at the
same connection point
(5) Clause 6.20.1(e)(2)
omit
Market Customer
insert
Retailer
(6) Clause 6.20.1(e)(4)
omit
AEMO's
insert
NTESMO's
(7) Clause 6.20.1(e)(4)
omit
Market Customers
insert
Market Loads, Retailers
(8) Clause 6.20.1(e)(5)
omit
a metrology procedure
insert
schedule 7A.7
-- 93 of 290 --
Schedule 2 Further modifications to operation of National Electricity Rules
National Electricity (Northern Territory) (National Uniform Legislation) (Modification)
Regulations 2016 88
(9) Clause 6.20.1(e)(5)
omit
AEMO's
insert
NTESMO's
(10) Clause 6.20.1(e)(5)
omit
Market Customers
insert
Market Loads, retailers
(11) Clause 6.20.1(f)(1)
omit
that are not Market Generators
insert
whose sent out generation is not purchased in its entirety by a
Retailer or Customer located at the same connection point
(12) Clause 6.20.1(f) and (g)
omit
Local Retailer
insert
Retailer
75B Rule 6.21.3 modified
Clause 6.21.3(a)
omit
13 December 1998
insert
1 July 2019
-- 94 of 290 --
Schedule 2 Further modifications to operation of National Electricity Rules
National Electricity (Northern Territory) (National Uniform Legislation) (Modification)
Regulations 2016 89
75C Rule 6.22.2 modified
(1) Clause 6.22.2(a)(2)
omit
Chapters 4, 5, this Chapter 6 and Chapter 7 and any other
applicable regulatory instrument
insert
Chapter 5, this Chapter 6, Chapter 7A and any other applicable
regulatory instrument including but not limited to jurisdictional
electricity legislation
(2) Clause 6.22.2(a)(3)
omit, insert
(3) in relation to all terms and conditions of access (including
price) the decisions of the AER where those decisions relate
to those terms and conditions under Chapter 5, this
Chapter 6, Chapter 7A and jurisdictional electricity legislation
and are made under Chapter 5, this Chapter 6 and
Chapter 7A.
(3) Clause 6.22.2(b)(2)
omit
AEMO
insert
NTESMO
(4) Clause 6.22.2(c)(2)
omit
Chapters 4, 5, this Chapter 6 and Chapter 7 of the Rules
insert
Chapter 5, this Chapter 6, Chapter 7A and jurisdictional electricity
legislation
-- 95 of 290 --
Schedule 2 Further modifications to operation of National Electricity Rules
National Electricity (Northern Territory) (National Uniform Legislation) (Modification)
Regulations 2016 90
(5) Clause 6.22.2(c)(3)
omit, insert
(3) in relation to all terms and conditions of access (including
price) the decisions of the AER where those decisions relate
to those terms and conditions under Chapter 5, this
Chapter 6, Chapter 7A and jurisdictional electricity legislation
and are made under Chapter 5, this Chapter 6 and Chapter 7;
(6) Clause 6.22.2(d)(2)
omit
AEMO
insert
NTESMO
(7) Clause 6.22.2, at the end
insert
Note:
The terms and conditions of access in jurisdiction electricity legislation referred to
in paragraphs (a)(2) and (3) and (c)(2) and (3) will be terms and conditions that
correspond to matters set out in Chapter 4 of the Rules applying in other
participating jurisdictions. The application of those paragraphs will be revisited
as part of the phased implementation of the Rules in this jurisdiction.
77 Clause S6.1.1 modified
(1) Clause S6.1.1(6) and (7)
omit, insert
(5A) in the case of a building block proposal for a distribution
determination for a Distribution Network Service Provider in this
jurisdiction that will apply during the 1st regulatory control period:
(i) capital expenditure for each of the past years of the 2009-14
NT regulatory control period and 2014-19 NT regulatory
control period, and the expected capital expenditure for each
of the last 2 years of the 2014-19 NT regulatory control period,
categorised in the same way as for the capital expenditure
forecast and separately identifying for each such year:
-- 96 of 290 --
Schedule 2 Further modifications to operation of National Electricity Rules
National Electricity (Northern Territory) (National Uniform Legislation) (Modification)
Regulations 2016 91
(A) margins paid or expected to be paid by the Distribution
Network Service Provider in circumstances where those
margins are referable to arrangements that do not reflect
arm's length terms; and
(B) expenditure that should have been treated as operating
expenditure in accordance with the policy submitted
under paragraph (8) for that year; and
(ii) an explanation of any significant variations in the forecast
capital expenditure from capital expenditure in the 2009-14 NT
regulatory control period and 2014-19 NT regulatory control
period;
(5B) in the case of a building block proposal for a distribution
determination for a Distribution Network Service Provider in this
jurisdiction that will apply during the 2nd regulatory control period:
(i) capital expenditure for each of the past years of the 2014-19
NT regulatory control period and each of the past regulatory
years of the 1st regulatory control period, and the expected
capital expenditure for each of the last 2 regulatory years of
the 1st regulatory control period, categorised in the same way
as for the capital expenditure forecast and separately
identifying for each such year:
(A) margins paid or expected to be paid by the Distribution
Network Service Provider in circumstances where those
margins are referable to arrangements that do not reflect
arm's length terms; and
(B) expenditure that should have been treated as operating
expenditure in accordance with the policy submitted
under paragraph (8) for that year; and
(ii) an explanation of any significant variations in the forecast
capital expenditure from capital expenditure in the 2014–19
NT regulatory control period and 1st regulatory control period;
(6) in the case of a building block proposal for a distribution
determination for a Distribution Network Service Provider in this
jurisdiction that will apply after the 2nd regulatory control period –
capital expenditure for each of the past regulatory years of the
previous and current regulatory control period, and the expected
capital expenditure for each of the last 2 regulatory years of the
current regulatory control period, categorised in the same way as
for the capital expenditure forecast and separately identifying for
each such regulatory year:
-- 97 of 290 --
Schedule 2 Further modifications to operation of National Electricity Rules
National Electricity (Northern Territory) (National Uniform Legislation) (Modification)
Regulations 2016 92
(i) margins paid or expected to be paid by the Distribution
Network Service Provider in circumstances where those
margins are referable to arrangements that do not reflect
arm's length terms; and
(ii) expenditure that should have been treated as operating
expenditure in accordance with the policy submitted under
paragraph (8) for that regulatory year;
(7) in the case of a building block proposal for a distribution
determination for a Distribution Network Service Provider in this
jurisdiction that will apply after the 2nd regulatory control period –
an explanation of any significant variations in the forecast capital
expenditure from historical capital expenditure; and
(2) Clause S6.1.1, at the end
insert
Note:
The modifications to this clause expire on 1 July 2029.
78 Clause S6.1.2 modified
Clause S6.1.2(7) and (8)
omit, insert
(6A) in the case of a building block proposal for a distribution
determination for a Distribution Network Service Provider in this
jurisdiction that will apply during the 1st regulatory control period:
(i) operating expenditure for each of the past years of the
2009-14 NT regulatory control period and 2014-19 NT
regulatory control period, and the expected operating
expenditure for each of the last 2 years of the 2014-19 NT
regulatory control period, categorised in the same way as for
the operating expenditure forecast; and
(ii) an explanation of any significant variations in the forecast
operating expenditure from operating expenditure in the
2009-14 NT regulatory control period and 2014-19 NT
regulatory control period;
(6B) in the case of a building block proposal for a distribution
determination for a Distribution Network Service Provider in this
jurisdiction that will apply during the 2nd regulatory control period:
(i) operating expenditure for each of the past years of the
2014-19 NT regulatory control period and each of the past
-- 98 of 290 --
Schedule 2 Further modifications to operation of National Electricity Rules
National Electricity (Northern Territory) (National Uniform Legislation) (Modification)
Regulations 2016 93
regulatory years of the 1st regulatory control period, and the
expected operating expenditure for each of the last
2 regulatory years of the 1st regulatory control period,
categorised in the same way as for the operating expenditure
forecast; and
(ii) an explanation of any significant variations in the forecast
operating expenditure from operating expenditure in the
2014-19 NT regulatory control period and the 1st regulatory
control period;
(7) in the case of a building block proposal for a distribution
determination for a Distribution Network Service Provider in this
jurisdiction that will apply after the 2nd regulatory control period –
operating expenditure for each of the past regulatory years of the
previous and current regulatory control period, and the expected
operating expenditure for each of the last 2 regulatory years of the
current regulatory control period, categorised in the same way as
for the operating expenditure forecast;
(8) in the case of a building block proposal for a distribution
determination for a Distribution Network Service Provider in this
jurisdiction that will apply after the 2nd regulatory control period –
an explanation of any significant variations in the forecast operating
expenditure from historical operating expenditure.
Note:
The modifications to this clause expire on 1 July 2029.
79 Clause S6.2.1 modified
(2) Clause S6.2.1(a), at the end
insert
However, this clause does not apply to the establishment of the
value of the regulatory asset base for a distribution system in this
jurisdiction as at the beginning of the 1st regulatory control period.
Note:
See clause S6.2.3A for the establishment of the value of the regulatory asset
base for a distribution system in this jurisdiction as at the beginning of the 1st
regulatory control period. Also see rule 6.0(b)(2) for the treatment of distribution
systems in this jurisdiction for the purposes of this schedule.
(3) Clause S6.2.1(b)
omit
S6.2.2 and S6.2.3
-- 99 of 290 --
Schedule 2 Further modifications to operation of National Electricity Rules
National Electricity (Northern Territory) (National Uniform Legislation) (Modification)
Regulations 2016 94
insert
S6.2.3 and S6.2.3A
80 Clause S6.2.1 modified
After clause S6.2.1(e)(3)
insert
(3A) However, in calculating the value of the regulatory asset base
for a distribution system in this jurisdiction as at the beginning
of the first regulatory year of the 2nd regulatory control period,
the previous value of the regulatory asset base must be
adjusted for the difference between:
(i) the estimated capital expenditure for any part of the
2014-19 NT regulatory control period or 1st regulatory
control period where that estimated capital expenditure
has been included in that value; and
(ii) the actual capital expenditure for that part of the 2014-19
NT regulatory control period or 1st regulatory control
period.
This adjustment must also remove any benefit or penalty
associated with any difference between the estimated and
actual capital expenditure.
Note:
This subparagraph expires on 1 July 2029.
82 Clause S6.2.2A modified
After clause S6.2.2A(a1)
insert
(a2) However, for a decision on the regulatory asset base for a
distribution system in this jurisdiction as at the commencement of
the 2nd regulatory control period, review period means only the
previous control period (excluding the last 2 regulatory years of that
previous control period).
Note:
This paragraph expires on 1 July 2029.
-- 100 of 290 --
Schedule 2 Further modifications to operation of National Electricity Rules
National Electricity (Northern Territory) (National Uniform Legislation) (Modification)
Regulations 2016 95
83 Clause S6.2.2B modified
After clause S6.2.2B, heading
insert
Note:
Clause S6.2.2B(b) and (c) has no effect in this jurisdiction until 1 July 2019 (see
regulation 5A of the National Electricity (Northern Territory) (National Uniform
Legislation) (Modification) Regulations).
84 Clause S6.2.3A inserted
After clause S6.2.3
insert
S6.2.3A Establishment of opening regulatory asset base for
distribution system in this jurisdiction for 1st regulatory
control period
(a) Application of this clause
This clause applies to the establishment of the value of the
regulatory asset base for a distribution system in this jurisdiction as
at the beginning of the 1st regulatory control period.
(b) Roll forward model to comply with this clause
The values to be used for completing the roll forward model must
be established in accordance with this clause.
(c) Previous value of regulatory asset base for distribution system
in this jurisdiction
For paragraph (d), the previous value of the regulatory asset base
for all distribution systems in this jurisdiction that are owned,
controlled or operated by the Distribution Network Service Provider
mentioned in the table below is as set out in the table:
Jurisdiction Distribution Network
Service Provider
Regulatory Asset Base ($m)
Northern
Territory
Power and Water
Corporation
ABN 15 947 352 360
860.65 (as at 1 July 2014 in
July 2014 dollars)
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(d) Method of adjustment of value of regulatory asset base
The value of the regulatory asset base for the distribution systems
mentioned in paragraph (c) as at the beginning of the first
regulatory year of the 1st regulatory control period must be
calculated by adjusting the previous value (the previous value) of
the regulatory asset base for the distribution systems as specified in
paragraph (c) as follows:
(1) The previous value of the regulatory asset base must be:
(i) increased by the amount of all capital expenditure
incurred during the 2014-19 NT regulatory control period
(the previous control period), including any capital
expenditure determined for that period under
clause 3.2.4(d)(i)(A) of Part B of the 2014 NT Network
Price Determination where the Determination has been
amended under clause 3.2.4(d)(iii) of the Determination
(regardless of whether such capital expenditure is above
or below the forecast capital expenditure for the period
that is adopted for the purposes of the Determination (if
any) for that period); and
(ii) reduced by the amount of any capital expenditure that
has been recovered by way of a pass through under
clause 3.1 of Part B of the 2014 NT Network Price
Determination where the amount of that capital
expenditure would otherwise have been included in the
value of the regulatory asset base.
(2) The previous value of the regulatory asset base must be
increased by the amount of the estimated capital expenditure
approved by the Utilities Commission or AER for any part of
the previous control period for which actual capital expenditure
is not available.
(3) The previous value of the regulatory asset base must be
adjusted for the difference between:
(i) the estimated capital expenditure for any part of the
2009-14 NT regulatory control period or 2014-19 NT
regulatory control period where that estimated capital
expenditure has been included in that value; and
(ii) the actual capital expenditure for that part of the 2009-14
NT regulatory control period or 2014-19 NT regulatory
control period.
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This adjustment must also remove any benefit or penalty
associated with any difference between the estimated and
actual capital expenditure.
(4) The previous value of the regulatory asset base must only be
increased by estimated or actual capital expenditure to the
extent that all such capital expenditure is properly allocated to
the provision of NT equivalent services in accordance with the
Cost Allocation Methodology (as amended, varied or
substituted from time to time) that is the subject of the Utilities
Commission's final decision referred to in Chapter 5 of Part A
of the 2014 NT Network Price Determination.
(5) The previous value of the regulatory asset base must be
reduced by the amount of depreciation of the regulatory asset
base during the previous control period, calculated in
accordance with the 2014 NT Network Price Determination.
(6) The previous value of the regulatory asset base must be
reduced by the disposal value of any asset where that asset
has been disposed of during the previous control period.
(7) The previous value of the regulatory asset base must be
reduced by the value of an asset where the asset was
previously used to provide NT equivalent services but, as a
result of the classification of the asset under Part B, the asset
is not to be used to provide standard control services for the
1st regulatory control period.
(8) The previous value of the regulatory asset base may be
increased by the value of an asset to which this subparagraph
applies to the extent that:
(i) the AER considers the asset to be reasonably required
to achieve one or more of the capital expenditure
objectives; and
(ii) the value of the asset has not been otherwise recovered.
This subparagraph applies to an asset that:
(iii) was not used to provide NT equivalent services in the
previous control period but, as a result of a change to
the classification of a particular service under Part B, is
to be used to provide standard control services for the
1st regulatory control period; or
(iv) was never previously used to provide NT equivalent
services but is to be used to provide standard control
services for the 1st regulatory control period.
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(e) An increase or reduction in the value of the regulatory asset base
under paragraph (d)(7) or (8) is to be based on the portion of the
value of the asset properly allocated, or formerly properly allocated,
to NT equivalent services in accordance with the principles and
policies set out in the Cost Allocation Methodology (as amended,
varied or substituted from time to time) that is the subject of the
Utilities Commission's final decision referred to in Chapter 5 of
Part A of the 2014 NT Network Price Determination. The value of
the relevant asset is taken to be its value as shown in
independently audited and published accounts.
85 Chapters 6A and 6B modified
After Chapters 6A and 6B, headings
insert
Note:
This Chapter has no effect in this jurisdiction (see regulation 5A of the National
Electricity (Northern Territory) (National Uniform Legislation) (Modification)
Regulations). The application of this Chapter will be revisited as part of the
phased implementation of the Rules in this jurisdiction.
86 Chapter 7 modified
After Chapter 7, heading
insert
Note:
This Chapter has no effect in this jurisdiction but will take effect at a later date.
Chapter 7A applies in this jurisdiction from 1 July 2019 in substitution for this
Chapter.
Criteria for assessing when the transition to this Chapter will take effect will be
considered as part of the phased implementation of the Rules in this jurisdiction.
87 Chapter 7A inserted
After Chapter 7
insert
Chapter 7A Metering
Note
Chapter 7A applies in substitution for Chapter 7 (which establishes the metering
framework that applies in the other participating jurisdictions). Chapter 7A
operates as a transitional framework until Chapter 7 takes effect in this
jurisdiction.
Criteria for assessing when the transition to Chapter 7 will take effect will be
considered as part of the phased implementation of the Rules in this jurisdiction.
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The application of requirements in Chapter 7A relating to market and institutional
arrangements will also be considered as part of the phased implementation of the
Rules in this jurisdiction.
Part A Introduction
7A.1 Introduction to the Metering Chapter
7A.1.1 Purpose and application
This Chapter provides the framework for metering for local
electricity systems by establishing the requirements for metering
installations at connection points on transmission networks or
distribution networks.
7A.1.2 Contents
This Chapter sets out provisions relating to:
(a) roles and responsibilities of financially responsible
participants, Metering Coordinators, NTESMO and the Utilities
Commission relating to metering;
(b) the appointment of, and the qualifications and requirements
applying to, Metering Providers and Metering Data Providers;
(c) the appointment of Metering Coordinators;
(d) metering installation requirements;
(e) metering data services and the metering database;
(f) metering register requirements, the disclosure of NMI
information, and the provision of metering data to retail
customers;
(g) security of, and rights to access, metering installations,
services provided by metering installations, energy data held
in metering installations and metering data from metering
installations; and
(h) relevant metering procedures.
7A.1.3 Definitions
In this Chapter:
actual meter reading means the collection of energy data from a
metering installation by local access or remote acquisition.
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data stream means a stream of metering data associated with a
connection point, as represented by a NMI. A NMI may have
multiple data streams (for example, from one or more meters, or
one or more channels or registers that comprise a single meter).
Each data stream is identified by a unique suffix associated with the
NMI to which it belongs.
financially responsible participant means a person who is
financially responsible for a connection point.
MDFF Specification means:
(a) the Metering Data File Format Specification published by
NTESMO in a communication guideline under clause S7A.1.3;
or
(b) if no Metering Data File Format Specification is published by
NTESMO – the Metering Data File Format Specification NEM
12 and NEM 13, published by AEMO, with an effective date of
1 May 2022 (version 2.5).
Metering Data File Format means metering data that is in a form
that complies with the MDFF Specification.
metering provision services means the provision, installation and
maintenance of metering installations.
prepayment device means a metering installation that requires a
prepayment for the supply of electricity prior to consumption.
scheduled meter reading means an actual meter reading
performed in accordance with the usual reading cycle for the meter.
special meter reading means an actual meter reading performed
outside of the usual reading cycle for the meter.
vending services means, for a metering installation at a
connection point that is a prepayment device, services that allow
the financially responsible participant to sell electricity that will flow
through the prepayment device in the future for consumption, and
to receive payment in advance for selling that electricity.
Note
The following are examples of vending services:
(a) services for prepayments made by credit card through a website or app, or
over the telephone;
(b) services for prepayments made in person by cash or credit card to purchase
a physical token or unique code that must be entered into a prepayment
device.
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7A.1.4 Inconsistency
(a) If there is an inconsistency between substantive Chapter 7A and
the schedules to this Chapter, substantive Chapter 7A prevails to
the extent of the inconsistency.
(b) In this clause:
substantive Chapter 7A means this Chapter other than the
schedules to this Chapter.
Note
To the extent that there is an inconsistency between the Rules and the National
Measurement Act, the Act prevails to the extent of the inconsistency: see
Rule 1.7.1A.
Part B Roles and Responsibilities
7A.2 Role and responsibility of financially responsible
participant
(a) Before participating in a market in respect of a connection point,
and for so long as the financially responsible participant continues
to participate in a market, the financially responsible participant for
a connection point must ensure that:
(1) a Metering Coordinator is appointed in respect of the
connection point in accordance with Part C of this Chapter;
(2) the connection point has a metering installation and
information about the metering installation is provided to
NTESMO for inclusion on the metering register, where this is
required by clause 7A.10.1;
(3) a NMI has been obtained with respect to the connection point;
and
(4) if information about the metering installation is required to be
provided to NTESMO for inclusion on the metering register by
clause 7A.10.1, the NMI is obtained prior to that information
being provided to NTESMO.
Note
This provision is classified as a civil penalty provision under the National
Electricity (NT) Regulations. (See regulation 6(1) and Schedule 1 of the National
Electricity (NT) Regulations.)
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(b) NTESMO may refuse to permit a financially responsible participant
to participate in a market in respect of a connection point used for
the purposes of settlements if the financially responsible participant
is not compliant with its obligation under paragraph (a) with respect
to the connection point.
(c) Where, following a request made by a financially responsible
participant in accordance with clause 7A.6.14, the metering
installation at a connection point is a prepayment device, the
financially responsible participant is responsible for ensuring that an
arrangement for vending services is in place.
7A.3 Role and responsibility of Metering Coordinator
7A.3.1 Responsibility of the Metering Coordinator
For the term of its appointment in respect of a connection point, the
Metering Coordinator is the person responsible for:
(a) the provision, installation and maintenance of a metering
installation at the connection point in accordance with Part D
of this Chapter;
(b) the collection of metering data with respect to the metering
installation, the processing of that data, the retention of that
data in the metering data services database and the delivery
of that data to the metering database and other persons in
accordance with Part E of this Chapter; and
(c) managing the security of and access to:
(1) the metering installation;
(2) services provided by the metering installation;
(3) energy data held in the metering installation; and
(4) metering data from the metering installation,
in accordance with Part F of this Chapter.
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7A.3.2 Role of the Metering Coordinator
Appointment of a Metering Provider
(a) The Metering Coordinator at a connection point, other than a
connection point with a type 7 metering installation, must appoint a
person who is accredited to provide metering provision services in
this jurisdiction to be the Metering Provider to provide metering
provision services for the connection point.
Note
This provision is classified as a civil penalty provision under the National
Electricity (NT) Regulations. (See regulation 6(1) and Schedule 1 of the National
Electricity (NT) Regulations.)
Appointment of a Metering Data Provider
(b) The Metering Coordinator at a connection point must appoint a
person who is accredited to provide metering data services in this
jurisdiction to be the Metering Data Provider to provide metering
data services for the connection point.
Note
This provision is classified as a civil penalty provision under the National
Electricity (NT) Regulations. (See regulation 6(1) and Schedule 1 of the National
Electricity (NT) Regulations.)
Metering installations
(c) The Metering Coordinator at a connection point, other than a
connection point with a type 7 metering installation, must ensure
that:
(1) the metering installation is provided, installed and maintained
in accordance with the Rules;
(2) the components, accuracy and testing of the metering
installation comply with the requirements of the Rules;
(3) the security control of the metering installation is provided in
accordance with rule 7A.13;
(4) if remote acquisition is used or is to be used – a
communications interface is installed and maintained to
facilitate connection to the telecommunications network;
(5) NTESMO is provided (when requested) with any information
required for the purposes of Schedule 7A.1 for any new or
replacement metering installation or any altered metering
installation; and
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(6) the Metering Provider it appoints for the connection point
complies with the obligations imposed on Metering Providers
by this Chapter.
(d) A Metering Coordinator must not prevent, hinder or otherwise
impede the Local Network Service Provider from locally accessing
a metering installation or connection point for the purposes of
reconnecting or disconnecting the connection point.
Note
This provision is classified as a civil penalty provision under the National
Electricity (NT) Regulations. (See regulation 6(1) and Schedule 1 of the National
Electricity (NT) Regulations.)
Metering data services
(e) The Metering Coordinator at a connection point must:
(1) ensure that the Metering Data Provider it appoints for the
connection point complies with the obligations imposed on
Metering Data Providers by this Chapter;
(2) ensure that metering data services are provided in accordance
with the Rules; and
(3) arrange for the provision of relevant metering data to the
Metering Data Provider if remote acquisition, if any, becomes
unavailable.
Note
This provision is classified as a civil penalty provision under the National
Electricity (NT) Regulations. (See regulation 6(1) and Schedule 1 of the National
Electricity (NT) Regulations.)
Access to type 4 metering installations
(f) The Metering Coordinator at a connection point with a type 4
metering installation:
(1) must ensure that access to the metering installation, the
services provided by the metering installation and energy data
held in the metering installation is only granted to persons
entitled to access the metering installation, or the services
provided by the metering installation or energy data held in the
metering installation, in accordance with this Chapter;
(2) must not arrange a disconnection except:
(i) on the request of the financially responsible participant
or Local Network Service Provider;
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(ii) where the disconnection is effected via remote access;
and
(iii) in accordance with jurisdictional electricity legislation;
(3) must not arrange a reconnection except:
(i) on the request of the financially responsible participant,
Local Network Service Provider or incoming retailer;
(ii) where the reconnection is effected via remote access;
and
(iii) in accordance with jurisdictional electricity legislation;
and
(4) must not arrange a retailer planned interruption of the supply
of electricity at the metering installation except:
(i) on the request of the retailer; and
(ii) in accordance with jurisdictional electricity legislation.
Note
This provision is classified as a civil penalty provision under the National
Electricity (NT) Regulations. (See regulation 6(1) and Schedule 1 of the National
Electricity (NT) Regulations.)
7A.4 Qualification and requirements of Metering
Providers and Metering Data Providers
7A.4.1 Metering Providers
(a) A Metering Provider must have an ISO 9000 series quality system
in place.
(b) For a connection point in respect of which a type 1, 2 or 3 metering
installation is installed, or is required to be installed under this
Chapter:
(1) the Local Network Service Provider is taken to be accredited
to provide metering provision services in this jurisdiction
(including the services mentioned in the schedules in respect
of which a Metering Provider requires accreditation); and
(2) the Metering Coordinator at the connection point is taken to
have appointed the Local Network Service Provider as the
Metering Provider for the connection point.
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(c) For a connection point in respect of which a type 4, 4A, 5 or 6
metering installation is installed, or is required to be installed under
this Chapter:
(1) the Local Network Service Provider is taken to be accredited
to provide metering provision services in this jurisdiction
(including the services mentioned in the schedules in respect
of which a Metering Provider requires accreditation); and
(2) the Metering Coordinator at the connection point is taken to
have appointed the Local Network Service Provider as the
Metering Provider for the connection point.
(d) A Metering Provider may, in providing metering provision services
under this Chapter, contract with another person to assist it in the
provision of those services, if that person meets all relevant safety
and technical requirements in any applicable regulatory instruments
or other relevant law.
7A.4.2 Metering Data Providers
(a) A Metering Data Provider must have an ISO 9000 series quality
system in place.
(b) For a connection point in respect of which a type 1, 2 or 3 metering
installation is installed, or is required to be installed under this
Chapter:
(1) the Local Network Service Provider is taken to be accredited
to provide metering data services in this jurisdiction (including
the services mentioned in the schedules in respect of which a
Metering Data Provider requires accreditation); and
(2) the Metering Coordinator at the connection point is taken to
have appointed the Local Network Service Provider as the
Metering Data Provider for the connection point.
(c) For a connection point in respect of which a type 4, 4A, 5, 6 or 7
metering installation is installed, or is required to be installed under
this Chapter:
(1) the Local Network Service Provider is taken to be accredited
to provide metering data services in this jurisdiction (including
the services mentioned in the schedules in respect of which a
Metering Data Provider requires accreditation); and
(2) the Metering Coordinator at the connection point is taken to
have appointed the Local Network Service Provider as the
Metering Data Provider for the connection point.
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(d) A Metering Data Provider may, in providing metering data services
under this Chapter, contract with another person to assist it in the
provision of those services, if that person meets all relevant safety
and technical requirements in any applicable regulatory instrument
or other relevant law.
Part C Appointment of Metering Coordinator
7A.5 Appointment of Metering Coordinator
(b) For a connection point in respect of which a type 1, 2 or 3 metering
installation is installed, or is required to be installed under this
Chapter, the financially responsible participant for the connection
point is taken to have appointed the Local Network Service Provider
as the Metering Coordinator for the connection point.
(c) For a connection point in respect of which a type 4, 4A, 5 or 6
metering installation is installed, or is required to be installed under
this Chapter, the financially responsible participant for the
connection point is taken to have appointed the Local Network
Service Provider as the Metering Coordinator for the connection
point.
(d) For a connection point with a type 7 metering installation, the
financially responsible participant for the connection point is taken
to have appointed the Local Network Service Provider as the
Metering Coordinator for the connection point.
Part D Metering installation
7A.6 Metering installation arrangement
7A.6.1 Metering installation requirements
(a) The Metering Coordinator at a connection point must ensure that
there is a metering installation at that connection point.
Note
This provision is classified as a civil penalty provision under the National
Electricity (NT) Regulations. (See regulation 6(1) and Schedule 1 of the National
Electricity (NT) Regulations.)
(b) The Metering Coordinator at a connection point must ensure that
energy data held in the metering installation is based on units of
watthour (active energy) and where required varhour (reactive
energy).
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(c) Installation and maintenance of a metering installation must be
carried out in a safe manner, and only by a Metering Provider
appointed under clause 7A.3.2.
Note
This provision is classified as a civil penalty provision under the National
Electricity (NT) Regulations. (See regulation 6(1) and Schedule 1 of the National
Electricity (NT) Regulations.)
7A.6.2 Metering installation components
(a) A Metering Provider must, in accordance with the Rules, ensure
that a metering installation, other than a type 7 metering installation:
(1) contains a device that has either a visible or an equivalently
accessible display of the cumulative total energy measured by
that metering installation (at a minimum);
Note
This provision is classified as a civil penalty provision under the National
Electricity (NT) Regulations. (See regulation 6(1) and Schedule 1 of the National
Electricity (NT) Regulations.)
(2) is accurate in accordance with clause 7A.6.6;
Note
This provision is classified as a civil penalty provision under the National
Electricity (NT) Regulations. (See regulation 6(1) and Schedule 1 of the National
Electricity (NT) Regulations.)
(3) in the case of a type 1, 2, 3 or 4 metering installation – has
electronic data transfer facilities from the metering installation
to the metering data services database;
Note
This provision is classified as a civil penalty provision under the National
Electricity (NT) Regulations. (See regulation 6(1) and Schedule 1 of the National
Electricity (NT) Regulations.)
(4) includes a communications interface to meet the requirements
of clause 7A.3.2(c)(4);
Note
This provision is classified as a civil penalty provision under the National
Electricity (NT) Regulations. (See regulation 6(1) and Schedule 1 of the National
Electricity (NT) Regulations.)
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(5) is secure in accordance with rule 7A.9;
Note
This provision is classified as a civil penalty provision under the National
Electricity (NT) Regulations. (See regulation 6(1) and Schedule 1 of the National
Electricity (NT) Regulations.)
(6) records energy data in a manner that enables metering data to
be collated in accordance with clause 7A.8.6;
Note
This provision is classified as a civil penalty provision under the National
Electricity (NT) Regulations. (See regulation 6(1) and Schedule 1 of the National
Electricity (NT) Regulations.)
(7) is capable of separately recording energy data for energy
flows in each direction where bi-directional active energy flows
occur or could occur;
Note
This provision is classified as a civil penalty provision under the National
Electricity (NT) Regulations. (See regulation 6(1) and Schedule 1 of the National
Electricity (NT) Regulations.)
(8) has a measurement element for active energy and, if required
in accordance with schedule 7A.4, a measurement element for
reactive energy, with both measurements to be recorded;
Note
This provision is classified as a civil penalty provision under the National
Electricity (NT) Regulations. (See regulation 6(1) and Schedule 1 of the National
Electricity (NT) Regulations.)
(9) includes facilities for storing interval energy data for a period
of at least 35 days if the metering installation is a type 1, 2, 3
or 4 metering installation;
Note
This provision is classified as a civil penalty provision under the National
Electricity (NT) Regulations. (See regulation 6(1) and Schedule 1 of the National
Electricity (NT) Regulations.)
(10) includes facilities for storing interval energy data for a period
of at least 200 days or such other period as specified in
schedule 7A.7 if the metering installation is a type 4A or 5
metering installation;
Note
This provision is classified as a civil penalty provision under the National
Electricity (NT) Regulations. (See regulation 6(1) and Schedule 1 of the National
Electricity (NT) Regulations.)
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(11) in the case of a type 6 metering installation, includes facilities
capable of continuously recording the total accumulated
energy supplied through it by a visible display in accordance
with subparagraph (1), over a period of at least 12 months;
and
Note
This provision is classified as a civil penalty provision under the National
Electricity (NT) Regulations. (See regulation 6(1) and Schedule 1 of the National
Electricity (NT) Regulations.)
(12) is suitable for the range of operating conditions to which it will
be exposed (for example temperature or impulse levels) and
operates within the defined limits for its components.
(b) A metering installation may consist of combinations of:
(1) a current transformer;
(2) a voltage transformer;
(3) secure and protected wiring from the current transformer and
the voltage transformer to the meter;
(4) communications interface equipment such as a modem,
isolation requirements, telephone service, radio transmitter
and data link equipment;
(5) auxiliary electricity supply to the meter;
(6) an alarm circuit and monitoring facility;
(7) a facility to keep the metering installation secure from
interference;
(8) test links and fusing;
(9) summation equipment; and
(10) several metering points to derive the metering data for a
connection point.
(c) The Local Network Service Provider or financially responsible
participant may, with the agreement of the Metering Coordinator
(which agreement must not be unreasonably withheld), arrange for
a metering installation to contain features which are in addition to,
or which enhance, the features specified in paragraph (b).
(d) The financially responsible participant for a connection point must:
(1) apply to the Local Network Service Provider for a NMI; and
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(2) provide the Metering Coordinator at the connection point with
the NMI for the metering installation within 5 business days of
receiving the NMI from the Local Network Service Provider.
(e) The Local Network Service Provider must:
(1) issue a unique NMI for each metering installation on its
network to the financially responsible participant; and
(2) provide information about the NMI to NTESMO, where this is
required for the purposes of clause 7A.10.1.
Note
This provision is classified as a civil penalty provision under the National
Electricity (NT) Regulations. (See regulation 6(1) and Schedule 1 of the National
Electricity (NT) Regulations.)
(f) The Metering Coordinator must ensure that NTESMO is provided
with the relevant details of the metering installation as specified in
Schedule 7A.1 within 10 business days of receiving the NMI under
paragraph (d)(2), where this is required for the purposes of
clause 7A.10.1.
Note
This provision is classified as a civil penalty provision under the National
Electricity (NT) Regulations. (See regulation 6(1) and Schedule 1 of the National
Electricity (NT) Regulations.)
(g) Where a metering installation is used for operational purposes in
addition to metrological purposes, the Metering Coordinator must:
(1) use reasonable endeavours to ensure that there will be no
infringement of the requirements of the Rules; and
(2) co-ordinate with the persons who use the metering installation
for such other purposes.
7A.6.3 Emergency management
Note
Emergency management will be considered as part of the phased
implementation of the Rules in this jurisdiction.
7A.6.4 Network devices
Note
Network devices will be considered as part of the phased implementation of the
Rules in this jurisdiction.
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7A.6.5 Metering point
(a) The Metering Coordinator at a connection point must ensure that:
(1) the metering point is located as close as practicable to the
connection point, but is in a position that allows safe and
unimpeded access to the metering installation by the Metering
Provider, Metering Data Provider and any other person
required or permitted to have access to the metering
installation under the Rules or any other law; and
Note
This provision is classified as a civil penalty provision under the National
Electricity (NT) Regulations. (See regulation 6(1) and Schedule 1 of the National
Electricity (NT) Regulations.)
(2) any instrument transformers required for a check metering
installation are located in a position that achieves a
mathematical correlation with the metering data.
Note
This provision is classified as a civil penalty provision under the National
Electricity (NT) Regulations. (See regulation 6(1) and Schedule 1 of the National
Electricity (NT) Regulations.)
(b) The financially responsible participant, the Local Network Service
Provider and NTESMO must use their best endeavours to agree to
adjust the metering data which is recorded in the metering
database to allow for physical losses between the metering point
and the relevant connection point where a meter is used to
measure the flow of electricity in a power conductor.
7A.6.6 Metering installation types and accuracy
(a) The type of metering installation and the accuracy requirements for
a metering installation are to be determined in accordance with
schedule 7A.4.
Note
This Chapter 7A makes provision for type 7 metering installations and imposes
requirements on type 7 metering installations, including obligations about
calculating metering data. Those obligations will only apply in this jurisdiction in
the event of a type 7 metering installation being available in this jurisdiction and
after a 12 month transitional period allowing all participants to achieve
compliance.
(b) A check metering installation is not required to have the degree of
accuracy required of a metering installation but the Metering
Coordinator must ensure that it has mathematical correlation with
the metering installation and complies with the requirements of
schedule 7A.4.
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(c) The Metering Coordinator at a connection point must ensure that
the accuracy of a type 6 metering installation is in accordance with
regulations issued under the National Measurement Act or, in the
absence of any such regulations, with schedule 7A.7.
Note
This provision is classified as a civil penalty provision under the National
Electricity (NT) Regulations. (See regulation 6(1) and Schedule 1 of the National
Electricity (NT) Regulations.)
7A.6.7 Functionality requirements for type 1, 2, 3 and 4 metering
installations
(a) This clause applies in respect of a type 1, 2, 3 or 4 metering
installation.
(b) The Metering Coordinator at a connection point must ensure that
the metering installation complies with the functionality
requirements specified in schedule 7A.5.
7A.6.8 Meter churn
(a) A Metering Coordinator may arrange to alter a type 5 or 6 metering
installation to make it capable of remote acquisition if:
(1) the alteration is reasonably required to address operational
difficulties; or
(2) the Metering Coordinator is the Local Network Service
Provider and the alteration is reasonably required to enable
the Local Network Service Provider to meet its obligations to
provide a safe, reliable and secure network.
(b) An alteration of a metering installation by a Metering Coordinator in
accordance with paragraph (a) does not alter the classification of
that installation to a type 4 or 4A metering installation.
(c) For paragraph (a)(1), operational difficulties arise if the metering
installation is difficult or unsafe to access because:
(1) it is on a remote property;
(2) it is within a secure facility;
(3) it is in close proximity to hazardous materials; or
(4) accessing or arranging access to it otherwise poses a risk to
the safety and security of persons or property.
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7A.6.9 Metering installation malfunctions
(a) Unless an exemption is obtained by the Metering Coordinator from
NTESMO under this clause 7A.6.9, the Metering Coordinator must,
if a metering installation malfunction occurs in respect of a
connection point with a type 1, 2 or 3 metering installation, cause
repairs to be made to the metering installation as soon as
practicable but no later than 2 business days after the Metering
Coordinator had been notified of the metering installation
malfunction.
Note
This provision is classified as a civil penalty provision under the National
Electricity (NT) Regulations. (See regulation 6(1) and Schedule 1 of the National
Electricity (NT) Regulations.)
(b) Unless an exemption is obtained by the Metering Coordinator from
NTESMO under this clause 7A.6.9, if a metering installation
malfunction occurs, the Metering Coordinator must, in respect of a
connection point with:
(1) a type 4 metering installation – cause repairs to be made to
the metering installation as soon as practicable but no later
than 10 business days after the Metering Coordinator has
been notified of the metering installation malfunction; or
(2) a metering installation other than the installations mentioned in
paragraph (a) or subparagraph (1) – cause repairs to be made
to the metering installation as soon as practicable but no later
than 10 business days after the Metering Coordinator has
been notified of the metering installation malfunction.
(c) NTESMO must establish, maintain and publish a procedure
applicable to the provision of exemptions for the purposes of
paragraphs (a) and (b).
(d) If an exemption is provided by NTESMO under this clause 7A.6.9,
then the Metering Provider must provide NTESMO with a plan for
the rectification of the metering installation.
Note
This provision is classified as a civil penalty provision under the National
Electricity (NT) Regulations. (See regulation 6(1) and Schedule 1 of the National
Electricity (NT) Regulations.)
(e) A Registered Participant, Metering Provider or Metering Data
Provider who becomes aware of a metering installation malfunction
that cannot be rectified within the applicable timeframes as
specified in paragraphs (a) and (b) must notify the Metering
Coordinator of the metering installation malfunction within 1
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business day.
Note
This provision is classified as a civil penalty provision under the National
Electricity (NT) Regulations. (See regulation 6(1) and Schedule 1 of the National
Electricity (NT) Regulations.)
7A.6.10 Timeframes for meters to be installed – new connection
(a) Subject to paragraph (b), where a new connection is requested at a
retail customer's premises, the relevant retailer must arrange a
meter to be installed:
(1) by a date agreed with the retail customer; or
(2) failing agreement with the retail customer, on a date no later
than 6 business days from the date the retailer is informed that
the connection service (as defined in clause 5A.A.1) is
complete.
(b) The timeframe under paragraph (a)(1) or (2) (as applicable) will not
apply where:
(1) the retail customer has not entered into an agreement with the
retailer for the meter to be installed;
(2) the proposed site for the meter at the retail customer's
premises is not accessible or safe or ready for the meter to be
installed, or the connection service (as defined in
clause 5A.A.1) has not been completed; or
(3) installing the meter requires interrupting supply to another
retail customer.
(c) Subject to the reapplication of paragraph (b), on and from the date
that an exception under paragraph (b) ceases to apply, the retailer
must arrange for the meter to be installed:
(1) by a new date agreed with the retail customer; or
(2) failing agreement, on a date no later than 5 business days
from the date that the exception ceases to apply.
(d) A retailer must inform its retail customers of its obligations under
this clause.
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7A.6.11 Timeframes for meters to be installed – where a connection
service is not required
(a) Subject to paragraph (b), if a retail customer has requested the
retailer to install a meter at the customer's premises and a
connection service (as defined in clause 5A.A.1) is not required, the
retailer must arrange for the meter to be installed:
(1) by a date agreed with the retail customer; or
(2) failing agreement with the retail customer, on a date no later
than 15 business days after the retailer received the request
from the retail customer for the meter to be installed.
(b) The timeframe under paragraph (a)(1) or (2) (as applicable) will not
apply where:
(1) the retail customer has not entered into an agreement with the
retailer for the meter to be installed;
(2) the proposed site for the meter at the retail customer's
premises is not accessible, safe, or ready for the meter to be
installed; or
(3) installing the meter requires interrupting supply to another
retail customer.
(c) Subject to the reapplication of paragraph (b), on and from the date
that an exception under paragraph (b) ceases to apply, the retailer
must arrange for the meter to be installed:
(1) by a new date agreed with the retail customer; or
(2) failing agreement, on a date no later than 15 business days
from the date that the exception ceases to apply.
(d) For the avoidance of doubt, the timeframes for meters to be
installed under this rule 7A.6.11 do not apply for a retailer initiated
installation of a meter, or for a new connection.
(e) A retailer must inform its retail customers of its obligations under
this clause.
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7A.6.12 Timeframes for meters to be installed – where a connection
alteration is required
(a) Subject to paragraph (b), if a retail customer has requested a meter
to be installed at the customer's premises and a connection
alteration is also required:
(1) the retailer must arrange for the meter to be installed:
(i) by a date agreed with the retail customer and the
Distribution Network Service Provider where the
Distribution Network Service Provider is providing the
connection alteration; or
(ii) failing agreement, on a date no later than 15 business
days after the retailer received the request from the retail
customer for the meter to be installed; and
(2) where a Distribution Network Service Provider is providing the
connection alteration, the Distribution Network Service
Provider must co-ordinate the connection alteration, with the
retailer and other relevant parties, in order to allow the retailer
to comply with its obligation under subparagraph (1).
(b) The timeframe under paragraph (a)(1) (i) or (ii) (as applicable) will
not apply where:
(1) the retail customer has not entered into an agreement with the
retailer for the meter to be installed;
(2) the proposed site for the meter at the retail customer's
premises is not accessible, safe, or ready for the meter to be
installed;
(3) installing the meter requires interrupting supply to another
retail customer;
(4) the retail customer has not met the conditions that it is
required to comply with under its connection contract; or
(5) augmentation is required for the purposes of the connection
alteration and has not yet been completed.
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(c) Subject to the reapplication of paragraph (b), on and from the date
that an exception under paragraph (b) ceases to apply:
(1) the retailer must arrange for the meter to be installed:
(i) by a new date agreed with the retail customer and the
Distribution Network Service Provider where the
Distribution Network Service Provider is providing the
connection alteration; or
(ii) failing agreement, on a date no later than 15 business
days from the date that the exception ceases to apply;
and
(2) where a Distribution Network Service Provider is providing the
connection alteration, it must co-ordinate the connection
alteration, with the retailer and other relevant parties, in order
to allow the retailer to meet its obligation under
subparagraph (1).
(d) If the retailer receives a request from a retail customer for a meter
to be installed at the customer's premises where a connection
alteration is also required, the retailer must inform the Distribution
Network Service Provider of the request no later than the next
business day after receiving the request.
(e) For the avoidance of doubt, the timeframes for meters to be
installed under this rule 7A.6.12 do not apply for a retailer initiated
installation of a meter, or for a new connection.
(f) A retailer must inform its retail customers of its obligations under
this clause.
7A.6.13 Changing a metering installation
(a) Subject to this clause, nothing in these Rules prevents the
financially responsible participant (on its own behalf or, in the case
of a retailer, on its own behalf or on behalf of a retail customer) or
Network Service Provider in respect of a connection point from
requesting the Metering Coordinator to arrange for:
(1) the alteration of the metering installation at that connection
point; or
(2) the installation of a new metering installation at that
connection point.
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(b) The incremental costs of the alteration of the metering installation
or the installation of the new metering installation must be borne by
the person who requests the alteration of the metering installation
or the installation of the new metering installation.
(c) The Metering Coordinator at a connection point must ensure that
changes to parameters or settings within a metering installation are:
(1) implemented by a Metering Provider; and
Note
This provision is classified as a civil penalty provision under the National
Electricity (NT) Regulations. (See regulation 6(1) and Schedule 1 of the National
Electricity (NT) Regulations.)
(2) confirmed by the Metering Coordinator within 2 business days
after the alteration has been made; and
Note
This provision is classified as a civil penalty provision under the National
Electricity (NT) Regulations. (See regulation 6(1) and Schedule 1 of the National
Electricity (NT) Regulations.)
(3) reported to NTESMO where required to enable NTESMO to
record the changes in the metering register in accordance with
clause 7A.10.2.
Note
This provision is classified as a civil penalty provision under the National
Electricity (NT) Regulations. (See regulation 6(1) and Schedule 1 of the National
Electricity (NT) Regulations.)
7A.6.14 Prepayment metering
(a) This clause applies if, in accordance with clause 7A.6.13, the
financially responsible participant in respect of a connection point
requests the Metering Coordinator to arrange for:
(1) the alteration of a metering installation so that it is a
prepayment device; or
(2) the installation of a new metering installation that is a
prepayment device.
(b) The Metering Coordinator must ensure that the Metering Provider:
(1) alters the metering installation so that it is a prepayment
device, if so requested; or
(2) installs a new metering installation that is a prepayment
device, if so requested.
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7A.7 Maintenance, inspection, testing and auditing of
metering installations
7A.7.1 Maintenance
The Metering Coordinator for a connection point must ensure that
any maintenance (including inspection and testing) of a metering
installation at the connection point is carried out in a safe manner
by an appropriately qualified person.
7A.7.2 Responsibility for inspection and testing
(a) The Metering Coordinator for a connection point must ensure that
any inspection or testing of a metering installation at the connection
point is carried out in a safe manner by an appropriately qualified
person.
(b) A person who arranges or carries out an inspection or testing of a
metering installation under this clause must do so in accordance
with:
(1) this clause; and
(2) the relevant inspection and testing requirements set out in
schedule 7A.6.
Note
This provision is classified as a civil penalty provision under the National
Electricity (NT) Regulations. (See regulation 6(1) and Schedule 1 of the National
Electricity (NT) Regulations.)
(c) A Registered Participant may request that the Metering Coordinator
make arrangements for the testing of a metering installation and, if
the request is reasonable, the Metering Coordinator:
(1) must not refuse the request; and
(2) must make arrangements for the testing.
(d) The Registered Participant who requested the testing under
paragraph (c) may make a request to the Metering Coordinator to
witness the tests.
(e) The Metering Coordinator must not refuse a request received under
paragraph (d) and must, no later than 5 business days prior to the
testing, advise:
(1) the party making the request; and
(2) the financially responsible participant,
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of:
(3) the location and time of the tests; and
(4) the method of testing to be undertaken.
Note
This provision is classified as a civil penalty provision under the National
Electricity (NT) Regulations. (See regulation 6(1) and Schedule 1 of the National
Electricity (NT) Regulations.)
(f) If the Metering Coordinator has arranged testing of a metering
installation under this clause and schedule 7A.6, the Metering
Coordinator must:
(1) inform the financially responsible participant that testing has
been undertaken in respect of the metering installation in
accordance with this clause; and
(2) make the test results available in accordance with
paragraphs (g) and (h).
(g) If the test results mentioned in paragraph (f) indicate deviation from
the technical requirements for the metering installation, the
Metering Coordinator must ensure that the test results are provided
as soon as practicable to the persons who receive the metering
data for the metering installation under clause 7A.8.4.
Note
This provision is classified as a civil penalty provision under the National
Electricity (NT) Regulations. (See regulation 6(1) and Schedule 1 of the National
Electricity (NT) Regulations.)
(h) If the test results mentioned in paragraph (f) indicate compliance
with the technical requirements for the metering installation, the
Metering Coordinator must ensure that the test results are provided
as soon as practicable:
(1) in circumstances where the tests were requested by a
Registered Participant, to the Registered Participant and
persons who receive the metering data for the metering
installation under clause 7A.8.4; or
(2) to a Registered Participant if requested by that Registered
Participant, if the tests are not the result of a request for
testing.
Note
This provision is classified as a civil penalty provision under the National
Electricity (NT) Regulations. (See regulation 6(1) and Schedule 1 of the National
Electricity (NT) Regulations.)
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(i) The Utilities Commission may check the test results recorded in the
metering register by arranging for audits of metering installations to
satisfy itself and NTESMO that the accuracy of each metering
installation complies with the requirements of this Chapter 7A.
(j) The Metering Coordinator must store the test results in accordance
with clause 7A.7.7 and provide a copy to the Utilities Commission
on request or as part of an audit.
(k) The cost of any testing under paragraph (c) must be borne by:
(1) if paragraph (g) applies – the Metering Coordinator; or
(2) otherwise – the Registered Participant who requested the test.
7A.7.3 Actions in event of non-compliance
(a) If the accuracy of the metering installation does not comply with the
requirements of the Rules, the Metering Coordinator must:
(1) advise NTESMO as soon as practicable of the errors detected
and the possible duration of the existence of the errors;
(2) arrange for the accuracy of the metering installation to be
restored within:
(i) 10 business days; or
(ii) if a timeframe is agreed with the financially responsible
participant, in that timeframe; and
(3) correct the metering data and provide the corrected metering
data to NTESMO.
Note
This provision is classified as a civil penalty provision under the National
Electricity (NT) Regulations. (See regulation 6(1) and Schedule 1 of the National
Electricity (NT) Regulations.)
(b) NTESMO may make appropriate corrections to the metering data to
take account of errors referred to it under paragraph (a) for the
purposes of settlements.
7A.7.4 Audits of information held in metering installations
(a) The Utilities Commission is responsible for auditing metering
installations.
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(b) A Registered Participant or NTESMO may request the Utilities
Commission to conduct an audit to determine the consistency
between the data held in the metering database and the data held
in the relevant metering installation.
(c) If there are inconsistencies between data held in a metering
installation and data held in the metering database, the Metering
Coordinator and Registered Participants with a financial interest in
the metering installation or the energy measured by the metering
installation must liaise together to determine the most appropriate
way to resolve the discrepancy.
(d) If there are inconsistencies between data held in a metering
installation and data held in the metering database, the data held in
the metering installation is to be taken as prima facie evidence of
the connection point's energy data, except if the meter or
components of the metering installation are found to be non-
compliant with the Rules.
(e) The cost of any audit conducted under paragraph (b) will be borne
by:
(1) if paragraph (c) applies, the Metering Coordinator; or
(2) otherwise, the Registered Participant who requested the audit
or NTESMO, as the case may be.
7A.7.5 Appointment of external auditor
(a) The Utilities Commission may, upon reasonable notice to the
Metering Coordinator, appoint an independent auditor to audit
metering installations to confirm compliance with the Rules.
(b) If the Utilities Commission appoints an independent auditor under
paragraph (a):
(1) the Utilities Commission will nominate the standards and
requirements and the auditor will report in accordance with
those standards and requirements; and
(2) the Metering Coordinator must cooperate with any reasonable
requests made by the independent auditor in undertaking the
audit.
(c) The Utilities Commission will provide a copy of the auditor's report
to:
(1) the Metering Coordinator;
(2) NTESMO; and
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(3) the relevant financially responsible participant,
as soon as reasonably possible after it has been completed.
(d) The Metering Coordinator must ensure that the Utilities
Commission (or its agents) have unrestricted access to metering
installations for the purpose of carrying out external audits provided
that the Utilities Commission agrees to comply with the Metering
Coordinator's reasonable security and safety requirements and has
first given the Metering Coordinator at least 2 business days notice
of its intention to carry out an audit.
(e) A notice under paragraph (d) must include:
(1) the name of the representative who will be conducting the
audit on behalf of the Utilities Commission; and
(2) the time when the audit will commence and the expected time
when the audit will conclude.
(f) The Metering Coordinator will be responsible for the costs of
undertaking the audit.
7A.7.6 Errors found in metering tests, inspections or audits
(a) Subject to paragraph (c), if a metering installation test, inspection or
audit, carried out in accordance with this rule, demonstrates errors
in excess of those prescribed in schedule 7A.4, the Metering
Coordinator must ensure the metering data is substituted in
accordance with this clause and clause 7A.8.1 as appropriate.
(b) If the Metering Coordinator is not aware of the time at which the
error arose:
(1) the error is taken to have occurred at a time halfway between
the time of the most recent test or inspection which
demonstrated that the metering installation complied with the
relevant accuracy requirement and the time when the error
was detected; and
(2) the time that the error was taken to occur is to be used by the
Metering Data Provider in performing substitution of the
metering data.
(c) If a test of a metering installation demonstrates an error of
measurement of less than 1.5 times the error permitted by
schedule 7A.4, no substitution of readings is required.
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(d) The Metering Coordinator must arrange for a suitable substation of
the incorrect metering data to be undertaken in accordance with the
substitution requirements of schedule 7A.7.
7A.7.7 Retention of test records and documents
(a) All records and documentation of tests prepared under or for this
Chapter must be retained in accordance with this clause.
(b) The Metering Coordinator must ensure records and documentation
are retained as follows:
(1) for a period of at least 7 years:
(i) sample testing of meters while the meters of the relevant
style remain in service;
(ii) the most recent sample test results of the meters
mentioned in subparagraph (i) after the meters are no
longer in service;
(iii) non-sample testing of meters while the meters remain in
service;
(iv) the most recent non-sample test results after the meters
are no longer in service;
(v) the most recent sample test results of instrument
transformers after instrument transformers of the
relevant type are no longer in service;
(vi) the most recent non-sample test results of instrument
transformers after they are no longer in service;
(vii) tests of new metering equipment of the relevant style
while the equipment remains in service; and
(viii) tests of new metering equipment of the relevant style
after the equipment is no longer in service;
(2) for a period of at least 10 years:
(i) sample testing of instrument transformers while
instrument transformers of the relevant type remain in
service; and
(ii) non-sample testing of instrument transformers while the
instrument transformers remain in service.
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(c) In addition, the Metering Coordinator must ensure records of type
tests and pattern approvals carried out or obtained in accordance
with clause S7A.4.5.1(f) are retained while metering equipment of
the relevant type remains in service and for at least 7 years after it
is no longer in service.
Part E Metering data
7A.8 Metering data services
7A.8.1 Metering data services
(a) Metering Data Providers must provide metering data services,
including the following, in accordance with the Rules:
(1) collecting energy data by local access or remote acquisition;
(2) the validation and substitution of metering data for types 1, 2,
3 and 4 metering installations;
(3) the validation, substitution and estimation of metering data for
types 4A, 5 and 6 metering installations;
(4) the calculation, estimation and substitution of metering data
for type 7 metering installations;
(5) establishing and maintaining a metering data services
database associated with each metering installation and
providing access to the metering data services database in
accordance with clause 7A.8.3;
(6) the delivery of metering data and relevant NT NMI Data for a
metering installation in accordance with clause 7A.8.4;
(7) the delivery to NTESMO of the following for settlements:
(i) metering data;
(ii) any metering register data requested by NTESMO;
(8) the delivery to relevant financially responsible participants of
metering data for billing transactions;
(9) ensuring the metering data and other data associated with the
metering installation is kept secure and disclosed only in
accordance with the Rules;
(10) maintaining the standard of accuracy of the time setting of the
metering installation in accordance with clause 7A.8.8;
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(11) notifying the Metering Coordinator of any metering installation
malfunction in accordance with clause 7A.6.9;
(12) management and storage of metering data in accordance with
clause 7A.8.3; and
(13) in respect of a metering installation that is a prepayment
device, subject to paragraph (b), services required to support
the energisation and de-energisation of the metering
installation.
(b) Metering Data Providers are not responsible:
(1) for the provision of a prepayment device; or
(2) in relation to a metering installation that is a prepayment
device, unless there is an agreement with the financially
responsible participant to the contrary, for the provision of
vending services.
Note
The installation of prepayment devices is dealt with in clause 7A.6.14.
The provision of vending services for prepayment devices is dealt with in
rule 7A.2.
(c) Metering Data Providers may provide additional data services that
exceed the minimum requirements of the Rules at the request of a
relevant financially responsible participant provided that:
(1) the full cost of providing such additional data services is met
by the financially responsible participant; and
(2) the provision of additional data services does not affect the
provision of metering data services.
Note
For example, vending services for a prepayment device could be an additional
service, if the financially responsible participant arranges for them to be provided
by the Metering Data Provider, noting that in accordance with clause 7A.2(c) the
financially responsible participant is responsible for ensuring that an arrangement
for vending services is in place.
7A.8.2 Collection of energy data and estimation of metering data
(a) A Metering Data Provider must, in accordance with this rule, collect
energy data from, and estimate metering data in respect of, a
metering installation at a connection point for which it has been
appointed the Metering Data Provider.
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Scheduled meter reading
(b) The Metering Data Provider must use reasonable endeavours to
ensure that energy data is collected from a metering installation by
way of an actual meter reading at least once every 3 months or,
where a greater frequency has been agreed with a financially
responsible participant, at that greater frequency.
(c) Despite paragraph (b), the Metering Data Provider must ensure that
energy data is collected from a metering installation by way of an
actual meter reading at least once every 12 months.
Special meter reading
(d) The Metering Data Provider must perform a special meter reading
(including a final meter reading) at the request of a financially
responsible participant.
(e) The Metering Data Provider may charge the financially responsible
participant or retail customer (as the case may be) for the collection
of energy data under paragraph (d) to the extent that its costs of
collection are higher than they would otherwise be.
Estimated metering data
(f) When energy data is not collected by the Metering Data Provider
from a metering installation by way of an actual meter reading at
the applicable meter reading frequency under paragraph (b), the
Metering Data Provider must estimate metering data for that
metering installation in accordance with schedule 7A.7.
(g) Estimated metering data for the purposes of paragraph (f) must be
provided to the retailer within 10 business days of the scheduled
meter reading date under paragraph (b).
Altering energy data
(h) The energy data in a metering installation must not be altered
except when the metering installation is reset to zero as part of a
repair or reprogramming.
7A.8.3 Data management and storage
(a) A Metering Data Provider must:
(1) retain metering data for all relevant metering installations in
the metering data services database:
(i) in electronic format for at least 13 months; and
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(ii) following the retention under subsubparagraph (i), in an
accessible format for at least 7 years;
(2) archive, in an accessible format, for at least 7 years:
(i) metering data in its original form as collected from the
metering installation; and
(ii) records of each substitution to metering data in respect
of a metering installation;
(3) enable the persons mentioned in clause 7A.13.5(c)(1) to (6) to
access or receive the metering data and NT NMI data in the
metering data services database; and
Note
This provision is classified as a civil penalty provision under the National
Electricity (NT) Regulations. (See regulation 6(1) and Schedule 1 of the National
Electricity (NT) Regulations.)
(4) except for the persons mentioned in clause 7A.13.3(c)(1)
to (6), ensure that no person has access to the metering data
services database.
Note
This provision is classified as a civil penalty provision under the National
Electricity (NT) Regulations. (See regulation 6(1) and Schedule 1 of the National
Electricity (NT) Regulations.)
(b) A Metering Data Provider must maintain electronic data transfer
facilities in order to deliver metering data from the metering data
services database in accordance with schedule 7A.8 and
clause 7A.8.4.
(c) Check metering data, where available, and appropriately adjusted
for differences in metering installation accuracy, where applicable,
must be used by the Metering Data Provider to validate metering
data.
(d) If the Metering Data Provider becomes aware that the metering
data that has been delivered into the metering database from a
metering data services database is incorrect, then the Metering
Data Provider must provide corrected metering data to the
financially responsible participant and NTESMO within 1 business
day of detection.
(e) Metering data may only be altered by a Metering Data Provider,
except in the preparation of settlements ready data, in which case
NTESMO may alter the metering data in accordance with
clause 7A.9.2(c).
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(f) A Metering Data Provider may only alter metering data in the
metering data services database in accordance with schedule 7A.7.
(g) A Metering Data Provider must arrange with the Metering
Coordinator to obtain the relevant metering data if remote
acquisition, if any, becomes unavailable.
(h) A Metering Data Provider's rules and protocols for supplying
metering data services must be approved by NTESMO and
NTESMO must not unreasonably withhold such approval.
7A.8.4 Provision of metering data to certain persons
A Metering Data Provider must give metering data and relevant NT
NMI data to the persons mentioned in clause 7A.13.5(c)(1) to (6)
and clause 9A.13.5(g)(1) as required by, and in accordance with,
the Rules.
Note
This provision is classified as a civil penalty provision under the National
Electricity (NT) Regulations. (See regulation 6(1) and Schedule 1 of the National
Electricity (NT) Regulations.)
7A.8.5 Use of check metering data
Check metering data, if available and if it has been appropriately
adjusted for differences in metering installation accuracy, must be
used by Metering Data Providers or NTESMO, as the case may be,
for:
(a) validation;
(b) substitution; and
(c) estimation,
of metering data as required by clause 7A.8.1.
7A.8.6 Periodic energy metering
(a) Subject to paragraph (b), a Metering Data Provider must:
(1) for type 1, 2, 3, 4, 4A and 5 metering installations, collate
metering data relating to:
(i) the amount of active energy; and
(ii) reactive energy (where relevant) passing through a
connection point,
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in recording intervals within a metering data services
database; and
(2) for type 6 metering installations, collate accumulated energy
data relating to an interval of up to 3 months.
(b) However:
(1) in relation to paragraph (a)(1):
(i) for local electricity systems with a market administered
by NTESMO – it may be agreed between NTESMO and
the financially responsible participant that metering data
may be recorded in sub-multiples of a recording interval
where a metering installation is used for the purposes of
settlements; and
(ii) for local electricity systems without a market
administered by NTESMO – it may be agreed between
the Metering Coordinator and the financially responsible
participant that metering data may be recorded in sub-
multiples of a recording interval where a metering
installation is used for the purposes of billing
transactions; and
(2) in relation to paragraph (a)(2):
(i) for local electricity systems with a market administered
by NTESMO – it may be agreed between NTESMO and
the financially responsible participant that some other
period will apply either on an ongoing basis or once-off
basis; and
(ii) for local electricity systems without a market
administered by NTESMO – it may be agreed between
the Metering Coordinator and the financially responsible
participant that some other period will apply either on an
ongoing basis or once-off basis.
(c) A Metering Data Provider must, for type 7 metering installations,
prepare estimated metering data relating to the amount of active
energy passing through a connection point in accordance with
clause 7A.8.1(a)(4) in 3 months or, where a greater frequency has
been agreed with a financially responsible participant, at that
greater frequency within a metering data services database.
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7A.8.7 Verification of metering data
Metering installations other than type 7 metering installations
(a) A Metering Data Provider responsible for a metering installation,
other than a type 7 metering installation, must ensure that the
metering data collected from the installation is validated in
accordance with schedule 7A.7.
(b) If validation under paragraph (a) demonstrates that there has been
a failure of the metering installation or that a measurement error
exists:
(1) the metering data must be substituted in accordance with
schedule 7A.7;
(2) the Metering Data Provider must provide the quality flag of the
substituted metering data to the financially responsible
participant for its record in accordance with clause S7A.7.8.4;
and
(3) for connection points associated with a retail customer – the
Metering Data Provider must provide the substituted metering
data to the retailer so that the retailer can meet its billing
obligations.
(c) The Metering Data Provider:
(1) must make a separate record of any substitution made under
this clause, including:
(i) the reasons for the substitution;
(ii) the methodology used for the substitution; and
(iii) the substituted metering data; and
(2) must maintain the record for at least 7 years and provide access to
the record at reasonable times to the relevant financially
responsible participant or retail customer (as the case may be).
Type 7 metering installations
Note
Obligations relating to type 7 metering installations, including requirements for
calculating metering data under this clause, will only apply in this jurisdiction in
the event of a type 7 metering installation being available in this jurisdiction and
after a 12 month transitional period allowing all participants to achieve
compliance.
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(d) A Metering Data Provider responsible for a type 7 metering
installation must ensure that the metering data for that installation:
(1) is calculated in accordance with the Network Service
Provider's applicable procedure, which must be based on a
methodology in, or otherwise be consistent with,
schedule 7A.7; and
(2) is validated in accordance with schedule 7A.7.
(e) If validation under paragraph (d)(2) demonstrates that there has
been a failure of the metering installation or that a measurement
error exists, the Metering Data Provider must ensure the metering
data is substituted in accordance with schedule 7A.7.
7A.8.8 Time settings
(a) The Metering Provider must set the times of clocks of all metering
installations with reference to Australian Central Standard Time to a
standard of accuracy in accordance with schedule 7A.4 relevant to
the load through the connection point when installing, testing and
maintaining metering installations.
(b) NTESMO must ensure that the metering database clock is
maintained within ±1 second of Australian Central Standard Time.
(c) The Metering Data Provider must ensure that the metering data
services database clock is maintained within ±1 second of
Australian Central Standard Time.
(d) The Metering Data Provider must:
(1) check the accuracy of the clock of the metering installation
with reference to Australian Central Standard Time to a
standard of accuracy in accordance with schedule 7A.4
relevant to the load through the connection point on each
occasion that the metering installation is accessed;
(2) reset the clock of the metering installation so that it is
maintained to the required standard of accuracy in accordance
with schedule 7A.4 relevant to the load through the connection
point if the clock error of a metering installation does not
conform to the required standard of accuracy on any occasion
that the metering installation is accessed; and
(3) notify the Metering Provider if the Metering Data Provider is
unable to reset the clock of the metering installation in
accordance with subparagraph (2).
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7A.8.9 Metering data performance standards
(a) Where required for the purposes of settlements, the Metering
Coordinator must ensure that metering data is provided to
NTESMO for all recording intervals where the metering installation
has the capability for remote acquisition of metering data, and that
the data is:
(1) derived from a metering installation compliant with
clause 7A.6.5(a);
(2) provided within the timeframe for settlements required in
accordance with jurisdictional electricity legislation;
(3) actual or substituted in accordance with schedule 7A.7; and
(4) provided in accordance with the performance standards
specified in schedule 7A.7.
Note
This provision is classified as a civil penalty provision under the National
Electricity (NT) Regulations. (See regulation 6(1) and Schedule 1 of the National
Electricity (NT) Regulations.)
(b) Where:
(1) the metering installation is a type 4A metering installation, or
does not have the capability for remote acquisition of metering
data; and
(2) metering data is required for the purposes of settlements,
the Metering Coordinator must ensure that metering data is
provided to NTESMO and that the data is:
(3) derived from a metering installation compliant with
clause 7A.6.5(a);
(4) provided within the timeframe required for settlements in
accordance with jurisdictional electricity legislation;
(5) actual, substituted or estimated in accordance with
schedule 7A.7; and
(6) provided in accordance with the performance standards
specified in schedule 7A.7.
Note
This provision is classified as a civil penalty provision under the National
Electricity (NT) Regulations. (See regulation 6(1) and Schedule 1 of the National
Electricity (NT) Regulations.)
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(c) The Metering Coordinator must ensure that, for all metering
installations used for billing transactions, metering data is provided
to the financially responsible participant for all recording intervals
where the metering installation has the capability for remote
acquisition of metering data, and that the data is:
(1) derived from a metering installation compliant with
clause 7A.6.5(a);
(2) provided to the financially responsible participant every
35 days for billing transactions unless it has been agreed
between the Metering Coordinator and the financially
responsible participant that some other timeframe will apply;
(3) actual or substituted in accordance with schedule 7A.7; and
(4) provided in accordance with the performance standards
specified in schedule 7A.7.
Note
This provision is classified as a civil penalty provision under the National
Electricity (NT) Regulations. (See regulation 6(1) and Schedule 1 of the National
Electricity (NT) Regulations.)
(d) For type 6 metering installations, metering data relating to the
amount of active energy passing through a connection point must
be provided to the financially responsible participant:
(1) every 3 months; or
(2) where a greater frequency has been agreed with the
financially responsible participant – at that greater frequency.
7A.9 Metering data and data base
7A.9.1 Metering database
(a) NTESMO must create, maintain and administer a metering
database (either directly or under a contract for provision of the
database) containing information for each metering installation
registered with NTESMO.
(b) The metering database must include metering data, settlements
ready data, and information for each metering installation registered
with NTESMO in accordance with this rule 7A.9.
(c) NTESMO:
(1) must enable the persons referred to in clause 7A.13.5(c)(1)
to (4) and clause 7A.13.5(f)(1) to access or receive data in the
metering database; and
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(2) except as specified in subparagraph (1), must ensure that no
other person has access to the metering database.
(d) For all types of metering installations, the metering database must
contain metering data that is:
(1) retained in an electronic format for at least 13 months; and
(2) following the retention under subparagraph (1), archived in an
accessible format for an overall period of not less than
7 years.
(e) The settlements ready data held in the metering data base must be
used by NTESMO for settlement purposes.
(f) The settlements ready data held in the metering database may be
used by Distribution Network Service Providers for the purpose of
determining distribution service charges in accordance with
clause 6.20.1.
(g) NTESMO must retain settlements ready data for all metering
installations for at least 7 years.
(h) Despite anything to the contrary in this Rule, NTESMO may provide
the energy ombudsman with metering data relating to a Registered
Participant from a metering installation, the metering database, or
the metering register, if the energy ombudsman has received a
complaint to which the data is relevant from a retail customer of the
Registered Participant.
(i) NTESMO must notify the relevant Registered Participant of any
information requested by the energy ombudsman under
paragraph (h) and, if it is requested by that Registered Participant,
supply the Registered Participant with a copy of any information
provided to the energy ombudsman.
7A.9.2 Data validation, substitution and estimation
(a) If NTESMO in the preparation of settlements ready data detects
metering data that fails validation NTESMO must notify the
Metering Data Provider within 1 business day of detection.
(b) Where a Metering Data Provider receives notification under
paragraph (a), the Metering Data Provider must use its best
endeavours to provide corrected metering data to NTESMO within
1 business day or advise NTESMO that this time limit cannot be
achieved, and the reason for delay, in which case the parties must
agree on a revised time limit by which the corrected metering data
will be provided.
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(c) Where metering data fails validation by NTESMO in the preparation
of settlements ready data and replacement metering data is not
available within the time required for settlements then NTESMO
must prepare a substitute value in accordance with
schedule S7A.7.
7A.9.3 Changes to energy data or to metering data
(a) The Metering Coordinator must ensure that energy data held in a
metering installation is not altered except when the meter is reset to
zero as part of a repair or reprogramming.
(b) If an on-site test of a metering installation requires the injection of
current, the Metering Coordinator must ensure that:
(1) the energy data stored in the metering installation is
inspected;
(2) if necessary following the inspection under subparagraph (1),
alterations are made to the metering data, to ensure that the
metering data in the metering data services database and the
metering database is not materially different from the energy
consumed at that connection point during the period of the
test.
(c) If a Metering Coordinator considers alterations are necessary under
paragraph (b)(2), the Metering Coordinator must:
(1) for local electricity systems with a market operated by
NTESMO, notify NTESMO that alteration to the metering data
is necessary; and
(2) advise the financially responsible participant of the need to
change the metering data, and the Metering Coordinator must
arrange for the Metering Data Provider to:
(i) alter the metering data for the connection point held in
the metering data services database in accordance with
the validation, substitution and estimation procedures in
schedule 7A.7; and
(ii) provide the altered metering data to the persons who
receive that metering data under clause 7.13.5(c).
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(d) If a test referred to in paragraph (b) is based on actual connection
point loads, no alteration is required.
Note
This provision is classified as a civil penalty provision under the National
Electricity (NT) Regulations. (See regulation 6(1) and Schedule 1 of the National
Electricity (NT) Regulations.)
7A.10 Register of metering information
7A.10.1 Metering register
(a) As part of the metering database, NTESMO must maintain a
metering register of all metering installations and check metering
installations which provide metering data for settlements.
(b) The metering register referred to in paragraph (a) must contain the
information specified in Schedule 7A.1.
7A.10.2 Metering installation registration process
(a) For the purpose of maintaining the metering register, NTESMO
must establish, maintain and publish a registration process in
respect to the following (where metering data provided is used for
settlements):
(1) new metering installations;
(2) modifications to existing metering installations; and
(3) decommissioning of metering installations.
7A.10.3 Metering register discrepancy
(a) If the information in the metering register indicates that the metering
installation or the check metering installation does not comply with
the requirements of the Rules, NTESMO must advise affected
Registered Participants of the discrepancy.
(b) The Metering Coordinator must arrange for the discrepancy to be
corrected within 2 business days of receipt of notification under
paragraph (a) unless otherwise agreed by NTESMO.
Discrepancies between database and other data
(c) If there is a discrepancy between energy data held in a metering
installation and data held in the metering database:
(1) the affected Metering Coordinator and NTESMO must liaise
together to determine the most appropriate way to resolve the
discrepancy; and
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(2) for the purposes of this Chapter the energy data for the
metering point in the metering installation is to be taken to be
correct, unless it is proven to be incorrect.
(d) If there is a discrepancy between information held in a metering
register and the same category of information in any other
database, then for the purposes of this Chapter the information
recorded in the metering register is to be taken to be correct, unless
it is proven to be incorrect.
Metering Coordinators must keep the registry accurate
(e) If a Metering Coordinator becomes aware of a change to, or an
inaccuracy in, information in the metering register, then it must as
soon as practicable and no later than 2 business days after the day
it becomes aware of the change or inaccuracy notify NTESMO and
provide details of the change to, or inaccuracy in, the information.
NTESMO may amend metering register
(f) If NTESMO is notified of an inaccuracy in information by a Metering
Coordinator or other Registered Participant in relation to the
connection point it is financially responsible for, NTESMO must
undertake investigations to the standard of good industry practice to
determine whether the metering register should be updated.
(g) If NTESMO determines that the metering register should be
updated as a result of an investigation conducted in accordance
with paragraph (a), NTESMO must update the registry to reflect the
change to, or correct the inaccuracy in, the information.
(h) If information for a connection point is updated in the metering
register, NTESMO must, within 2 business days after the update,
notify the update to:
(1) the financially responsible participant; and
(2) if the financially responsible participant is a retailer and there
was a change in retailer, the previous retailer where that
updated information relates to a period or periods when the
previous retailer was the retailer for that connection point.
Note
In paragraph (h)(2), references to "previous retailer" means a retailer who was
previously recorded in the metering register as the financially responsible
participant for the connection point referred to in paragraph (h).
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7A.11 Disclosure of information
7A.11.1 Provision of data to retailers
NMI and NMI checksum
(a) A Distribution Network Service Provider must, at the request of a
retailer, and within 1 business day of the date of the request,
provide the retailer with the NMI and NMI checksum for premises
identified in the request by reference to:
(1) a unique meter identifier held by the Distribution Network
Service Provider;
(2) a street address; or
(3) the code used by Australia Post to provide a unique identifier
for postal addresses.
(b) If a computer search by the Distribution Network Service Provider
does not produce a unique match for the information provided by
the retailer, the Distribution Network Service Provider must provide
the retailer with any computer matches achieved up to a maximum
of 99.
NT NMI Data
(c) A Distribution Network Service Provider must, at the request of a
retailer, and within 2 business days of the date of the request,
provide the retailer with the NT NMI Data for premises identified in
the request by reference to the NMI for the premises.
7A.12 Metering data provision to retail customers
Note
The application of this rule will be revisited as part of the phased implementation
of the Rules in this jurisdiction.
Part F Security of metering installations and energy
data
7A.13 Security of metering installations, energy data and
metering data
7A.13.1 Confidentiality of data
(a) Energy data, metering data, NT NMI data, information in the
metering register and passwords are confidential and must be
treated as confidential information in accordance with the Rules.
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(b) For the purposes of clause 8.6.2(c), metering data from a metering
installation at a retail customer's connection point is deemed to
have been provided by the retail customer.
7A.13.2 Security of metering installations
General security
(a) The Metering Coordinator at a connection point must ensure that
the metering installation is secure and that associated links, circuits
and information storage and processing systems are protected by
appropriate security mechanisms.
Note
This provision is classified as a civil penalty provision under the National
Electricity (NT) Regulations. (See regulation 6(1) and Schedule 1 of the National
Electricity (NT) Regulations.)
(b) In respect of a connection point used for settlements, NTESMO
may override any of the security mechanisms fitted to a metering
installation with prior notice to the Metering Coordinator.
Broken seals
(c) If a Network Service Provider, financially responsible participant,
Metering Provider or Metering Data Provider becomes aware that a
seal protecting metering equipment has been broken, it must notify
the Metering Coordinator within 5 business days.
(d) If a broken seal has not been replaced by the person who notified
the Metering Coordinator under paragraph (c), the Metering
Coordinator must ensure that the broken seal is replaced no later
than:
(1) the first occasion on which the metering equipment is visited
to take a reading; or
(2) 100 days,
after receipt of notification that the seal has been broken.
(e) The costs of replacing broken seals as required by paragraph (d)
are to be borne by:
(1) the financially responsible participant if the seal was broken by
a retail customer of the financially responsible participant;
(2) a Registered Participant if the seal was broken by the
Registered Participant;
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(3) the Metering Provider if the seal was broken by the Metering
Provider;
(4) the Metering Data Provider if the seal was broken by the
Metering Data Provider; or
(5) otherwise by the Metering Coordinator.
(f) If it appears that, as a result of, or in connection with, the breaking
of a seal mentioned in paragraph (c) the relevant metering
equipment may no longer meet the relevant minimum standard, the
Metering Coordinator must ensure that the metering equipment is
tested in accordance with clause 7A.7.2.
7A.13.3 Security controls for energy data
(a) The Metering Coordinator at a connection point must ensure that
energy data held in the metering installation is protected from local
access and remote access by suitable password and security
controls.
Note
This provision is classified as a civil penalty provision under the National
Electricity (NT) Regulations. (See regulation 6(1) and Schedule 1 of the National
Electricity (NT) Regulations.)
(b) The Metering Provider must keep records of passwords secure.
Note
This provision is classified as a civil penalty provision under the National
Electricity (NT) Regulations. (See regulation 6(1) and Schedule 1 of the National
Electricity (NT) Regulations.)
(c) The Metering Provider must allocate suitable passwords to the
Metering Data Provider to enable the Metering Data Provider to
collect the energy data and maintain the clock of the metering
installation in accordance with clause 7A.8.7.
(d) The Metering Data Provider must keep all metering installation
passwords secure and not make the passwords available to any
other person.
Note
This provision is classified as a civil penalty provision under the National
Electricity (NT) Regulations. (See regulation 6(1) and Schedule 1 of the National
Electricity (NT) Regulations.)
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7A.13.4 Additional security controls for type 4 metering installations
In respect of a type 4 metering installation:
(a) the Metering Coordinator must ensure that access to energy
data held in the metering installation is given only:
(1) to a person who is permitted to have access to it under
the Rules; and
(2) for a purpose that is permitted under the Rules;
(b) the Metering Coordinator must ensure that access to services
provided by the metering installation and metering data from
the metering installation is given only:
(1) in respect of:
(i) a remote disconnection service and the metering
data in connection with that service – to the Local
Network Service Provider and the financially
responsible participant;
(ii) a remote reconnection service and the metering
data in connection with that service – to the Local
Network Service Provider, the financially
responsible participant and the incoming retailer;
(iii) a remote on-demand meter reading service and the
metering data in connection with that service – to
Registered Participants with a financial interest in
the metering installation or the energy measured by
that metering installation and a person to whom a
retail customer has given its consent under
subparagraph (3)(ii);
(iv) a remote scheduled meter reading service and the
metering data in connection with that service – to
Registered Participants with a financial interest in
the metering installation or the energy measured by
that metering installation and a person to whom a
retail customer has given its consent under
subparagraph (3)(ii);
(v) a metering installation inquiry service and the
metering data in connection with that service – to
the Local Network Service Provider, the financially
responsible participant and a person to whom a
retail customer has given its consent under
subparagraph (3)(ii); and
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(vi) an advanced meter reconfiguration service and the
metering data in connection with that service – to
the Local Network Service Provider and the
financially responsible participant;
(2) to a person who is permitted to have access to it under
the Rules and for a purpose that is permitted under the
Rules; or
(3) except as otherwise specified in subparagraph (1) or (2):
(i) to the Local Network Service Provider, but only to
the extent that, in the Metering Coordinator's
reasonable opinion, the access is reasonably
required by the Local Network Service Provider to
enable it to meet its obligations to provide a safe,
reliable and secure network; or
(ii) to a person and for a purpose to which the retail
customer has given prior consent;
(c) the Metering Coordinator must ensure that the services
provided by the metering installation are protected from local
access and remote access by suitable password and security
controls in accordance with paragraph (e);
(d) the Metering Provider must keep records of passwords
secure; and
(e) the Metering Provider must:
(1) forward a copy of a password allowing local access and
a copy of a password allowing remote access to the
metering installation, services provided by the metering
installation and energy data held in the metering
installation, to the Metering Coordinator, Metering Data
Provider and NTESMO; and
(2) ensure that no other person receives or has access to a
copy of a password allowing local access or remote
access to the metering installation, services provided by
the metering installation or energy data held in the
metering installation.
Note
This provision is classified as a civil penalty provision under the National
Electricity (NT) Regulations. (See regulation 6(1) and Schedule 1 of the National
Electricity (NT) Regulations.)
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7A.13.5 Access to data
(a) Access to energy data recorded by a metering installation must only
be given if passwords are allocated in accordance with
clause 7A.13.3.
(b) The Metering Coordinator must ensure that access to energy data
from the metering installation is scheduled appropriately to ensure
that congestion does not occur.
(c) Subject to this clause, the only persons entitled to access or receive
metering data, settlements ready data, NT NMI data or data from
the metering register for a metering installation are:
(1) the financially responsible participant in respect of the
connection point for the metering installation and any other
Registered Participant with a financial interest in the metering
installation or the energy measured by the metering
installation;
(2) the Metering Coordinator appointed in respect of the
connection point for the metering installation;
(3) the Metering Provider appointed with respect to the metering
installation;
(4) the Metering Data Provider appointed with respect to the
metering installation;
(5) NTESMO and its authorised agents;
(6) the Local Network Service Provider associated with the
connection point; and
(7) the AER and the Utilities Commission.
(d) In addition to the persons mentioned in paragraph (c), the following
persons may access or receive metering data in accordance with
the Rules:
(1) a retail customer or customer authorised representative, upon
request by that retail customer or its customer authorised
representative to the retailer or Distribution Network Service
Provider in relation to that retail customer's metering
installation;
(2) the energy ombudsman.
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(e) A retailer or Distribution Network Service Provider must, upon
request by a retail customer or its customer authorised
representative under paragraph (d)(1), provide information about
the retail customer's energy consumption for the previous 2 years.
(f) Without limiting this clause:
(1) a retailer is entitled to access or receive NT NMI data;
(2) a customer authorised representative may receive metering
data; and
(3) a retailer or a Distribution Network Service Provider may
access or receive metering data or provide metering data to a
customer authorised representative,
after having first done whatever may be required, if relevant, under
any applicable privacy legislation and clause 7A.9.5 including, if
appropriate, making relevant disclosures or obtaining relevant
consents from retail customers.
(g) For the avoidance of doubt and without limiting this clause:
(1) a Metering Data Provider must provide relevant NT NMI data
to a Distribution Network Service Provider to the extent that
NT NMI data is required for the Distribution Network Service
Provider to fulfil its obligations under this Chapter 7A of the
Rules; and
(2) a Distribution Network Service Provider is authorised to, and
must provide, relevant NT NMI data to a Metering Data
Provider to the extent that NT NMI data is required for the
Metering Data Provider to fulfil its obligations under this
Chapter 7A of the Rules.
Schedule 7A.1 Metering register
S7A.1.1 General
The metering register forms part of the metering database and
holds static metering information associated with metering
installations defined by the Rules that determine the validity and
accuracy of metering data.
S7A.1.2 Metering register information
Metering information to be contained in the metering register must
include, but is not limited to, the following:
(a) serial numbers;
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(b) the metering installation identification name; and
(c) the information required to assign loss factors.
S7A.1.3 Communication guideline
(a) NTESMO must develop, maintain and publish a communication
guideline in accordance with the Rules consultation procedures.
(b) A communication guideline must be in place at all times.
(c) The communication guideline is intended to set out specific details
as to how metering and energy data and other information
exchange processes will be implemented.
(d) The communication guideline must:
(1) specify, or incorporate by reference, detailed technical
specifications (including file formats, protocols and
timeframes) as to how data and information communication is
to be processed, and how the necessary information systems
are to be designed and developed; and
(2) be sufficient to enable a Registered Participant to design and
commission the information systems necessary for it to
engage in communications with NTESMO for the purposes of
the Rules.
(e) The communication guideline may include types of metering
information that must be included in the metering register.
Schedule 7A.2 Metering provider
Note
The detail of this schedule will be considered as part of the phased
implementation of the Rules in this jurisdiction.
Schedule 7A.3 Metering data provider
Note
The detail of this schedule will be considered as part of the phased
implementation of the Rules in this jurisdiction.
Schedule 7A.4 Types and accuracy of metering installations
S7A.4.1 General requirements
This schedule sets out the minimum requirements for metering
installations.
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S7A.4.2 Accuracy requirements for metering installations
Table S7A.4.2.1 Overall accuracy requirements of metering
installation components
Type
Volume
limit per
annum per
connection
point
Maximum
allowable overall
error (±%) at full
load (Item 6)
Minimum
acceptable
class or
standard of
components
Metering
installation
clock error
(seconds) in
reference to
ACST
active reactive
1 greater
than
1 000GWh
0.5 1.0 0.2CT/VT/meter
Wh
0.5 meter varh
±5
2 100 to
1 000GWh
1.0 2.0 0.5CT/VT/meter
Wh
1.0 meter varh
±7
3 0.75 to less
than
100 GWh
1.5 3.0 0.5CT/VT
1.0 meter Wh
2.0 meter varh
(Item 1)
±10
4 less than
750 MWh
(Item 2)
1.5 n/a Either 0.5 CT and
1.0 meter Wh; or
whole current
general purpose
meter Wh meets
requirements of
clause
7A.6.2(a)(9) and
7A.8.9(a)
(Item 1)
±20
4A less than x
MWh
(Item 3)
1.5 3.0 Either 0.5 CT and
1.0 meter Wh;
or whole current
general purpose
meter Wh meets
requirements of
clause
7A.6.2(a)(10) and
7A.8.9(b)
±20
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Type
Volume
limit per
annum per
connection
point
Maximum
allowable overall
error (±%) at full
load (Item 6)
Minimum
acceptable
class or
standard of
components
Metering
installation
clock error
(seconds) in
reference to
ACST
active reactive
5 less than x
MWh
(Item 3)
1.5 n/a Either 0.5 CT and
1.0 meter Wh; or
whole current
connected
general purpose
meter Wh meets
requirements of
clause
7A.6.2(a)(10) and
7A.8.9(b).
(Item 1)
‘±/-20'
6 less than y
MWh
(Item 4)
2.0 n/a CT or whole
current general
purpose meter
Wh recording
accumulated
energy data only.
Processes used
to convert the
accumulated
metering data
into recording
interval metering
data and
estimated
metering data
where necessary
are included in
schedule 7A.7.
(Item 1)
7 volume limit
not
specified
(Item 5)
(Item 6) n/a No meter. The
metering data is
calculated
metering data
determined in
accordance with
schedule 7A.7.
n/a
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Item 1: (a) For a type 3, 4, 4A, 5 and 6 metering installation, whole
current meters may be used if the meters meet the
requirements of the relevant Australian Standards and
International Standards identified in schedule 7A.7.
(b) The metering installation types referred to in paragraph (a)
must comply with any applicable specifications or guidelines
(including any transitional arrangements) specified by the
National Measurement Institute under the National
Measurement Act.
Item 2: High voltage customers that require a voltage transformer and
whose annual consumption is below 750 MWh, must meet the
relevant accuracy requirements of Type 3 metering for active
energy only.
Item 3: In relation to a type 4A and type 5 metering installation, the value
of ‘x' in this jurisdiction is 0 MWh per annum.
Item 4: The following requirements apply in relation to a type 6 metering
installation:
(1) the value of ‘y' in this jurisdiction is 750 MWh per annum;
(2) devices within the metering installation may record
accumulated energy data in predetermined daily time periods
where such time periods are specified in schedule 7A.7.
Item 5: (a) A type 7 metering installation classification applies where a
metering installation does not require a meter to measure the
flow of electricity in a power conductor and accordingly there
is a requirement to determine by other means the metering
data that is deemed to correspond to the flow of electricity in
the power conductor.
(b) The condition referred to in paragraph (a) will only be allowed
for a connection point if:
(1) the operation of an unmetered device at the
connection point results in a type of
unmetered load that is authorised under the
terms of a local instrument; and
(2) NTESMO in consultation with Metering
Coordinator determines:
(i) that the load pattern is predictable;
(ii) that, for the purposes of settlements, the
load pattern can be reasonably
calculated by a relevant method set out
in schedule S7A.7; and
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(iii) that it would not be cost effective to
meter the connection point taking into
account:
(A) the small magnitude of the load;
(B) the connection arrangements; and
(C) the geographical and physical
location.
Note
The effect of paragraph (b) is that if a type of
unmetered load is authorised under a local
instrument, a connection point with that type of
unmetered load may be used for the purposes of
settlements, and be eligible for a type 7 metering
installation, if NTESMO makes a determination
under (b)(2) in relation to that connection point.
The National Electricity (Northern Territory) (National
Uniform Legislation) (Modification) Regulations 2016
are an example of a local instrument.
(c) A connection point that meets the condition for classification
as a type 7 metering installation does not prevent that
connection point from being subject to metering in the future.
Item 6: The maximum allowable overall error (±%) at different loads and
power factors is set out in Tables S7A.4.2.2 to S7A.4.2.6.
Table S7A.4.2.2 Type 1 installation – Annual energy throughput greater
than 1 000GWh
%
Rated
Load
Power Factor
Unity 0.866 lagging 0.5 lagging Zero
Active Active Reactive Active Reactive Reactive
10 1.0% 1.0% 2.0% n/a n/a 1.4%
50 0.5% 0.5% 1.0% 0.7% 1.4% 1.0%
100 0.5% 0.5% 1.0% n/a n/a 1.0%
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Table S7A.4.2.3 Type 2 installation – Annual energy throughput between 100 and
1 000GWh
%
Rated
Load
Power Factor
Unity 0.866 lagging 0.5 lagging Zero
Active Active Reactive Active Reactive Reactive
10 2.0% 2.0% 4.0% n/a n/a 2.8%
50 1.0% 1.0% 2.0% 1.5% 3.0% 2.0%
100 1.0% 1.0% 2.0% n/a n/a 2.0%
Table S7A.4.2.4 Type 3 installation – Annual energy throughput from
0.75 GWh to less than 100 GWh and Type 4A installation – annual energy
throughput less than 0.75 GWh
%
Rated
Load
Power Factor
Unity 0.866 lagging 0.5 lagging Zero
Active Active Reactive Active Reactive Reactive
10 2.5% 2.5% 5.0% n/a n/a 4.0%
50 1.5% 1.5% 3.0% 2.5% 5.0% 3.0%
100 1.5% 1.5% 3.0% n/a n/a 3.0%
Table S7A.4.2.5 Type 4 or 5 installation – annual energy throughput less
than 0.75GWh
% Rated Load Power Factor
Unity 0.866 lagging 0.5 lagging
Active Active Active
10 2.5% 2.5% n/a
50 1.5% 1.5% 2.5%
100 1.5% 1.5% n/a
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Table S7A.4.2.6 Type 6 installation – annual energy throughput less than
0.75 GWh
% Rated Load Power Factor
Unity 0.866 lagging 0.5 lagging
Active Active Active
10 3.0% n/a n/a
50 2.0% n/a 3.0%
100 2.0% n/a n/a
Notes to Tables S7A4.2.2 to S7A4.2.6
All measurements in Tables S7A4.2.2 to S7A4.2.6 are to be referred to 24
degrees Celsius.
(a) The method for calculating the overall error is the vector sum of the errors of
each component part (that is, a + b + c) where:
a = the error of the voltage transformer and wiring;
b = the error of the current transformer and wiring; and
c = the error of the meter.
(b) If compensation is carried out then the resultant metering data error must be
as close as practicable to zero.
S7A.4.3 Check metering
(a) Where a check metering installation is in place, it is to be applied in
accordance with the following Table:
Metering Installation Type in
accordance with Table S7A.4.2.1
Check Metering Requirements
1 Check metering installation
2 Partial check metering
3 No requirement
4, 4A, 5 and 6 No requirement
(b) Where a check metering installation is not in place, and a financially
responsible participant requests the installation of a check metering
installation at a connection point, the Metering Coordinator at the
connection point must arrange for the installation of a check
metering installation that complies with the requirements of this
schedule.
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(c) A check metering installation involves either:
(1) the provision of a separate metering installation using
separate current transformer cores and separately fused
voltage transformer secondary circuits, preferably from
separate secondary windings; or
(2) if NTESMO, in its absolute discretion, considers it appropriate,
in the case of a metering installation located at the facility at
one end of the two-terminal link, a metering installation located
at the facility at the other end of a two-terminal link.
(d) Where the check metering installation duplicates the metering
installation and accuracy level, the average of the 2 validated data
sets will be used to determine the energy measurement.
(e) Partial check metering involves the use of other metering data or
operational data available in 30 min electronic format as part of a
validation process in accordance with Schedule 7A.7.
(f) Check metering installations may be supplied from secondary
circuits used for other purposes and may have a lower level of
accuracy than the metering installation, but must not exceed twice
the level prescribed for the metering installation.
(g) The physical arrangement of partial check metering will be
determined by the Metering Coordinator.
S7A.4.4 Resolution and accuracy of displayed or captured data
Programmable settings available within a metering installation of
any peripheral device, which may affect the resolution of displayed
or stored data, must:
(a) meet the requirements of the relevant Australian Standards
and International Standards specified in schedule 7A.7; and
(b) comply with any applicable specifications or guidelines
(including any transitional arrangements) specified by the
National Measurement Institute under the National
Measurement Act.
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S7A.4.5 General design standards
S7A.4.5.1 Design requirements
Without limiting the scope of detailed design, the following
requirements must be incorporated in the design of each metering
installation:
(a) for metering installations greater than 1 000 GWh pa per
connection point, the current transformer core and secondary
wiring associated with the meter(s) must not be used for any
other purpose;
(b) for metering installations less than 1 000 GWh pa per
connection point, the current transformer core and secondary
wiring associated with the meter(s) may be used for other
purposes (for example, local metering or protection) provided
the Metering Coordinator is able to demonstrate that the
accuracy of the metering installation is not compromised and
suitable procedures/measures are in place to protect the
security of the metering installation;
(c) where a voltage transformer is required, if separate secondary
windings are not provided, then the voltage supply to each
metering installation must be separately fused and located in
an accessible position as near as practical to the voltage
transformer secondary winding;
(d) secondary wiring must be by the most direct route and the
number of terminations and links must be kept to a minimum;
(e) the incidence and magnitude of burden changes on any
secondary winding supplying the metering installation must be
kept to a minimum;
(f) meters must:
(1) meet the requirements of relevant Australian Standards
and International Standards (if any) specified in
schedule 7A.7; and
(2) have a valid pattern approval issued under the authority
of the National Measurement Institute or, until relevant
pattern approvals exist, a valid type test certificate;
(g) new instrument transformers must:
(1) meet the requirements of relevant Australian Standards
and International Standards (if any) specified in
schedule 7A.7; and
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(2) have a valid pattern approval issued under the authority
of the National Measurement Institute or, until relevant
pattern approvals exist, a valid type test certificate;
(h) suitable isolation facilities are to be provided to facilitate
testing and calibration of the metering installation;
(i) suitable drawings and supporting information, detailing the
metering installation, must be available for maintenance
purposes.
S7A.4.5.2 Design guidelines
In addition to the design requirements specified in clause S7A.5.1,
the following guidelines should be considered for each metering
installation:
(a) the provision of separate secondary windings for each
metering installation where a voltage transformer is required;
(b) a voltage changeover where more than one voltage
transformer is available.
Schedule 7A.5 Metering functionality requirements for type 1,
2, 3 and 4 metering requirements
S7A.5.1 Introduction
S7A.5.1.1 Purpose
This schedule specifies the meter functionality requirements for
type 1, 2, 3 and 4 metering installations in this jurisdiction.
S7A.5.1.2 Definitions
In this schedule:
communications network means all communications equipment,
processes and arrangements that lie between the meter and the
NMS.
end user customer means the customer or retail customer who
consumes electricity at the point of use.
export means the delivery of energy from the network to an end-
use customer.
import means the delivery of energy from an end-use customer
into a distribution network.
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local disconnection means the operation of the supply contactor
to effect a disconnection of supply performed locally at the meter by
alternative electronic means.
metering system means the installed metering installation,
communications network or infrastructure, and any other systems
required under this schedule.
NMS (Network Management System) means the component of a
metering system that manages the communications network.
remote disconnection means the utilisation of the communication
system to disconnect the end-use customer's supply at the meter
by the operation of a contactor.
supply contactor means the contactor in the meter that, when
opened, causes the supply to be disconnected and, when closed,
allows the supply to become connected.
total accumulated energy means the total or accumulated amount
of energy measured and recorded per channel of a meter since the
installation of the meter or the resetting of the value.
S7A.5.2 Functionality Requirements for Meters in Type 1, 2,
and 3 metering installations
S7A.5.2.1 Application
Clause S7A.5.2 applies to meters in type 1, 2 and 3 metering
installations.
S7A.5.2.2 Applicable meter configurations
(a) The configuration for a meter must be:
(1) three phase Low Voltage CT connect (excluding supply
contactor); or
(2) three phase CT/VT.
(b) Meters must meet the relevant requirements of AS 62052.11,
AS 62053.22 and AS 62053.21, and any pattern approval
requirements of the National Measurement Institute.
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S7A.5.2.3 Metrology
Meters must comply with the following requirements:
(a) three phase meters must be four quadrant meters and must
be able to separately record active energy and reactive
energy, import and export in recording intervals;
(b) meters must record total accumulated energy for each
recorded channel of interval data;
(c) the resolution for collection of interval energy data must be at
least 0.1 kWh for active energy and 0.1 kVArh for reactive
energy;
(d) meters must have a minimum storage of 35 days per channel
of interval energy data;
(e) all channels of interval energy data must be able to be read
locally as well as remotely read;
(f) it must be possible to remotely and locally select or configure
whether import interval energy data is recorded or not;
(g) it must be possible to remotely and locally select or configure
whether reactive energy interval energy data is recorded from
three phase meters or not.
S7A.5.3 Functionality Requirements for Meters in Type 4
metering installations
S7A.5.3.1 Application
Clause S7A.5.3 applies to meters in type 4 metering installations.
S7A.5.3.2 Applicable meter configurations
(a) The configuration for a meter must be:
(1) single phase, single element;
(2) single phase, two element;
(3) three phase direct connect; or
(4) three phase CT connect (excluding supply contactor).
(b) Meters must meet the relevant requirements of AS 62052.11,
AS 62053.22 and AS 62053.21, and any pattern approval
requirements of the National Measurement Institute.
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S7A.5.3.3 Metrology
Meters must comply with the following requirements:
(a) single phase meters must be two quadrant meters and must
be able to separately record active energy for import and
export in recording intervals;
(b) three phase meters must be four quadrant meters and must
be able to separately record active energy and reactive
energy, import and export in recording intervals;
(c) meters must record total accumulated energy data for each
recorded channel of interval energy data;
(d) the resolution for collection of interval energy data must be at
least 0.1 kWh for active energy and 0.1 kVArh for reactive
energy;
(e) the resolution of energy consumption displayed on a meter's
display must be at least 0.1 kWh and 0.1 kVArh for direct
connected meters;
(f) meters must have a minimum storage of 200 days per channel
of interval energy data;
(g) all channels of interval energy data must be able to be read
locally as well as by remote acquisition;
(h) the values that must be recorded for import and export are the
actual values at the connection point for direct connect
meters;
(i) it must be possible to remotely and locally select or configure
whether import interval energy data is recorded or not;
(j) it must be possible to remotely and locally select or configure
whether reactive energy interval energy data is recorded from
three phase meters or not.
Note:
Export is when energy is exported from the network to a customer and import is
when the customer delivers energy into the network. See clause S7A5.1.2.
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S7A.5.3.4 Remote and local reading of meters
(a) If a meter is remotely read:
(1) the meter's total accumulated energy data per collected
channel must be able to be collected once every 24 hours;
and
(2) the interval energy data per collected channel must be able to
be collected once every 24 hours.
(b) If a meter is locally read, the meter's total accumulated energy per
collected channel and the interval energy data per collected
channel must be able to be collected.
(c) For individual reads of meters, it must be possible to select up to 35
days of interval energy data to be collected per channel.
S7A.5.3.5 Supply disconnection and reconnection
S7A.5.3.5.1 General requirements
(a) Meters excluding CT connected meters must have a supply
contactor.
(b) Meters must support both local and remote disconnect, and local
and remote reconnection of end-use customer supply via the supply
contactor. When a meter performs a disconnection operation, all
outgoing circuits from the meter must be disconnected.
(c) To confirm the current state of a meter, the meter must support
"on-demand" remote polling of the meter to determine whether the
supply contactor is open or closed.
(d) A meter must provide clear local visual indication of the status
(open/closed) of the supply contactor.
S7A.5.3.5.2 Disconnection
(a) A meter must support both local and remote end-use customer
supply disconnection functionality.
Local disconnection
Note:
The circumstances in which local disconnection may occur include where:
(a) a technician is already on-site performing works and it is most efficient for the
technician to perform the disconnection; or
(b) a meter that is capable of remote reading is installed; however the
communications infrastructure has not been rolled out or has failed.
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(b) Local disconnection via the meter must only be able to be
performed by an authorised technician. Unauthorised persons must
be physically prevented from operating the supply contactor to
disconnect supply.
(c) A meter must support the following:
(1) opening of the supply contactor performed locally;
(2) remote communication of the status (open/closed) of the
supply contactor (if communications are active) from the meter
to the NMS;
(3) event logging of the local disconnection at that meter.
Remote disconnection
(d) A meter must support the following:
(1) opening of the supply contactor performed remotely;
(2) remote communication of the status (open/closed) of the
supply contactor (if communications are active) from the meter
to the NMS;
(3) event logging of the remote disconnection at that meter.
S7A.5.3.5.3 Reconnection
(a) A meter must support both local and remote end-use customer
supply reconnection functionality.
Local reconnection
(b) Reconnection via the meter must only be able to be performed
locally by an authorised technician. Unauthorised persons must be
physically prevented from operating the supply contactor to
reconnect supply.
(c) A meter must support the following:
(1) closing of the supply contactor performed locally;
(2) remote communication of the status (open/closed) of the
supply contactor (if communications are active) from the meter
to the NMS;
(3) event logging of local reconnection at that meter.
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Remote reconnection
(d) A meter must support the following:
(1) closing of the supply contactor performed remotely;
(2) remote communication of the status (open/closed) of the
supply contactor from the meter to the NMS; and
(3) event logging of remote reconnection.
S7A.5.3.6 Time clock synchronisation
Date and time within meters must be maintained within 20 seconds
of Australian Central Standard Time.
S7A.5.3.7 Quality of Supply and other event recording
(a) A meter must support the recording of Quality of Supply (QoS)
events and other events that occur at each meter as detailed as
follows:
ID Events
1 Import energy detected
2 Supply contactor opened – local
3 Supply contactor opened – remote
4 Supply contactor closed – local
5 Supply contactor closed – remote
6 Undervoltage event
7 Overvoltage event
8 Tamper detected
9 Whenever there is a change of meter settings
locally
Undervoltage and overvoltage recording
(b) A meter must support the recording of undervoltage and
overvoltage events. The thresholds shall be remotely and locally
settable for undervoltage in the range of at least -5% to -20% in 1%
steps and for overvoltage in the range of at least +5% to +20% in
1% steps.
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Tamper detection
(c) A meter must support the detection and recording of an attempt to
tamper with the meter as an event.
S7A.5.3.8 Tamper detection
A meter must support the detection and recording as an event
attempts to tamper with the meter.
S7A.5.3.9 Communications and data security
All device elements must contain the necessary security to prevent
unauthorised access or modification of data.
S7A.5.3.10 Remote firmware upgrades
Meters must have the capability for their firmware to be remotely
upgraded. It must be possible to remotely change firmware without
impacting the metrology functions of the meter.
S7A.5.3.11 Remote arming
Meters must have the capability to be remotely armed.
Schedule 7A.6 Inspection and testing requirements
S7A.6.1 General
(a) The Metering Coordinator must ensure that equipment comprised in
a purchased metering installation has been tested to the required
class accuracy with less than the uncertainties set out in
Table S7A.6.1.1.
(b) The Metering Coordinator must ensure appropriate test certificates
of the tests referred to in paragraph (a) are retained.
(c) The Metering Coordinator (or any other person arranging for
testing) must ensure that testing of the metering installation is
carried out:
(1) in accordance with:
(i) clause 7A.7.2 and this schedule; or
(ii) an asset management strategy that defines an
alternative testing practice (other than time based)
determined by the Metering Coordinator and approved
by NTESMO;
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(2) in accordance with a test plan that has been registered with
NTESMO;
(3) to the same requirements as for new equipment where
equipment is to be recycled for use in another site; and
(4) so as to include all data storage and processing components
specified in schedule 7A.7.
(d) The testing intervals may be increased if the equipment
type/experience proves favourable.
(e) The maximum allowable level of testing uncertainty (±) for all
metering equipment must be in accordance with Table S7A.6.1.1.
Table S7A.6.1.1 Maximum allowable level of testing uncertainty (±)
Description Metering Equipment Class
Class 0.2 Class 0.5 Class 1.0 General
Purpose
Class 2.0
In Laboratory
CTs
ratio
phase
0.05%
0.07 crad
0.1%
0.15 crad
n/a n/a n/a
VTs
ratio
Phase
0.05%
0.05 crad
0.1%
0.1 crad
n/a n/a n/a
Meters
Wh
0.05/cosφ% 0.1/cosφ% 0.2/cosφ% 0.2/cosφ% n/a
Meters
varh
n/a 0.2/sinφ% 0.3/sinφ% n/a 0.4/sinφ
%
In Field
CTs
ratio
Phase
0.1%
0.15 crad
0.2%
0.3 crad
n/a n/a n/a
In Field
CTs
ratio
Phase
0.1%
0.15 crad
0.2%
0.3 crad
n/a n/a n/a
VTs
ratio
0.1% 0.2% n/a n/a n/a
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Description Metering Equipment Class
Class 0.2 Class 0.5 Class 1.0 General
Purpose
Class 2.0
Phase 0.1 crad 0.2 crad
Meters
Wh
0.1/cosφ% 0.2/cosφ% 0.3/cosφ% 0.3/cosφ% n/a
Meters
varh
n/a 0.3/sinφ% 0.4/sinφ% n/a 0.5/sinφ
%
Where cosφ is the power factor at the test point under evaluation.
Table S7A.6.1.2 Maximum Period Between Tests
Unless the Metering Coordinator has developed an approved asset
management strategy that defines practices that meet the intent of
this schedule, the maximum period between tests must be in
accordance with Table S7A.6.1.2.
Description Metering Installation Type
Type 1 Type 2 Type 3 Type 4 & 4A Types 5
& 6
CT 10
years
10 years 10 years 10 years 10 years
VT 10
years
10 years 10 years n/a
Burden tests When meters are tested or when changes are made
CT
connected
meter
(electronic)
5 years 5 years 5 years 5 years 5 years
CT
connected
meter
(induction)
2.5
years
2.5 years 5 years 5 years 5 years
Whole
current meter
The testing and inspection requirements must be in
accordance with an approved asset management strategy.
Guidelines for the development of an asset management
strategy are set out in Schedule 7A.7
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Table S7A.6.1.3 Period between inspections
Unless the Metering Coordinator has developed an approved asset
management strategy that meets the intent of this schedule and is
approved by NTESMO, the maximum period between inspections
must be in accordance with Table S7A.6.1.3.
Description Metering Installation Type
Type 1 Type 2 Type 3 Type 4, 4A, 5
& 6
Metering
installation
equipment
inspection
2.5 years 12 months
(2.5 years if
check
metering
installed)
> 10 GWh:
2 years
2≤ GWh ≤ 10:
3 years
<2 GWh: when
meter is tested.
When meter
is tested.
S7A.6.2 Technical guidelines
(a) Current transformer and voltage transformer tests are primary
injection tests, or other approved testing procedures as approved
by NTESMO.
(b) The calculations of accuracy based on test results are to include all
reference standard errors.
(c) An "estimate of testing uncertainties" must be calculated in
accordance with the ISO "Guide to the Expression of Uncertainty
for Measurement".
(d) Where operational metering is associated with settlements metering
then a shorter period between inspections is recommended (but is
not mandatory).
(e) For sinφ and cosφ, refer to the ISO "Guide to the Expression of
Uncertainty in Measurement", where cosφ is the power factor.
(f) A typical inspection may include:
(1) check the seals;
(2) compare the pulse counts;
(3) compare the direct readings of meters;
(4) verify meter parameters and physical connections; and
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(5) current transformer ratios by comparison.
Schedule 7A.7 Metrology procedure
Part A
S7A.7.1 Introduction
S7A.7.1.1 General
(a) This schedule applies to NTESMO, Registered Participants,
Metering Coordinators, Metering Providers, Metering Data
Providers and the Utilities Commission in relation to connection
points in this jurisdiction.
(b) This schedule provides information on the application of metering
installations to connection points and sets out provisions for
metering installations and metering data services.
(c) For service provision at connection points where:
(1) the Metering Provider and the Metering Data Provider are part
of the same company; and
(2) metering installation, provision or maintenance work is
performed using internal processes and procedures,
those internal processes and procedures will be taken to be
compliant with this schedule if the metering work satisfies the
performance and quality outcomes of this schedule.
S7A.7.1.2 Definitions
In this schedule:
accumulation meter means a meter where the energy data
recorded in the meter represents a period in excess of a recording
interval.
estimated reading means:
(a) an estimate of a meter reading where an actual meter reading
has not occurred; or
(b) a substitute of a meter reading used for the purposes of
transferring a retail customer to a new Retailer where an
actual meter reading has not occurred.
final reading means the last actual meter reading for a retail
customer when they vacate an address or change retailer or the
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last actual meter reading taken before all or any part of a metering
installation is removed or modified and where the modification
affects the energy data in the metering installation.
ILAC means International Laboratory Accreditation Cooperation.
inventory table means a table of devices for unmetered loads
associated with each NMI as described in clauses S7A.7.14.2(c)
and S7A.7.14.3(c).
load table means a table of unmetered device loads as described
in clause S7A.7.14.1.
on/off table means a table recording the switching status (On = 1,
Off = 0) for each recording interval for the unmetered loads
associated with a NMI as described in Part B of this schedule.
physical inventory means a physical count of devices.
public holiday means a day that is a public holiday, as defined in
section 17 of the Interpretation Act 1978 (NT), that is observed in
the City of Darwin, other than a public holiday that is part of a day.
routine testing, for the purposes of this schedule, includes the
ongoing and regular maintenance testing, compliance testing and
in-service testing of metering installation components initiated by
the Metering Coordinator or Metering Provider to fulfil their
obligations in accordance with schedule 7A.6.
Sample Test Plan means a statement of the sample size or sizes
to be taken, the frequency of sample testing and the required
accuracy.
scheduled reading date means the date of the next scheduled
meter reading.
unmetered means a load or a connection point at which a meter is
not necessary under schedule 7A.6.
S7A.7.1.3 Relevant retailer
In this schedule, a reference to the relevant retailer is a reference to
Power Retail Corporation (trading as Jacana Energy) ABN 65 889
840 667.
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Part B
S7A.7.2 Purpose and scope
S7A.7.2.1 Purpose
The purpose of this Part is to set out:
(a) the obligations of the Metering Coordinator, in relation to
metering installations that are referred to in the Rules;
(b) the obligations of Metering Providers in relation to the
provision, installation, routine testing and maintenance of a
metering installation; and
(c) the obligations of Metering Data Providers in relation to the
provision of metering data services.
S7A.7.2.2 Scope
This schedule provides information on the application of metering
installations to connection points. In particular, this schedule sets
out provisions for metering installations and metering data services
relating to:
(a) Metering Providers, which include:
(1) the type of metering installation permitted for the
measurement of active energy;
(2) the provision, installation, testing, inspection and
maintenance of metering installations;
(3) the components of each type of metering installation;
and
(4) storage of, and access rights to, energy data in the
metering installation; and
(b) Metering Data Providers, which include:
(1) the collection or calculation, processing and delivery of
metering data; and
(2) storage of metering data in the metering data services
database and rights of access to metering data.
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S7A.7.3 Metering provision
S7A.7.3.1 Responsibility for metering provision
(a) Metering Coordinators must use Metering Providers to provide,
install, test and maintain the relevant components, characteristics
and service requirements of the metering installation as specified in
the Rules.
(b) Metering Coordinators are responsible for the design of a metering
installation and warrant that the design complies with the
components, characteristics and service requirements specified in
the Rules.
(c) Metering Coordinators must ensure the components have been
selected, installed, tested and commissioned by the Metering
Providers so that the metering installation satisfies the relevant
accuracy and performance requirements in the Rules.
S7A.7.3.2 Metering installation components
(a) Meters used in type 1, 2, 3, 4, 4A, 5 and 6 metering installations
must comply with any applicable specifications or guidelines
(including transitional arrangements) specified by the National
Measurement Institute, under the National Measurement Act, and
must also meet the relevant requirements of Australian Standards
and International Standards:
(1) for type 1, 2, 3, 4, 4A, and 5 (including type 3 and 4 whole
current) metering installation measurement elements:
AS 62052.11, AS 62053.21 and AS 62053.22; and
(2) for type 6 metering installation measurement elements:
AS 1284.1, AS 62053.21 and AS 62052.11.
(b) Current transformers for type 1, 2, 3, 4, 4A, 5 and 6 metering
installations must meet the relevant requirements of AS 60044.1
and must also comply with any applicable specifications or
guidelines (including transitional arrangements) specified by the
National Measurement Institute under the National Measurement
Act.
(c) Voltage transformers for type 1, 2, 3, 4, 4A, 5 and 6 metering
installations must meet the relevant requirements of AS 60044.2,
AS 60044.3, AS 60044.5 and AS 1243 and must also comply with
any applicable specifications or guidelines (including transitional
arrangements) specified by the National Measurement Institute
under the National Measurement Act.
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(d) New current transformers and voltage transformers must comply
with current Australian Standards.
(e) In-service current transformers and voltage transformers must
comply with the Australian Standard that applied at the time of
installation.
(f) Unless otherwise permitted by the Rules, the Metering Coordinator
must ensure that new meters and related equipment used at a
connection point have a valid pattern approval issued under the
authority of the National Measurement Institute or, until relevant
pattern approvals exist, a valid type test certificate issued by a
NATA accredited laboratory or a body recognised by NATA under
the ILAC mutual recognition scheme. Relevant approval certificates
must be provided to the Utilities Commission on request.
(g) A visible display must be provided to display, at a minimum, the
cumulative total energy for each register measured by that metering
installation.
(h) Any programmable settings available within the metering
installation, or any peripheral device, which may affect the
resolution of displayed or stored data, must meet the relevant
requirements of AS 62052.11, AS 62053.21 and AS 62053.22 and
must comply with any applicable specifications or guidelines
(including transitional arrangements) specified by the National
Measurement Institute under the National Measurement Act.
S7A.7.3.3 Use of optical ports and pulse outputs
(a) Where requested by a financially responsible participant, the
Metering Coordinator must provide pulse output facilities
representing the quantity of electricity measured in accordance with
the relevant Australian Standard for that meter within a reasonable
time of receiving the request.
(b) For type 1, 2, 3, 4, 4A and 5 metering installations with a pulse
output, the measurement element pulse output must provide a
number of energy pulses in each integrating period commensurate
with the accuracy class of the metering installation when operating
at the top of the range of measurement of the metering installation
but may be set at a lower rate where the anticipated operating
range is significantly lower than the top of the range of
measurement of the metering installation.
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(c) A type 4A or 5 metering installation must have an optical port that
meets the AS 1284.10.2 or AS 62056.21 or a computer serial port
to facilitate downloading of 90 days of interval energy data for each
meter associated with the metering installation in 35 seconds or
less.
S7A.7.3.4 Load control equipment
Where the metering installation includes equipment for load control
or the measurement of reactive energy, the installation and
operation of that equipment will be governed by an instrument other
than the Rules, for example, a ‘use of system' agreement between
the Local Network Service Provider and the financially responsible
participant.
S7A.7.3.5 Data storage requirements for meters
Note
No specific requirements are included under this heading for this jurisdiction at
this stage. The clause may be used as part of the phased implementation of the
Rules in this jurisdiction.
S7A.7.3.6 Metering installation clock
(a) A type 4A, 5 or 6 metering installation clock is to be reset to within ±
20 seconds of Australian Central Standard Time on each occasion
that the metering installation is accessed in the circumstances
referred to in paragraphs (b) and (c), and the maximum drift in the
type 4A or 5 metering installation clock permitted between
successive meter readings is ± 300 seconds.
(b) A Metering Provider must reset a type 4A, 5 or 6 metering
installation clock when inspecting, maintaining or commissioning
the metering installation.
(c) A Metering Data Provider must reset a type 4A, or 5 metering
installation clock when interval metering data is collected from the
metering installation.
(d) For type 6 metering installations with different time of day rates, the
metering installation must meet AS 62054.11, AS 62054.21 and
AS 62052.21, or have the switching between the different rates
controlled by a frequency injection relay or time clock operated by
the Local Network Service Provider.
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S7A.7.3.7 Interval meters
Where a metering installation records interval energy data the
interval periods must be based on recording intervals or parts of a
recording interval in accordance with the following requirements:
(a) the end of each interval for a 15-minute interval period must
be on the hour, on the half-hour and on each quarter of an
hour (ACST);
(b) the end of each interval for a 30-minute interval period must
be on the hour and on the half-hour (ACST);
(c) for other sub-multiple intervals –where agreed with NTESMO
(in respect of a metering installation that is used for the
purposes of settlements), the Local Network Service Provider
and the relevant financially responsible participant, provided
that the ends of the intervals correspond each and every exact
hour (ACST) and half-hour (ACST).
S7A.7.3.8 Alarm settings
(a) Where an interval meter supports alarm functionality, the Metering
Provider is required to enable the following alarms:
(1) power failure/meter loss of supply for instrument transformer
connected metering installations only;
(2) voltage transformer or phase failure;
(3) pulse overflow;
(4) cyclic redundancy check error; and
(5) time tolerance.
(b) Where there are alarm sensitivity settings, these must be set at
appropriate levels to ensure meaningful alarm outputs (for example,
for contestable supplies a voltage drop of -15% is nominally
appropriate).
S7A.7.3.9 Summation metering
(a) If summation metering is achieved by paralleling current
transformer secondary circuits, the overall metering system must
meet the minimum standards for a new metering installation under
all load combinations of the individual current transformer
secondaries.
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(b) If summation metering is achieved by the arithmetic sum of data
registers or the accumulation of pulses, each individual metering
point must meet the minimum standards for a new metering
installation and the Metering Coordinator must on request
demonstrate that the summation techniques reliably and accurately
transfer data.
(c) Current transformer secondaries can only be paralleled using
appropriate arrangements of links; this must not be done at the
meter terminals.
(d) For type 2 metering installations only – direct summation, in which
secondary wiring from a multiple number of feeders are connected
directly into the terminals of a meter, or summation current
transformers, are permitted provided that the overall errors of the
installation are considered.
S7A.7.3.10
Note
No requirements are included in this clause for this jurisdiction at this stage. The
clause may be used as part of the phased implementation of the Rules in this
jurisdiction.
S7A.7.3.11 Routine testing and inspection of metering installations
(a) Unless a Metering Coordinator has an Asset Management Strategy
approved by NTESMO, metering installations must be tested and
inspected in accordance with rule 7A.7 and schedule 7A.6.
Paragraphs (b) to (f) provide guidelines that:
(1) the Metering Coordinator will need to take into consideration
when seeking approval of an Asset Management Strategy;
and
(2) NTESMO will need to take into consideration in approving a
proposed Asset Management Strategy.
(b) An acceptable alternative testing practice or test plan for in-service
meter performance must demonstrate compliance with Australian
Standard "AS 1284.13: Electricity Metering in-service compliance
testing".
(c) Unless the Metering Coordinator has developed an alternative
accuracy assessment method for type 5 and 6 metering
installations that meets the intent of Tables S7A.4.2.5 and
S7A.4.2.6 and is approved by NTESMO, the overall metering
installation error is calculated by the vector sum of the errors of
each metering installation component, being a + b + c where:
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a = error of VT and wiring
b = error of CT and wiring
c = error of meter.
(d) Where the Metering Coordinator is not testing and inspecting
metering installations in accordance with rule 7A.7 and
schedule 7A.6 (that is, not time-based), the Metering Coordinator
must include in its Asset Management Strategy an alternative
inspection practice that meets the requirements of schedule 7A.6.
(e) The Metering Coordinator must provide a copy of the Asset
Management Strategy to each relevant Metering Provider.
(f) For those meters for which new or amended pattern approval has
been received from the National Measurement Institute or, in the
absence of pattern approval, new or amended type testing has
been undertaken by a NATA accredited laboratory or a body
recognised by NATA under the ILAC mutual recognition scheme,
the Metering Coordinator must ensure that the Sample Test Plan
stipulates that this population of meter is tested at least once in the
first three years of being placed in service.
S7A.7.3.12 Requests for testing type 1 – 6 metering installations
(a) If requested by a Registered Participant with a financial interest in
the metering installation or the energy measured by the metering
installation, the Metering Coordinator must make arrangements for
the testing of the metering installation in accordance with
clause 7A.7.2 of the Rules.
(b) If requested by a Registered Participant with a financial interest in
the metering installation, the Utilities Commission must make
arrangements in accordance with clause 7A.7.4 of the Rules to
determine the consistency of metering data held in the metering
data services database and the energy data held in the type 1, 2, 3,
4, 4A, 5 and 6 metering installation.
(c) Where the Registered Participant requests a metering installation
test in accordance with paragraphs (a) and (b):
(1) the Metering Coordinator or the Utilities Commission (as
applicable) must use reasonable endeavours to conduct the
test within 15 business days of the request;
(2) if the requirement under subparagraph (1) would prevent the
Registered Participant's customer witnessing the test, then the
Metering Coordinator or the Utilities Commission may agree to
a mutually convenient time to conduct the test; and
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(3) the Metering Coordinator or the Utilities Commission (as
applicable) must, if requested, provide an estimate of costs
associated with the test prior to any test being undertaken.
S7A.7.4 Installation of meters and de-commissioning
S7A.7.4.1 General installation requirements
The Metering Coordinator must use reasonable endeavours to
ensure that, at the time of installation, a metering installation is:
(a) protected against damage;
(b) installed in such a way that it allows safe and unimpeded
access to the retail customer or any person whose obligation it
is to test, adjust, maintain, repair, or replace the metering
installation, or to collect metering data from the metering
installation; and
(c) available to the retail customer or any person whose obligation
it is to test, adjust, maintain, repair, or replace the metering
installation, or to collect metering data from the metering
installation via safe, convenient and unhindered access when
it is not located at the site.
S7A.7.4.2 Type 4A, 5 and 6 metering installations
The Metering Coordinator must ensure that when each type 4A, 5
or 6 metering installation is installed at a connection point, it is
checked such that it has the optical port, communications port and
visual display located so that the optical port, communications port,
or visual display can be readily accessed for meter reading.
S7A.7.4.3 Preliminary de-commissioning and removal of metering
equipment requirements
(a) Before de-commissioning all or any part of an existing metering
installation the Metering Provider undertaking the work must ensure
that:
(1) arrangements are put in place to ensure a final reading is
taken at the time of de-commissioning of all metering data
maintained in the existing meter; and
(2) the ownership of the existing meter is ascertained and
arrangements made for the meter to be returned to its owner
within 10 business days unless otherwise agreed with the
asset owner.
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(b) Where the metering data from the final reading is not transferred to
the relevant Metering Data Provider at the time of de-
commissioning, the owner must ensure the metering data or final
reading (as applicable), is provided to that Metering Data Provider
within 2 business days of receipt of the meter.
S7A.7.4.4
Note
No requirements are included in this clause for this jurisdiction at this stage. The
clause may be used as part of the phased implementation of the Rules in this
jurisdiction.
S7A.7.5
Note
No requirements are included in this clause for this jurisdiction at this stage. The
clause may be used as part of the phased implementation of the Rules in this
jurisdiction.
S7A.7.6 Responsibility for metering data services
S7A.7.6.1 Metering data storage
Note
No requirements are included in this clause for this jurisdiction at this stage. The
clause may be used as part of the phased implementation of the Rules in this
jurisdiction.
S7A.7.6.2 Verification of metering data for type 4, 4A, 5, 6 and 7
installations
To facilitate the verification of metering data for type 4, 4A, 5, 6
and 7 metering installations:
(a) each Metering Coordinator must ensure that a Sample Test
Plan is established and maintained in accordance with
Australian Standards "AS 1199: Sampling procedures for
inspection by attributes – Sampling schemes indexed by
acceptance quality limit (AQL) for lot-by-lot inspection" or
"AS 2490: Sampling Procedures and Charts for Inspection by
Variables for Percent Nonconforming" to validate that all
metering data stored in the metering data services database is
consistent with the energy data stored in the metering
installation or the physical inventory (as applicable);
(b) verification tests must be conducted in accordance with the
Sample Test Plan, which must not be less than once every 12
months;
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(c) the calculated metering data stored in a metering data
services database for a NMI is consistent with the physical
inventory if the error associated with calculating the energy
value for the sample, that is:
is within ± 2.0%; and
(d) if there is an inconsistency between the inventory table held in
a metering data services database for a type 7 metering
installation and the physical inventory, the physical inventory
is to be taken as prima facie evidence of the actual number of
unmetered devices.
Note
Provisions relating to type 7 metering installations will only apply in this
jurisdiction in the event of a type 7 metering installation being available in this
jurisdiction and after a 12 month transitional period allowing all participants to
achieve compliance.
S7A.7.6.3 Metering installation type 7 – sample testing
(a) For the purposes of sample testing type 7 metering installations, the
Metering Coordinator must ensure that the sample size is
determined using Table S7A.7.5.3.1. The sample is to be selected
from unmetered devices in the inventory table for a Metering
Coordinator.
(b) The Metering Coordinator must ensure that the sample size for the
first two validation tests is based on a ‘normal' sample size
indicated in Table S7A.7.5.3.1.
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Table S7A.7.5.3.1 -–Unmetered devices in inventory table
Number of Unmetered
Devices in Inventory Table
Sample Size
Reduced Normal Tightened
2 to 8 2 2 3
9 to 15 2 3 5
16 to 25 3 5 8
26 to 50 5 8 13
51 to 90 5 13 20
91 to 150 8 20 32
151 to 280 13 32 50
281 to 500 20 50 80
501 to 1200 32 80 125
1201 to 3200 50 125 200
3201 to 10000 80 200 315
10001 to 35000 125 315 500
35001 to 150000 200 500 800
150001 to 500000 315 800 1250
500001 to over 500 1250 2000
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(c) The Metering Coordinator must ensure that the sample size for
subsequent variation tests is based on the following:
(d) The Metering Coordinator must select sample unmetered devices
for a validation test from random geographic areas depending on
the sample size. The selection of the geographic area must be such
that each unmetered device has an equal chance of being included
in the sample.
(e) The Metering Coordinator must ensure that the validation test is
conducted at least once every 6 months, commencing from the first
validation test.
(f) Should the results of two consecutive validation tests, based on a
reduced sample size, be within the accuracy requirements for that
test, the Metering Coordinator must ensure that the next validation
test is conducted at least once every 12 months.
Reduced Current
sample size?
Tightened
Normal
Reduced Previous
sample size? Tightened
Normal
Previous test
within
accuracy
requirement?
No
Yes
Yes
Yes Current test
within
accuracy
requirement?
No
Current test
within
accuracy
requirement?
No
Next
sample
size -
Tightened
Next
sample size
- Reduced
Next sample
size - Normal
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S7A.7.6.4 Request for text of calculated metering data
If requested to test a type 7 metering installation by a Registered
Participant under clause 7A.7.2, the Metering Coordinator must:
(a) arrange to test that the calculated metering data stored in the
metering data services database reflects the physical
inventory for the type 7 metering installation;
(b) use reasonable endeavours to conduct the test within
15 business days of the request; and
(c) prior to any test being undertaken, provide an estimate of
costs associated with the test.
S7A.7.6.5 NTESMO's metering data substitution obligations
(a) Where metering data has been substituted, NTESMO must advise
affected Registered Participants at the same time as that metering
data is sent to financially responsible participants for settlements.
(b) If metering data has not been transferred to NTESMO to meet the
settlements time frames or such metering data has been
transferred but is unusable, NTESMO must, in accordance with
clause 7A.9.2:
(1) take action to obtain the metering data; or
(2) request the Metering Coordinator take action to obtain the
metering data.
Part C
S7A.7.7 Purpose and scope
S7A.7.7.1 Purpose
The purpose of this Part is to set out obligations concerning the
validation, substitution and forward estimation of metering data to
satisfy the Rules.
S7A.7.7.2 Scope
(a) This Part applies to Metering Data Providers, NTESMO and
Metering Coordinators.
(b) This Part must be read in conjunction with Schedule 7A.8 Part B.
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S7A.7.8 Principles for validation, substitution and
estimation
S7A.7.8.1 General validation, substitution and estimation requirements
The principles to be applied to validation, substitution and
estimation include the following:
(a) the Metering Coordinator must coordinate the resolution of
issues arising from the non-performance of metering systems,
including any liaison with associated Registered Participants,
Metering Providers and Metering Data Providers, and the
Metering Coordinator must respond promptly to requests for
remedial action from the Metering Data Provider or NTESMO;
(b) the Metering Data Provider must identify metering data errors
resulting from data collection and processing operations using
validation processes in accordance with this Part.
S7A.7.8.2 Substitution requirements
(a) The Metering Data Provider must undertake substitutions on behalf
of NTESMO or the Metering Coordinator, as appropriate, in a
manner consistent with this Part.
(b) Substitutions may be required in the following circumstances:
(1) where the system or equipment supporting the remote or
manual collection of metering data has failed or is faulty;
(2) where the metering installation for a connection point has
failed or is removed from service;
(3) to enable timely provision of metering data to financially
responsible participants or NTESMO for billing transactions or
settlements purposes, as relevant;
(4) in situations where metering data has been irretrievably lost;
(5) where the metering data is found to be erroneous or
incomplete;
(6) where metering data has not completed validation as part of
the registration or transfer of a connection point;
(7) where metering data has failed or has not completed the
validation process;
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(8) where metering data cannot be obtained in the performance
timeframes required for the data period in question:
(i) metering data for metering installations with remote
acquisition must be substituted if metering data cannot
be obtained to meet either settlements or billing
transactions timeframes, as relevant, or the required
performance in Schedule 7A.8 Part C; and
(ii) metering data for manually read metering installations
must be substituted if metering data cannot be obtained
on or within the expected timeframe of the next
scheduled reading date for a connection point, and any
historical or previous estimated metering data must be
replaced with substituted metering data;
(9) when an inspection or test on the metering installation
establishes that a measurement error exists due to a metering
installation fault;
(10) when the affected financially responsible participant, the
relevant retailer and Local Network Service Provider have all
agreed and subsequently informed the Metering Data Provider
that a previous substitution was inaccurate and that a re-
substitution of metering data is required;
(11) where the metering data calculation has failed the validation
tests for a metering installation with calculated metering data;
(12) in response to customer transfers authorised in this
jurisdiction;
(13) in situations involving meter churn.
S7A.7.8.3 Estimation requirement
(a) The Metering Data Provider must undertake estimations on behalf
of the Metering Coordinator in a manner consistent with this Part.
(b) Estimations may be required in the following circumstances:
(1) routinely for a period equal to or just greater than the period to
the next scheduled reading date or another forward period;
(2) in response to customer transfers authorised in this
jurisdiction;
(3) where the current published scheduled reading date has
changed due to a revised scheduled reading route and the
existing estimated metering data does not extend to or beyond
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the revised next scheduled reading date, and in this case the
Metering Data Provider must adjust the estimated metering
data for the revised next scheduled reading date.
S7A.7.8.4 Metering data quality flags
(a) The Metering Data Provider must assign the relevant metering data
quality flags to metering data as follows:
Quality Flag Description
A Actual metering data.
S For any substituted metering data that is considered temporary
and may be replaced by actual metering data. Substitutions
apply to historical date/time periods at the time of substitution.
E For any estimated metering data that is considered temporary
and may be replaced by actual metering data or substituted
metering data. Estimations apply to a period that has an end
date/time in the future.
F For substitutions that are of a permanent or final nature and,
subject to paragraph S7A.7.8.5(b) and (e), the metering data
would not be replaced by actual metering data at any time.
N This quality flag is only utilised within the interval metering data
file for instances where no metering data exists in the metering
data services database for the periods concerned.
(b) Unless specified otherwise in this Part, Metering Data Providers
must apply the following quality flag rules in the metering data
services database:
(1) ‘A' metering data can only be replaced with ‘A', ‘S' or ‘F'
metering data;
(2) ‘S' metering data can only be replaced with ‘A', ‘S' or ‘F'
metering data;
(3) ‘E' metering data can only be replaced with ‘A', ‘E', ‘S' or ‘F'
metering data;
(4) ‘F' metering data can only be replaced with ‘F' metering data
as per paragraph S7A.7.8.5(f) or ‘A' metering data as per
paragraph S7A.7.8.5(b) or S7A.7.8.5(h).
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S7A.7.8.5 Final substitution
The Metering Data Provider must undertake final substitutions in
the following circumstances:
(a) where a notice has been received from either the Metering
Coordinator or the Metering Provider detailing a failure of the
metering installation that affects the quality of the energy data;
(b) if actual metering data is unexpectedly recovered from the
metering installation and a final substitution has been
undertaken in accordance with paragraph (1), and in this case
the Metering Data Provider must replace the final substituted
metering data with the actual metering data and maintain a
record of the reason;
(c) where the Metering Data Provider must undertake final
substitutions following a meter churn;
(d) where the Metering Data Provider has received a notice that
the affected financially responsible participant, the relevant
retailer and Local Network Service Provider have agreed that
the metering data is erroneous and that a final substitution is
required;
(e) where NTESMO requests the provision of substitutions and
final readings in response to customer transfers authorised in
this jurisdiction where required for the purposes of
settlements;
(f) where the Metering Data Provider may undertake to replace
existing final substituted metering data with new final
substituted metering data in accordance with this Part;
(g) where the Metering Data Provider has found actual metering
data to be erroneous;
(h) where the Metering Data Provider is replacing type 6 final
substituted metering data with accumulated metering data that
spans consecutive meter readings on agreement with the
financially responsible participant, the relevant retailer and the
Local Network Service Provider.
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S7A.7.9 Substitution for acquisition of metering data from
remotely read metering installations
S7A.7.9.1 Application of S7A.7.9
(a) For metering installations with remote acquisition installed in
accordance with paragraph 7A.6.8(a), the Metering Data Provider
may perform substitutions in accordance with clause S7A.7.10.
(b) For all other metering installations with remote acquisition, the
Metering Data Provider must perform substitutions in accordance
with clause S7A.7.9.
S7A.7.9.2 Substitution rules
The Metering Data Provider must apply the following rules when
performing a substitution:
(a) the Metering Data Provider must obtain clear and concise
identification as to the cause of any missing or erroneous
metering data for which substitutions are required;
(b) the Metering Data Provider must undertake to do a type 11
substitution and use metering data obtained from any check
metering installation associated with the connection point as
the first choice considered for the source of metering data for
any substitutions undertaken;
(c) SCADA data, where available, may be used by the Metering
Data Provider as check metering data for substitutions;
(d) the Metering Data Provider may only undertake substitution
type 13 where substitution types 11 and 12 are not applicable
or cannot be carried out;
(e) for connection points where the financially responsible
participant is a generator:
(1) the Metering Data Provider may directly undertake
type 11, type 12 or type 13 substitutions if metering data
has failed validation;
(2) the Metering Data Provider may undertake type 16 or 18
substitutions following consultation and agreement with
the affected generator that the substituted metering data
is an accurate reflection of the interval metering data
concerned;
(3) if metering data cannot be collected from a metering
installation or substituted within the required timeframes,
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the Metering Data Provider must undertake type 19
substitutions as an interim until metering data can be
collected from the metering installation or substituted;
(f) the Metering Data Provider may only undertake substitution
types 14, 15, 16, 17, 18, or 19 where substitution types 11, 12
and 13 are not applicable or cannot be carried out;
(g) the Metering Data Provider may perform all substitution types
except type 16 or 18 without the agreement of the affected
financially responsible participant, Local Network Service
Provider or relevant retailer and the Metering Data Provider
may change the quality flag to an existing type 16 or 18
substitution without seeking further agreement from those
parties;
(h) the Metering Data Provider must notify the Local Network
Service Provider, relevant retailer and the financially
responsible participant for the connection point of any
substitution within two business days of the substitution being
carried out, and this notification is to be achieved via the
participant metering data file as detailed in the MDFF
Specification;
(i) where there is a metering installation malfunction that cannot
be repaired within the periods specified in clause 7A.6.9, the
Metering Data Provider must:
(1) where the metering installation malfunction is due to a
failure of the meter to correctly record interval energy
data and the Metering Coordinator has been granted an
exemption to repair the metering installation, substitute
the missing metering data in accordance with this Part;
(2) for type 1-3 metering installations and other instrument
transformer connected metering installations, and where
a metering installation malfunction is due to a failure of
the remote acquisition system, arrange for an alternative
method for the collection of metering data from the
metering installation in a timeframe that ensures the
Metering Data Provider complies with metering data
delivery requirements; or
(3) for non-instrument transformer connected metering
installations, and where a metering installation
malfunction is due to a failure of the remote acquisition
system, substitute the missing metering data in
accordance with this Part;
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(j) the Metering Data Provider must ensure that all substituted
metering data is replaced with actual metering data when it
becomes available.
S7A.7.9.3 Substitution types
Type 11 – Check data
(a) To perform a type 11 substitution, the Metering Data Provider must
use interval metering data obtained from the check metering
installation for that metering point where:
(1) the metering installation and check metering installation are
installed at the same connection point;
(2) the metering installation and check metering installation are
installed on different ends of a transmission line where the
difference due to transmission line losses can be accurately
determined; or
(3) the metering installation and the check metering installation
are installed across a parallel set of feeders having similar line
impedances between a common set of busbars.
Type 12 – Calculated
(b) To perform a type 12 substitution, the Metering Data Provider must
calculate the interval metering data to be substituted where they
relate to a single unknown feed to a node based on the other
known energy flows to or from that node.
Type 13 – SCADA
(c) To perform a type 13 substitution:
(1) the Metering Data Provider must use SCADA data provided by
NTESMO in the agreed format for substitution purposes,
which originates from a similar measurement point as the
meter;
(2) where SCADA data is inferior in accuracy or resolution and in
a dissimilar format to the metering data, (for example, 30 Min.
demand values). the Metering Data Provider may have to
adjust the data in both magnitude and form so that the
substitution is valid; and
(3) where SCADA data is to be used for Substitution, both the
provided ‘E' channel and ‘B' channel SCADA data streams
must be used.
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Type 14 – Like day
(d) To perform a type 14 substitution, the Metering Data Provider must
substitute missing or erroneous metering data using the nearest
equivalent day or like day method, as detailed in Table 1.
Table 1
TYPE 14
Substitution day Nearest equivalent day or like day (in
order of availability)
Monday Monday ##
Tuesday Tuesday## Wednesday## Thursday##
Wednesday# Thursday#
Wednesday Wednesday## Tuesday# Thursday##
Thursday# Tuesday##
Thursday Thursday## Wednesday# Tuesday#
Wednesday## Tuesday##
Friday Friday##
Saturday Saturday##
Sunday Sunday##
Substitutions for like day to be as detailed above, unless:
(a) No metering data is available on the first listed day, the next listed
preferred day is to be used. If there is no other suitable listed day, or
no metering data is available on any of the listed days type 15
substitution must be used.
(b) The substitution day was a public holiday, in which case the most
recent Sunday is to be used.
(c) The substitution day was not a public holiday and the listed day is a
public holiday, then the next listed preferred day that is not a public
holiday is to be used.
# Occurring in the same week as the substitution day.
## Occurring in the week preceding that in which the substitution day
occurs.
Type 15 – Average like day
(e) To perform a type 15 substitution, the Metering Data Provider may
substitute missing or erroneous metering data using the average
like day method, as detailed in Table 2.
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Table 2
TYPE 15
The interval metering data to be substituted will be calculated using an
average of the metering data from each corresponding interval from the
preceding 4 weeks, or any part of those. This averaging technique may be
applied in either of the following ways:
(a) where the averaged interval metering data is used to provide the
value for the metering data requiring substitution;
(b) where the averaged interval metering data is used to provide the
profile and is scaled to a pre-determined consumption value for the
metering data to be substituted.
Type 15 substitutions must not be used for public holidays.
Type 16 – Agreed method
(f) Where the Metering Data Provider is required to undertake
substitution for any period greater than seven days for type 1 –
3 metering installations or greater than 15 days for other metering
installation types, the Metering Data Provider must consult and use
reasonable endeavours to reach an agreement with the financially
responsible participants, relevant retailer and the Local Network
Service Provider for the connection point. This may include
changes to existing substitutions for any period where those
affected parties have directed that as a result of site or end user
information, the original substitutions are in error and a correction is
required.
Type 17 – Linear interpolation
(g) To perform a type 17 substitution, the Metering Data Provider may
substitute metering data for consecutive intervals up to, but not
exceeding two hours, by using simple linear interpolation.
Type 18 – Alternative
(h) To perform a type 18 substitution, the Metering Data Provider may
use an alternative method of substitution subject to agreement with
the financially responsible participants, relevant retailer and the
Local Network Service Provider for the connection point. The
specifics of this substitution type may involve a globally applied
method or a method where an adjusted profile is used to take into
account local conditions that affect consumption (for example, local
holiday or end user shutdown), or where alternative metering data
may be available for quality checks, such as using metering register
data.
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Type 19 – Zero
(i) The Metering Data Provider must undertake substitutions of ‘zero'
where:
(1) the Local Network Service Provider or the Metering Provider
has informed the Metering Data Provider of a de-energised
connection point or an inactive meter and the consumption is
reasonably believed to be zero; or
(2) substitutions are applicable for connection points where the
financially responsible participant is a Generator in
accordance with clause S7A.7.9.2.
S7A.7.10 Substitution and estimation for manually read
interval metering installations
S7A.7.10.1 Application of S7A7.10
(a) The substitution and estimation requirements in this
clause S7A.7.10 are only to be used for metering installations
where:
(1) interval metering data is manually collected as a scheduled
meter reading; or
(2) the metering installations have been installed with remote
acquisition in accordance with paragraph 7A.6.8(a).
(b) Where remote acquisition of metering data has failed at the
metering installation and manual collection of interval metering data
is required, the substitution requirements specified in
clause S7A.7.9 apply.
S7A.7.10.2 Substitution and estimation rules
(a) The Metering Data Provider must ensure that all substituted
metering data and estimated metering data are replaced with actual
metering data when it becomes available.
(b) The Metering Data Provider must obtain clear and concise
identification as to the cause of any missing or erroneous metering
data for which substitutions are required.
(c) Where there is a metering installation malfunction that cannot be
repaired within the periods specified in clause 7A.6.9, the Metering
Data Provider must substitute the missing metering data in
accordance with this Part.
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(d) The Metering Data Provider must only apply the following
substitution and estimation types:
(1) substitutions may be type 51, 52, 53, 54, 55, 56, 57 or 58;
(2) estimations may be type 51, 52, 56, 57 or 58.
(e) The Metering Data Provider must only use type 56 or 57
substitutions or estimations where the historical data does not
support the application of a type 51 or 52 substitution or estimation.
(f) The Metering Data Provider must notify the Local Network Service
Provider, the relevant retailer and the financially responsible
participant for the connection point of any substitution or estimation
within 2 business days of the substitution.
(g) Metering Data Providers must not perform type 53 or 55
substitutions or type 56 substitutions or estimations without the
agreement of the Local Network Service Provider, the relevant
retailer and the financially responsible participant for the connection
point. Metering Data Providers may change the quality flag to an
existing type 53 or 55 substitution or type 56 substitution or
estimation without seeking further agreement from those parties.
S7A.7.10.3 Substitution and estimation types
Type 51 – Previous years method (nearest equivalent day or
like day method)
(a) To perform a type 51 substitution, the Metering Data Provider must
provide a substitute or estimate using the metering data from the
nearest equivalent day or like day from the same, or similar, meter
reading period in the previous year. The nearest equivalent day or
like day is to be determined from Table 3.
Type 52 – Previous meter reading method (nearest equivalent
day or like day method)
(b) To perform a type 52 substitution, the Metering Data Provider must
provide a substitute or estimate using the metering data from the
nearest equivalent day or like day from the previous meter reading
period. The nearest equivalent day or like day is to be determined
from Table 3.
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Table 3
TYPE 51 or 52
Substitution day Nearest equivalent day or like day (in order
of availability)
Monday Monday ## Monday#
Tuesday Tuesday## Wednesday## Tuesday#
Wednesday#
Wednesday Wednesday## Tuesday## Thursday##
Wednesday# Thursday# Tuesday#
Thursday Thursday## Wednesday## Tuesday##
Thursday# Wednesday# Tuesday#
Friday Friday## Friday#
Saturday Saturday## Saturday#
Sunday Sunday## Sunday#
Substitutions or estimations for like day to be as detailed above, unless:
(a) no metering data is available on the first listed day, in which case the
next listed preferred day is to be used. If there is no other suitable day,
or no metering data is available on any of the listed days, type 52 must
be used;
(b) the substitution or estimation day was a public holiday, in which case
the most recent Sunday is to be used; or
(c) the substitution or estimation day was not a public holiday and the
listed day is a public holiday, in which case the next listed preferred
day that is not a public holiday, Saturday or Sunday is to be used.
## For type 51 utilise metering data from the corresponding week in
the previous year.
## For type 52 utilise metering data from the corresponding week of
the previous meter reading period.
# For type 51 utilise metering data from the week preceding the
corresponding week in the previous year.
# For type 52 utilise metering data occurring in the week preceding the
corresponding week of the previous meter reading period.
(c) Alternatively, the Metering Data Provider must provide substituted
metering data or estimated metering data using the average like
day method, as detained in Table 4.
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Table 4
TYPE 52 (Alternative)
The interval metering data for which substitution or estimation is to be carried
out will be calculated using an average of the metering data from each
corresponding interval from any part, or all, of the preceding 4 weeks. This
averaging technique may be applied in either of the following ways:
• where the averaged interval metering data is used to provide the value for
the metering data requiring substitution or estimation;
• where the averaged interval metering data is used to provide the profile
and are scaled to a pre-determined consumption value for the metering
data that are the subject of substitution or estimation.
Type 52 substitutes or estimates must not be used for public holidays.
Type 53 – Revision of substituted metering data
(d) To perform a type 53 substitution, the Metering Data Provider must
re-substitute or change substituted metering data to collecting an
actual meter reading, where the financially responsible participant,
the relevant retailer and the Local Network Service Provider have
agreed, on the basis of site or end user information, that the original
substituted metering data is in error and a correction is required.
Type 54 – Linear interpolation
(e) To perform a type 54 substitution, the Metering Data Provider may
substitute metering data for intervals up to, but not exceeding
2 hours, by using simple linear interpolation.
Type 55 – Agreed substitution method
(f) To perform a type 55 substitution, the Metering Data Provider may
undertake to use another method of substitution (which may be a
modification of an existing substitution type), where none of the
existing substitution types apply, subject to using reasonable
endeavours to form an agreement with the financially responsible
participant, the relevant retailer and Local Network Service Provider
for the connection point. The specifics of this substitution type may
involve a globally applied method.
Type 56 – Prior to first reading – agreed method
(g) Prior to the first actual meter reading and where no historical data
exists for the connection point, the Metering Data Provider may
provide a substitution or estimation for the interval metering data
using a method agreed between the financially responsible
participant, the relevant retailer and Local Network Service
Provider.
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Type 57 – Prior to first reading – customer class method
(h) [Not used]
Type 58 – Zero
(i) The Metering Data Provider must undertake substitutions or
estimations of ‘zero' where either the Local Network Service
Provider or the Metering Provider has informed the Metering Data
Provider of a de-energised connection point or an inactive meter
and where the consumption is known to be zero.
S7A.7.11 Substitution and estimation for metering
installations with accumulated metering data
S7A.7.11.1 Substitution and estimation rules
(a) The Metering Data Provider must replace all estimated metering
data with either actual metering data or substituted metering data
when:
(1) actual metering data covering all or part of the estimation
period is obtained;
(2) the scheduled meter reading could not be undertaken, by
replacing the estimated metering data with substituted
metering data with a quality flag of ‘F'; or
(3) the scheduled meter reading could not be undertaken, by
replacing the estimated metering data with substituted
metering data with a quality flag of ‘F' unless it was identified
that the metering installation no longer has an accumulation
meter installed, in which case a quality flag of ‘S' may be
used.
(b) Any final substituted metering data provided by the Metering Data
Provider must be re-validated, updated or re-calculated by the
Metering Data Provider when:
(1) the value of the metering data obtained at the next actual
meter reading is found to be less than the previous final
substitution; or
(2) the final substituted value is disputed and following
consultation and agreement with the financially responsible
participant, the relevant retailer and the Local Network Service
Provider for the connection point, the new agreed value will be
determined using type 64 substitution.
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(c) The Metering Data Provider must obtain clear and concise
identification as to the cause of any missing or erroneous metering
data for which substitutions are required.
(d) The Metering Data Provider may apply the following substitution
and estimation types:
(1) substitutions may be type 61, 62, 63, 64, 65, 66, 67 or 68;
(2) estimations may be type 61, 62, 63, 65 or 68.
When to use Type 62 substitution
(e) Where the scheduled meter reading cycle is less frequent than
monthly, the Metering Data Provider may only use a type 62
substitution or estimation method when metering data from the
same, or similar, meter reading period last year (that is, type 61) is
not available.
When to use Type 63 substitution
(f) The Metering Data Provider may use type 63 substitutions or
estimations only when the metering data from the same, or similar,
meter reading period last year and metering data from the previous
meter reading period is not available (that is, when type 61 and
type 62 substitution or estimation methods cannot be used).
When to use Type 65 substitution
(g) The Metering Data Provider may use type 65 substitutions or
estimations only when the metering data from the same, or similar,
meter reading period last year or the metering data from the
previous meter reading period is not available (that is, when type 61
and type 62 substitution or estimation methods cannot be used).
When to use Type 67 substitution
(h) The Metering Data Provider must only use a type 67 substitution
when:
(1) directed by the Metering Coordinator;
(2) not expressly disallowed in this jurisdiction;
(3) the retail customer-provided meter reading meets the
validation rules for that data stream; or
(4) the Metering Data Provider has no actual metering data.
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When to use Type 64 or 66 substitution
(i) Metering Data Providers must not perform type 64 or 66
substitutions without seeking the agreement of the financially
responsible participant, the relevant retailer and the Local Network
Service Provider for the connection point. Metering Data Providers
may, however, undertake to change the quality flag to an existing
type 64 or 66 substitution without seeking further agreement from
those parties.
(j) The Metering Data Provider must notify the relevant parties for the
connection point of any substitution or estimation within 2 business
days of the substitution or estimation. Notification must comply with
the obligations set out in S7A.8.9.11.
S7A.7.11.2 Substitution and estimation types
Type 61 – Previous year method (average daily consumption
method
(a) To perform a type 61 substitution, the Metering Data Provider must
provide a substitution or estimation of the meter reading by
calculating the energy consumption as per the following formula:
Type 62 – Previous meter reading method (average daily
consumption method)
(b) To perform a type 62 substitution, the Metering Data Provider must
provide a substitution or estimation of the meter reading by
calculating the energy consumption as per the following formula:
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Type 63 – Customer class method
(c) To perform a type 63 substitution, the Metering Data Provider must
provide a substitution or estimation by calculating the energy
consumption as per the following formula:
Type 64 – Agreed method
(d) To perform a type 64 substitution, the Metering Data Provider may
undertake to use another method of substitution (which may be a
modification of an existing substitution type), where none of the
existing substitution types are applicable, subject to using
reasonable endeavours to form an agreement with the financially
responsible participant, the relevant retailer and Local Network
Service Provider for the connection point. The specifics of this
substitution type may involve a globally applied method.
Type 66 – ADL method
(e) [Not used]
Type 66 – Revision of substituted metering data
(f) To perform a type 66 substitution, the Metering Data Provider must
re-substitute or change substituted metering data prior to collecting
an actual meter reading where the financially responsible
participant, the relevant retailer and the Local Network Service
Provider for the connection point have agreed to revise the original
substituted metering data, on the basis of site or end user specific
information.
Type 67 – Customer reading
(g) Unless the Metering Data Provider is required to apply a type 68
substitution, the Metering Data Provider must substitute any
previously substituted metering data or estimated metering data
based directly on a meter reading provided by an end user.
Type 68 – Zero
(h) The Metering Data Provider must undertake substitutions or
estimations of ‘zero' where either the Local Network Service
Provider or Metering Provider has informed the Metering Data
Provider of a de-energised connection point or an inactive meter
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and where the consumption is known to be zero.
S7A.7.12 Substitution and estimation for calculated
metering data
S7A.7.12.1 Substitution rules
(a) The Metering Data Provider must:
(1) obtain clear and concise identification as to the cause of any
missing or erroneous calculated metering data for which
substituted metering data are required;
(2) ensure that all substituted metering data and estimated
metering data are based on calculated metering data and not
on any previous substitutions or estimations (as applicable);
(3) base calculated metering data for type 7 metering installations
on inventory table data as follows:
(i) where the inventory table has not been updated for the
period concerned, calculated metering data must be
based on the most recent available information and
provided as an estimate; and
(ii) where the inventory table is correct for the period
concerned, the calculated metering data must be flagged
as ‘A' metering data, however, when the inventory table
is subsequently updated for the period concerned, the
calculated metering data must be flagged as ‘F' metering
data;
(4) notify the Local Network Service Provider, the relevant
retailer and the financially responsible participant for the
connection point of any substituted calculated metering
data within 2 business days of the substitution, and this
notification is achieved via the Participant metering data
file as detailed within Schedule 7A.8; and
(5) flag all calculated metering data substitutions as ‘F'.
(b) The Metering Data Provider may apply the following substitution
and estimations types:
(1) substitutions may be type 71, 72, 73, or 74;
(2) estimations may be type 75.
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S7A.7.12.2 Substitution and estimation types
Type 71 – Recalculation
(a) To perform a type 71 substitution, the Metering Data Provider must
substitute calculated metering data with the calculated metering
data obtained by a recalculation based on the current inventory
tables, load tables and on/off tables.
Type 72 – Revised tables
(b) Where the error in the calculated metering data is due to errors in
the inventory table, load table and on/off table, the Metering Data
Provider must substitute calculated metering data by a recalculation
based on the most recent inventory tables, load tables and on/off
tables in which there were no errors.
Type 73 – Revised algorithm
(c) Where the error in the calculated metering data is due to an error in
its calculation, the Metering Data Provider must substitute the most
recent calculated metering data for which there was no error.
Type 74 – Agreed method
(d) The Metering Data Provider may use another method of calculated
metering data substitution (which may be a modification of an
existing substitution type), where none of the existing substitution
types is applicable, subject to using reasonable endeavours to form
an agreement between the financially responsible participant, the
relevant retailer and Local Network Service Provider for the
connection point. The specifics of this substitution type may involve
a globally applied method.
Type 75 – Existing table
(e) The Metering Data Provider must provide an estimate for the
calculated metering data based on the most recent inventory table
until such time as an updated inventory table is received for the
period concerned.
S7A.7.13 Data validation requirements
S7A.7.13.1 Validation requirements for all metering installations
Metering Data Providers must manage systems and processes on
the basis that:
(a) stored metering data held in the meter buffer might be subject
to installation measurement error;
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(b) data delivered by reading systems, (for example, remote
reading systems, hand-held readers and conversion software)
might not be recovered from the meters without corruption;
and
(c) auditable validation procedures are of critical importance and
can have a direct impact on disputes. It is essential that
Metering Data Providers comply with these validation
procedures and that all metering data is subject to validation
prior to delivery to NTESMO, Registered Participants and
financially responsible participants.
S7A.7.13.2 Validation of interval metering data alarms
(a) The Metering Data Provider must validate interval metering data
against the following meter alarms when these are provided in the
meter:
(1) power failure/meter loss of supply;
(2) voltage transformer or phase failure;
(3) pulse overflow;
(4) cyclic redundancy check error; and
(5) time tolerance.
(b) Where interval metering installations assign alarms to the data
channel and the interval metering data concerned, the Metering
Data Provider must process the alarm along with the metering data
as part of the required validation.
(c) The Metering Data Provider must ensure that all metering data
alarm reports are signed off and dated by the person actioning the
data exception report review as part of the validation.
(d) The Metering Data Provider must validate all interval metering data
with all metering data alarms prior to providing to NTESMO,
Registered Participants or financially responsible participants.
(e) All Metering Data Provider exception reports must provide, for all
instances where the interval metering data was found to be
corrupted, an indication of the subsequent actions undertaken by
the Metering Data Provider.
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S7A.7.13.3 Validation within the meter reading process for manually
read metering installations
Validations during collection of interval metering data
(a) The validations to be performed by Metering Data Providers
responsible for the collection of interval metering data from
manually read metering installations are as follows:
(1) the meter serial number matches the recorded meter serial
number;
(2) the security of the metering installation is intact, for example,
meter seals are in place and in good order;
(3) the time synchronisation of the metering installation is correct
to ACST inclusive of any load control devices.
Validations during collection of accumulated metering data
(b) The validations to be performed by Metering Data Providers
responsible for the collection of accumulated metering data are as
follows:
(1) the value of metering data from the current meter reading ≥
the value of metering data from the previous meter reading;
(2) the value of metering data from the current meter reading is
valid against an expected minimum value;
(3) the value of metering data from the current meter reading is
valid against an expected maximum value;
(4) the meter serial number matches the recorded meter serial
number;
(5) the security of the metering installation is intact, for example,
meter seals are in place and in good order;
(6) the time synchronisation of the metering installation is correct
to ACST inclusive of any load control devices;
(7) the dial capacity is checked against the recorded dial capacity.
S7A.7.13.4 Validation as part of the registration process
General requirements
(a) Metering Data Providers must confirm information about the NMI is
provided to NTESMO, where this is required in accordance with
clause 7A.10.1, after any installation or change to a metering
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installation prior to the provision of any metering data to NTESMO
or Registered Participants for the purposes of settlements.
Validation of metering data from remotely read metering
installations
(b) Metering Data Providers must carry out the following validations
after any installation or change to a metering installation with
remote acquisition of metering data prior to the distribution of any
interval metering data to NTESMO, Registered Participants or
financially responsible participants for the purposes of settlements
or billing transactions:
(1) for instrument transformer connected metering installations,
the metering installation is recording metering data correctly,
in conjunction with the Metering Provider;
(2) for whole current metering installations, the metering data
correctly pertains to the registered metering installation;
(3) all data streams are captured.
Validation of interval metering data from manually read
metering installations
(c) The Metering Data Provider must carry out the following validations
in conjunction with the Metering Provider for manually read interval
metering installations after any changes to a metering installation
prior to the provision of any interval metering data to NTESMO,
Registered Participants or financially responsible participants for
the purposes of settlements or billing transactions:
(1) the metering data correctly pertains to the registered metering
installation;
(2) all data streams are captured.
Validation of accumulated metering data from manually read
metering installations
(d) Metering Data Providers must carry out the following validations,
following any changes to a metering installation and prior to the
provision of any accumulated metering data to NTESMO,
Registered Participants or financially responsible participants for
the purposes of settlements or billing transactions:
(1) the metering data correctly pertains to the registered metering
installation;
(2) all data streams are captured.
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Validation of type 7 metering installations
(e) Metering Data Providers must validate the calculated metering data
on registration of all metering installations to verify that the
inventory tables, load tables and on/off tables are complete and
correct for the specifics of the metering installation.
S7A.7.13.5 Validation of metering data
General
(a) For metering installations with remote acquisition installed in
accordance with paragraph 7A.6.8(a), the Metering Data Provider
may perform validation in accordance with clauses S7A.7.14.4 and
S7A.7.14.5, instead of clause S7A.7.14.2.
Validations for remotely read metering installations
(b) Metering Data Providers must, as a minimum, undertake the
following validations within the metering data services database for
metering installation types with remote acquisition of metering data:
(1) a check of all interval metering data against a nominated
maximum value:
(i) this validation is to ensure that erroneous interval
metering data spikes are trapped and substituted;
(ii) this check may additionally be performed in the polling
software;
(2) a check of the maximum value of active energy and reactive
energy:
(i) for current transformer metering installations, the
maximum value is to be initially determined by the
connected current transformer ratio of the metering
installation;
(ii) for whole current metering installations the maximum
rating of the meter is to be used;
(3) a check against a nominated minimum value or, alternatively,
a 'zero' check that tests for an acceptable number of zero
intervals values per day to be derived from the site's historical
metering data;
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(4) a check for null (no values) metering data in the metering data
services database for all data streams:
(i) the aim of this check is to ensure that there is a 100%
metering data set (and substitution for any missing
interval metering data is undertaken);
(ii) the minimum check required is to ensure that there is at
least one non-null active energy or reactive energy value
per interval per metering data stream;
(5) a check for the meter alarms referred to in clause S7A.7.13.2
and ensure:
(i) that a process is in place that captures these meter
alarms within the validation and ensures that any meter
alarm occurrences are retained as part of the metering
data audit trail;
(ii) the provision of details of the occurrences of meter
alarms to relevant Registered Participants within the
metering data file in accordance with the MDFF
Specification.
Validations for metering installations with checking metering
or partial check metering
(c) Metering Data Providers must undertake the following validations
by comparing the metering data and check metering data for all
metering installations that have associated check metering
installations or partial check metering installations:
(1) for metering installations where the check metering installation
duplicates the metering installation accuracy, the Metering
Data Provider must validate the metering installation data
streams and check metering data streams on a per interval
basis, and the average of the two validated metering data sets
will be used to determine the energy measurement;
(2) for installations where the check metering data validation
requires a comparison based on nodal balance (comparing
the sum energy flow to the busbar against energy flow from
the busbar):
(i) the Metering Data Provider must construct a validation
algorithm within the metering data services database
that will facilitate comparison of interval metering data for
each energy flow on a per interval basis;
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(ii) the Metering Data Provider must conduct an analysis of
the historical metering data for each connection point to
ascertain whether error differences in nodal balance are
acceptable;
(iii) the Metering Data Provider should use this information
to refine its validation algorithms to minimise the error
difference for each connection point, based on historical
metering data;
(iv) the maximum error difference considered acceptable for
any connection point is 1% on a per interval basis, and
the Metering Data Provider should minimise this for each
connection point, based on historical metering data;
(3) where the check metering installation is remote from the
metering installation (for example, at the other end of a
transmission line or the other side of a transformer):
(i) the Metering Data Provider must construct a validation
algorithm within the metering data services database
that will facilitate comparison of interval metering data
from the metering installation and the check metering
installation on a per interval basis with adjustment for
respective transformer or transmission line losses;
(ii) the Metering Data Provider must conduct an analysis of
the historical metering data for each connection point to
ascertain whether the error differences between the
metering data from the metering installation and check
metering installation are acceptable;
(iii) the Metering Data Provider should use this information
to refine its validation algorithms to minimise the error
difference for each connection point, based on historical
metering data;
(iv) the maximum error difference considered acceptable for
any connection point is 5% on a per interval basis, and
the Metering Data Provider should minimise this for each
connection point, based on historical metering data;
(4) for connection points where SCADA data is made available by
NTESMO for the purposes of validation, the Metering Data
Provider must validate the metering data by comparison of the
interval metering data against the SCADA data as provided by
NTESMO in the agreed format:
(i) the Metering Data Provider must construct a validation
algorithm within the metering data services database
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that will facilitate comparison of interval metering data
from the metering installation and the SCADA data on a
per interval basis;
(ii) the Metering Data Provider must conduct an analysis of
the historical metering data for each connection point to
ascertain whether error differences between the interval
metering data from the metering installation and the
SCADA data are acceptable;
(iii) the Metering Data Provider should use this information
to refine its validation algorithms to minimise the error
difference value for each connection point, based on
historical metering data;
(iv) the Metering Data Provider must construct an
appropriate validation algorithm as the SCADA data may
be derived from a different measurement point, have a
different interval collection period or have a different
base unit of measurement, (for example, power not
energy value) with allowances for a larger error of
measurement;
(5) the Metering Data Provider is only required to undertake
validation of metering data against the SCADA data on the
primary data channel i.e. only ‘B' channel validation where the
financially responsible participant is a Generator and only ‘E'
channel validation for loads, such as pumps.
Validations for interval metering data from manually read
metering installations with current transformers
(d) Metering Data Providers must, as a minimum, undertake the
following validations on interval metering data from manually read
metering installations with current transformers within the metering
data services database:
(1) a check of all interval metering data against a nominated
maximum value:
(i) this validation is to ensure that erroneous interval
metering data spikes are trapped and substituted;
(ii) this check may additionally be performed in the
collection software;
(2) a check of the maximum value of active energy, which must
initially be determined by the connected current transformer
ratio of the metering installation (maximum reactive energy
checks may also be performed as an option);
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(3) a check against a nominated minimum value or, alternatively,
a ‘zero' check that tests for an acceptable number of zero
interval values per day to be derived from the site's historical
metering data;
(4) a check for null (no values) metering data in the metering data
services database for all metering data streams:
(i) the aim of this check is to ensure that there is a 100%
metering data set (and that substitution for any missing
interval metering data is undertaken);
(ii) the minimum check required is to ensure that there is at
least one non-null active energy or reactive energy value
per interval per metering data stream;
(5) a check for meter alarms referred to in clause S7A.7.13.2 and
ensure that:
(i) a process is in place that captures these meter alarms
within the validation and ensures that any meter alarm
occurrences are retained as part of the metering data
audit trail; and
(ii) the relevant Registered Participants are notified of the
occurrences of these meter alarms within the metering
data file in the MDFF specification;
(6) where supported by the meter(s), validation for a given period
of interval metering data by comparison of the totalised
interval energy data (accumulation register reading) and the
change in the meter cumulative registers (energy tolerance); it
is acknowledged that this check would not identify current
transformer ratio changes that have occurred after initial
commissioning and have not been advised to the Metering
Data Provider;
(7) a check of the metering data for continuity and reasonability
over the meter reading period:
(i) check that no gaps in the metering data exist;
(ii) check that metering data for the expected period has
been delivered based on the scheduled meter reading
date.
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Validations for interval metering data from whole current
manually read metering installations
(e) Metering Data Providers must, as a minimum, undertake the
following validations on metering data from whole current manually
read interval metering installations within the metering data services
database:
(1) a check of all interval metering data against a nominated
maximum value:
(i) this validation is to ensure that erroneous interval
metering data spikes are trapped and substituted;
(ii) this check may additionally be performed in the
collection software;
(2) a check of the maximum value of active energy (maximum
reactive energy checks may also be performed as an option),
and the maximum value is to be initially set to the rating of the
meter;
(3) a check for null (no values) metering data in the metering data
services database for all metering data streams:
(i) the aim of this check is to ensure that there is a
100% metering data set (and that substitution for any
missing interval metering data is undertaken);
(ii) the minimum check required is to ensure that there is at
least one non-null active energy or reactive energy value
per interval per metering data stream;
(4) a check for meter alarms referred to in clause S7A.7.13.2 and
the Metering Data Provider is not required to validate the
interval metering data for power outage or power failure
alarms, but must ensure that:
(i) a process is in place that captures these meter alarms
within the validation and ensures that any meter alarm
occurrences are retained as part of the metering data
audit trail;
(ii) the relevant Registered Participants are notified of the
occurrences of these meter alarms within the metering
data file in accordance with the MDFF specification;
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(5) where supported by the meter(s), validation for a given period
of interval metering data by comparison of the totalised
interval energy data (accumulation register reading) and the
change in the meter cumulative registers (energy tolerance);
(6) a check of the metering data for continuity and reasonability
over the meter reading period:
(i) check that no gaps in the metering data exist;
(ii) check that metering data for the expected period has
been delivered based on the scheduled meter reading
date.
Validations for accumulation metering data from manually read
metering installations
(f) Metering Data Providers must undertake the following validations
within the metering data services database for metering
installations with accumulated metering data:
(1) a check against a nominated minimum value of metering data
collected from the metering installation;
(2) a check against a nominated maximum value of metering data
collected from the metering installation, and this is to be
applied to both the metering data collected from the metering
installation and the calculated energy consumption values;
(3) the current value of metering data collected from the metering
installation ≥ previous value of metering data collected from
the metering installation;
(4) the current value of metering data collected from the metering
installation is numeric and ≥ 0;
(5) the current date that metering data is collected from the
metering installation > the previous date that metering data
was collected from the metering installation;
(6) a check for null (no values) metering data in the metering data
services database for all metering data streams, and the aim
of this check is to ensure that there is a 100% metering data
set and substitution for any missing metering data is
undertaken.
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Validations for type 7 metering installations
(g) Metering Data Providers must undertake the following validations of
calculated metering data within the metering data services
database:
(1) a check against a nominated maximum calculated metering
data value;
(2) for subparagraph (1), calculated metering data value is
numeric and ≥ 0;
(3) a check for null (no values) calculated metering data for all
metering data streams, and the aim of this check is to ensure
that there is a 100% calculated metering data set (and
substitution for any missing calculated metering data has been
undertaken);
(4) a check of the inventory tables, load tables and on/off tables
using a process approved by the Metering Coordinator to
ensure that the correct version of these tables is being used
for the production of calculated metering data;
(5) a check against a nominated minimum value, or alternatively,
a ‘zero' check that tests for an acceptable number of zero
Interval values per day;
(6) calculated metering data date > previous calculated metering
data date.
S7A.7.14 Determination of metering data for unmetered
loads
Note
Obligations for determination of metering data for unmetered load, including
requirements and methodologies for calculating metering data and associated
responsibilities, will be considered in the event of a type 7 metering installation
being available in this jurisdiction and after a 12 month transitional period
allowing all participants to achieve compliance.
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S7A.7.14.1 Load table
Note
Responsibility for developing, maintaining and publishing the load table will be
considered in the event of a type 7 metering installation being available in this
jurisdiction and after a 12 month transitional period allowing all participants to
achieve compliance.
(a) The load table must set out:
(1) for each controlled unmetered device, its load (which includes
any associated control gear, in watts) for use in calculating
interval metering data in accordance with clause S7A.7.14.2;
and
(2) for each uncontrolled unmetered device, its annual energy
consumption in accordance with clause S7A.7.14.3. The
annual energy consumption is used to calculate the calculated
device wattage (in watts) which is used to calculate the
interval metering data for each device type as follows:
Where i = Uncontrolled unmetered device type i.
(b) Proposals to add a new unmetered device load to the load table
must include load measurement tests conducted by a NATA
accredited laboratory or an overseas equivalent.
(c) Agreement for an unmetered device load to be added to the load
table does not replace any obligation for an interested party to
obtain appropriate approvals related to the performance and
acceptance of use of the unmetered device.
S7A.7.14.2 Controlled unmetered devices
Metering data calculation
(a) The Metering Coordinator must ensure that the interval metering
data for controlled unmetered devices classified as a type 7
metering installation are calculated in accordance with the following
algorithm:
Interval metering data for TIj for NMI (in watt hours) =
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where:
i = device type
j = TI
k = proportion of device attributable to that NMI
TI is in minutes.
Unmetered device wattage/device wattage is determined from the
load table.
Unmetered device count/device count is determined from the
inventory table.
Period load is switched on is determined from the on/off table.
Inventory table
(b) For each NMI, a separate inventory table is required that identifies
each unmetered device type that forms part of the load and for
each unmetered device type lists:
(1) the unmetered device type;
(2) the form of on/off control – photoelectric cell control, timer
control, ripple control or other control;
(3) if timer control or ripple control, the on/off times for the timer
control or the ripple control system;
(4) if other control, the on/off times;
(5) if an unmetered device is shared with another NMI, the
proportion of load that is agreed by affected Registered
Participants to be attributable to that NMI (k), and each
k factor will be less than 1 and the sum of the k factors for a
shared unmetered device across each respective NMI must
be equal to 1;
(6) if an unmetered device is not shared with another NMI, the
k factor must be equal to 1;
(7) the number of such unmetered devices installed;
(8) the effective start date – the first day on which that record in
the inventory table is to be included in the calculation of
metering data for that NMI;
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(9) the effective end date – the last day on which that record in
the inventory table is to be included in the calculation of
metering data for that NMI; and
(10) the last change date – the date that record in the inventory
table was most recently created or modified.
(c) Each unmetered device in the inventory table is a unique
combination of physical hardware, time control classification and
shared portion. For example, if an unmetered device is shared with
another NMI, the individual portions of the unmetered device(s)
must be included in the inventory table as a separate unmetered
device type on each NMI.
(d) Each Metering Coordinator must develop the initial inventory table
for the NMIs for which it is responsible. The initial inventory table
must be agreed by each affected Registered Participant and the
relevant end user.
(e) Each Metering Coordinator must update the inventory table for the
NMIs for which it is responsible on at least a monthly basis to
ensure that the accuracy requirements in clause S7A.7.6.2 are met.
Any changes to the inventory table may only be made on a
retrospective basis where:
(1) agreed by the Metering Coordinator and the affected
Registered Participants; or
(2) necessary to comply with clause 7A.7.4.
(f) The Metering Coordinator must communicate any material changes
to the inventory table to the affected Registered Participants.
(g) The Metering Coordinator must provide the inventory table to
relevant Registered Participants when requested.
On/off table
(h) The form of on/off control may be:
(1) photoelecetric;
(2) timer control, or ripple control; or
(3) other control.
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Photoelectric cell control
(i) The Metering Coordinator must ensure that the appropriate sunset
times and sunrise times are obtained from the Australian
Government Geoscience website
(www.ga.gov.au/geodesy/astro/sunrise.jsp), based on the longitude
and latitude of the relevant town and Australian Central Standard
Time.
(j) The Metering Coordinator must ensure that the period that the load
is switched on during a recording interval is calculated as follows:
Recording interval Period load is switched on
For the recording intervals
commencing after sunset and
finishing prior to sunrise
Period load is switched on = 1
For the recording intervals
commencing after sunrise and
finishing prior to sunset
Period load is switched on = 0
For the recording interval during
which the sunset occurs
(Period load is switched on) =
For the recording interval during
which the sunrise occurs
(Period load is switched on) =
Timer control
(k) If the on/off times for an unmetered device is controlled by a timer
or ripple injection system:
(1) On time = ON time set on timer or ripple injection system;
(2) Off time = OFF time set on timer or ripple injection system.
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(l) The Metering Coordinator must ensure that the period that the load
is switched on during a recording interval is calculated as follows:
Recording interval Period load is switched on
For the recording intervals
commencing after on time and
finishing prior to off time
Period load is switched on = 1
For the recording intervals
commencing after off time and
finishing prior to on time
Period load is switched on = 0
For the recording interval during
which the on time occurs
(Period load is switched on)=
For the recording interval during
which the off time occurs
(Period load is switched on)=
Other control
(m) Where the on/off times for an unmetered device are not in
accordance with paragraphs (i) to (m), the following alternative
forms of control may be used:
(1) On time = sunset time + ON delay or ON time set on timer or
ripple injection system;
(2) Off time = sunrise time + OFF delay or OFF time set on timer
or ripple injection system or a fixed duration after ON time.
(n) Where sunrise or sunset times are used, the time is determined in
accordance with paragraph (j).
(o) The Metering Coordinator must ensure that the period that the load
is switched on during a recording interval is calculated as follows:
Recording interval Period load is switched on
For the recording intervals
commencing after on time and
finishing prior to off time
Period load is switched on = 1
For the recording intervals
commencing after off time and
finishing prior to on time
Period load is switched on = 0
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Recording interval Period load is switched on
For the recording interval during
which the on time occurs
(Period load is switched on)=
For the recording interval during
which the off time occurs
(Period load is switched on)=
S7A.7.14.3 Uncontrolled unmetered devices
(a) [Not used]
Energy calculation
(b) The Metering Coordinator must ensure that the interval metering
data for other unmetered loads, which have been classified as a
type 7 metering installation, is calculated in accordance with the
following algorithm:
Inventory table
(c) For each NMI, a separate inventory table is required that identifies
each device type that forms part of the NMI load and for each
device type lists:
(1) the device type;
(2) the form of on/off control (24 hours per day);
(3) if a device is shared with another NMI, the proportion of load
that is agreed by relevant financially responsible participants
to be attributable to that NMI (k), and each k factor will be less
than 1 and the sum of the k factors for a shared unmetered
device across each respective NMI must be equal to 1;
(4) if a device is not shared with another NMI, the k factor must be
equal to 1;
(5) the number of such devices installed;
(6) the effective start date – the first day on which that record in
the inventory table is to be included in the calculation of
metering data for that NMI;
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(7) the effective end date – the last day on which that record in
the inventory table is to be included in the calculation of
metering data for that NMI; and
(8) the last change date – the date that record in the inventory
table was most recently created or modified.
(d) Each device in the inventory table is a unique combination of
physical hardware, time control classification and shared portion.
For example, if a device is shared with another NMI, the individual
portions of the device(s) must be included in the inventory table as
a separate device type on each NMI.
(e) Each Metering Coordinator must develop the initial inventory table
for the NMIs for which it is responsible. The initial inventory table
must be agreed by the relevant financially responsible participants
and the relevant end-use customer.
(f) Each Metering Coordinator must use reasonable endeavours to
update the inventory table, for the NMIs for which it is responsible,
on at least a monthly basis for any additions, deletions and
modifications to ensure that the accuracy requirements in
clause S7A.7.6.2 are met. Such additions, deletions or
modifications to the inventory table may only be made on a
retrospective basis where:
(1) agreed by the Metering Coordinator and the relevant
financially responsible participants; or
(2) necessary to comply with clause 7A.7.6.
(g) The Metering Coordinator must communicate any material changes
to the inventory table to the relevant financially responsible
participants.
(h) The Metering Coordinator must provide the inventory table to
relevant financially responsible participants when requested.
On/off table
(i) Other unmetered loads are assumed to operate 24 hours per day.
(j) For each recording interval period load is switched on = 1.
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Schedule 7A.8 Service level procedures
Part A Introduction
S7A.8.1 Introduction
S7A.8.1.1 Purpose and scope
(a) This schedule applies to Metering Providers and Metering Data
Providers.
(b) This schedule sets out:
(1) the requirements for the provision, installation and
maintenance of metering installations by Metering Providers;
(2) requirements for the systems and processes for the collection,
processing and delivery of metering data by Metering Data
Providers;
(3) the performance levels associated with the collection,
processing and delivery of metering data;
(4) the data formats that must be used for the delivery of metering
data;
(5) the requirements for the management of relevant NT NMI
Data; and
(6) the requirements for the processing of metering data
associated with connection point transfers and the alteration of
metering installations where one or more devices are
replaced.
S7A.8.1.2 Definitions
In this schedule:
collect, collection, collected mean a process undertaken by the
Metering Data Provider to obtain metering data from a meter or
metering installation.
Service Providers means Metering Data Providers, Metering
Providers and Local Network Service Providers.
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Part B Metering provider services
S7A.8.2 Introduction
S7A.8.2.1 Purpose and exclusions
(a) Part B of this schedule:
(1) details the obligations, technical requirements, measurement
process and performance requirements that are to be
performed, administered and maintained by a Metering
Provider;
(2) details the obligations and technical/operational requirements
in the provision, installation and maintenance of the metering
installation by a Metering Provider;
(3) relates to Metering Providers who undertake the provision,
installation and maintenance of various metering installation
types as stipulated; and
(4) sets out minimum requirements for Metering Providers.
(b) For service provision at connection points where:
(1) the Metering Provider and the Metering Data Provider are part
of the same company; and
(2) metering installation provision or maintenance work is
performed using internal processes and procedures,
those internal processes and procedures will be deemed to be
compliant with this Part if the metering work satisfies the
performance and quality outcomes of this Part.
S7A.8.2.2 Services
The Metering Provider is responsible for the provision of metering
provision services, including but not limited to:
(a) maintaining the ongoing metering installation compliance with
the Rules;
(b) the provision and maintenance of physical metering
installation security controls;
(c) the provision, installation and maintenance of the metering
installation;
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(d) the maintenance of metering installation password security;
and
(e) the development and maintenance of an Asset Test Plan.
S7A.8.3 General requirements
S7A.8.3.1 Metering Provider capability and competency
Metering Providers must:
(a) employ personnel with the skills, knowledge and expertise
necessary for the discharge of the responsibilities under
Chapter 7A and have procedures for ensuring that personnel
maintain their knowledge and understanding of the
requirements of the Rules;
(b) maintain a register of employees, which for each employee
must include:
(1) skills, knowledge and expertise;
(2) qualifications, registrations and accreditations where
applicable to the discharge of Metering Provider duties;
(3) training undertaken and planned;
(4) authorisations to provide opinions and interpretations of
technical information; and
(5) authorisations to access metering installations within
secure and restricted areas;
(c) have policies and procedures for making statements of
opinions and interpretations, documented within the quality
system;
(d) comply with:
(1) AS 3000 Wiring Rules;
(2) applicable Australian Communications and Media
Authority (ACMA) communications and cabling
requirements;
(3) C-Tick compliance requirements;
(4) jurisdictional legislation, including safety legislation and
regulations; and
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(5) any reasonable requirements of the Local Network
Service Provider when working on or around Local
Network Service Provider.
S7A.8.3.2 Use of contractors
Where a Metering Provider engages a sub-contractor to perform
any of its obligations specified in the Rules, the Metering Provider:
(a) must have policies and procedures for assessing the sub-
contractor's capability, competency and processes,
procedures and systems, to ensure that they are compliant
with the Rules;
(b) must ensure that auditable processes are in place to certify
that all work performed by the sub-contractor complies with
the Rules;
(c) remains liable for all acts and omissions of any sub-contractor;
and
(d) must authorise the sub-contractor to provide any specific
opinion or interpretation of technical information.
S7A.8.3.3 Insurance
The Metering Provider must:
(a) hold public liability insurance for an amount not less than
$10,000,000 per occurrence;
(b) hold professional indemnity insurance for an amount of not
less than $1,000,000 per occurrence; and
(c) provide the Utilities Commission with certified current copies
of insurance policies on request.
Note
If a Metering Data Provider, Metering Provider and Metering Coordinator are the
same legal entity, a single insurance policy for public liability insurance for an
amount not less than $10,000,000 per occurrence and professional indemnity
insurance for an amount of not less than $1,000,000 per occurrence that covers
the operations of the Metering Data Provider, Metering Provider and Metering
Coordinator roles will satisfy the insurance requirements under this schedule.
S7A.8.4 Device management and test equipment
S7A.8.4.1 Procurement
The Metering Provider must have processes and systems in place
for the procurement of meters, instrument transformers and any
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other devices that can be installed by the Metering Provider within a
metering installation, and ensure that metering installation
components are suitable for use in accordance with the Rules.
S7A.8.4.2 Storage, handling and transport
(a) The Metering Provider must have processes that are consistent
with good industry practice, specifying the requirements for storage,
handling (including packaging) and transport (including return to
owner) of any equipment that is calibrated including meters,
instrument transformers and test equipment. The processes must
be designed to:
(1) minimise the risk of physical or environmental damage to the
equipment; and
(2) identify conditions under which the physical condition of the
equipment or accuracy is compromised as a result of storage,
transport or handling.
(b) The Metering Provider must ensure that meters, instrument
transformers and devices removed from the metering installation
are returned to their owner within 10 business days following their
removal, unless otherwise agreed with the owner.
S7A.8.4.3 Management of test equipment
The Metering Provider must:
(a) establish a register of test equipment used for testing metering
installations, meters and instrument transformers;
(b) maintain records of test equipment, including records of
calibration certificates, for at least 7 years from the issue date
of the calibration certificate;
(c) ensure that all test equipment is calibrated by a NATA
accredited testing laboratory holding ISO 9001 and 17025
accreditation for the calibration of test equipment, current at
the time of calibration; and
(d) ensure that all tests are undertaken with test equipment where
the calibration certificate is current and stated calibration due
date has not passed.
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S7A.8.4.4 Management of meter programming and authorised software
The Metering Provider must:
(a) establish a register of equipment and authorised software
used for programming meters; and
(b) maintain records of equipment, authorised software and
programs used for programming meters, including any
changes to firmware or software within the meter, for at least
7 years from the most recent date of use.
S7A.8.5 Installation and commissioning requirements
S7A.8.5.1 General commissioning requirements
The Metering Provider must develop, maintain and operate
processes and procedures for the installation and commissioning of
metering installations for which they are accredited, which must
include installation and verification requirements to ensure that:
(a) electrical wiring at the metering installation is:
(1) wired and terminated in compliance with meter and
instrument transformer manufacturer requirements,
relevant Australian Standards and jurisdictional
requirements;
(2) terminated in a manner that ensures no electrical
conductors are exposed, that the cable type and size,
and number of cables terminated in any one termination
are appropriate and that all terminations are tight;
(3) of an appropriate cable type, size and insulation that
meets the requirements of AS 3000;
(4) connected with the correct polarity at each termination
and connection; and
(5) connected with the correct phase sequence, where three
phases are connected at the metering installation; in the
case of a change to an existing metering installation, the
existing phase sequence is maintained;
(b) the accuracy class of metering installations and any
documentation from a certified body verifying the errors of
meters and instrument transformers comply with the Rules;
(c) nameplate information reflects the design accuracy class of
the meters and instrument transformers;
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(d) the actual connected ratios of all instrument transformers at a
metering installation and the calculation of the constant to be
applied to the collection and processing of metering data by
the Metering Data Provider are aligned;
(e) burdens applied to instrument transformers are within the
rated burden specified on the name plate of the instrument
transformer;
(f) voltage phase sequence relationships are correct unless the
Metering Provider can verify to the satisfaction of NTESMO
the accuracy of the metering installation when a non-standard
phase sequence is applied;
(g) the combined current and voltage phase relationships at the
meter terminals are correct;
(h) the meter programming parameters, display and error
functions are all correct in accordance with manufacturer
specifications, including the measurement of the forward
rotation of energy applied to the meter, and that the correct
pulse rates have been programmed into the meter;
(i) where the metering installation includes instrument
transformers, register readings are validated by use of a load
being placed on the load side of the metering installation and
may include a timing check by comparing the readings on the
meter display or pulse indicators against load and time;
(j) where the metering installation has meter alarms, occurrences
of alarms identified on commissioning are investigated and
resolved prior to leaving the site;
(k) where an aerial or antenna is installed as part of the metering
installation, it is installed in accordance with the
manufacturer's instructions and in a manner that maintains the
integrity of the meter enclosure, including water and
environmental seals; and
(l) the time setting of the metering installation is referenced in
accordance with clause 7A.8.8.
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S7A.8.5.2 Metering data validation requirements
The Metering Provider must develop, maintain and operate
processes and procedures for the validation of interval metering
data with the Metering Data Provider on the installation or alteration
of that metering installation, which must include processes to
ensure that:
(a) metering data is validated in accordance with schedule S7A.7;
(b) where validation has failed or cannot reasonably be
undertaken, the Metering Provider informs the Metering Data
Provider and the Metering Coordinator that the metering
installation cannot be validated and undertake wiring checks
which visibly verify correct connection and phase relationships
of voltage and current circuits and also undertake one or more
of the following alternative measurements and commissioning
checks to enable the Metering Coordinator and Metering
Provider to confirm that the metering installation complies with
the Rules:
(1) utilisation of meter energy measurement to calculate
load/ demand and that this value is reflective of expected
magnitude;
(2) use of a dummy load or phantom load box to verify
correct energy measurement at the metering installation;
and
(3) compare meter measurement of energy or load with an
alternative measurement of demand, current and other
measurements of electrical energy;
(c) where the Metering Provider has undertaken in-situ testing to
verify correct energy measurement at the metering installation,
the Metering Provider informs the Metering Data Provider of
the start and end times of the test to facilitate the Metering
Data Provider substituting and validating metering data.
S7A.8.6 Metering installation maintenance
S7A.8.6.1 Test plans
(a) The Metering Provider must develop and maintain Asset Test Plans
that provide confirmation of the Metering Provider's testing
approach to ensure metering installations are maintained:
(1) in accordance with the testing and inspection requirements of
the Rules;
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(2) in accordance with approved Asset Management Strategies;
or
(3) in any combination of the above.
(b) As a minimum, the Metering Provider's Asset Test Plans must
include:
(1) the approach to testing and inspecting for each metering
installation, or groups of metering installations;
(2) where appropriate, the approach to testing and inspecting
various device types; and
(3) the details of the test equipment and test methodology to be
employed in undertaking works considered in the test plan.
S7A.8.6.2 Management of metering installation malfunctions
(a) The Metering Provider must have processes and systems to
support the Metering Coordinator in identifying and rectifying a
metering installation malfunction in the timeframes specified in
clause 7A.6.9.
(b) Where a Metering Provider identifies a metering installation
malfunction, the Metering Provider must advise the Metering Data
Provider and the Metering Coordinator within 1 business day of
identification in accordance with paragraph 7A.6.9(d).
S7A.8.6.3 Telecommunications
(a) The Metering Provider must advise the Metering Data Provider and
the Metering Coordinator if communications equipment is to be
temporarily disconnected such that it may affect the remote
acquisition of metering data.
(b) The Metering Provider must use reasonable endeavours to assist
the Metering Coordinator and the Metering Data Provider with the
manual collection of metering data from the metering installation
where remote acquisition becomes unavailable.
S7A.8.6.4 Non-conforming test results or calibrations
The Metering Provider must have a process for the management of
non-conforming test results or calibrations at a metering installation,
and for devices removed from a metering installation for testing and
evaluation, which must include:
(a) a process to perform the evaluation of the non-conformance;
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(b) authority for management of the non-conformance;
(c) notification of the non-conformance to parties affected by the
non-conformance, which must include the Metering
Coordinator, Metering Data Provider, financially responsible
participant, Local Network Service Provider and NTESMO;
and
(d) initiation of corrective action.
S7A.8.7 Systems and administration
S7A.8.7.1 Register of metering installations
(a) The Metering Provider must establish and maintain a register of
metering installations which must include:
(1) the identity and characteristics of metering equipment
(instrument transformers, metering installation and check
metering installation), including:
(i) serial numbers;
(ii) metering installation identification name;
(iii) metering installation types and models;
(iv) instrument transformer ratios (available and connected);
(v) current test and calibration programme details, test
results and references to test certificates;
(vi) asset management plan and testing schedule;
(vii) calibration tables, where applied to achieve metering
installation accuracy;
(viii) Metering Provider(s) and Metering Data Provider(s)
details;
(ix) summation scheme values and multipliers; and
(x) data register coding details;
(2) for metering installations for connection points in a market
operated or administered by NTESMO – any matters identified
by NTESMO in a communication guideline issued in from time
to time accordance with clause S7A.1.3.
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(b) The register must be retained electronically for at least 13 months
for each metering installation from when the details of the metering
installation are first recorded in the register and may be archived
after this period.
(c) The register must be retained for at least 7 years for each metering
installation from when the details of the metering installation are
first recorded in the register and any archiving retrieval mechanisms
must facilitate analysis and management of information using the
same processing rules applied to the electronic register.
(d) The Metering Provider must provide information from their register
of metering installations to a party authorised to receive data in
accordance with clause 7A.13.5 in a timeframe agreed with that
party.
S7A.8.7.2 Disaster recovery
(a) The Metering Provider must establish and maintain a disaster
recovery plan and business continuity processes that include:
(1) detailed documentation that is maintained up to date,
showing revisions and the date of the last review;
(2) confirmation at least annually by the Metering Provider's
management that the plan is current for the systems and
processes in place; and
(3) confirmation that the plan has been subjected to an
annual end-to-end test that facilitates both a ‘fail-over'
from and ‘recovery' back to the production system.
(b) In the event of an IT system failure, the Metering Provider must
ensure that systems are returned to normal operational service
within 5 business days of the failure, as evidenced by:
(1) the software and the most recent back-up of data being
restored to operational service within the 5 business days; and
(2) no outstanding processing or delivery of NT NMI Data to
NTESMO and Registered Participants.
(c) The Metering Provider must at its earliest opportunity notify
NTESMO of any failure where the Metering Provider has a
requirement to implement its disaster recovery plan.
S7A.8.7.3 Audits undertaken by the Utilities Commission
The Metering Provider must undertake all services in a manner that
is auditable by the Utilities Commission and must provide all
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reasonable assistance to the Utilities Commission in discharging its
obligations under the Rules and any relevant jurisdictional
legislation in relation to metering installations.
Part C Metering Data Provider services
S7A.8.8 Introduction
S7A.8.8.1 Purpose
(a) The purpose of Part C of this schedule is to detail the obligations,
technical requirements, measurement processes and performance
requirements that are to be performed, administered and
maintained by the Metering Data Provider.
(b) This Part details:
(1) the obligations of Metering Data Providers in the provision of
metering data services;
(2) the obligations of Metering Data Providers to establish and
maintain a metering data services database; and
(3) the obligations of Metering Data Providers in support of the
Metering Coordinator.
S7A.8.8.2 Obligations
Metering data services
(a) Each Metering Data Provider must:
(1) provide metering data services in accordance with the Rules
and relevant jurisdictional codes and policies;
(2) establish, maintain and operate a metering data services
database;
(3) ensure that metering data is kept confidential and secure and
only provided to persons entitled to have such access in
accordance with the Rules;
(4) undertake the collection, processing and delivery of metering
data and meter alarm occurrences; and
(5) co-operate in good faith with NTESMO, and all Registered
Participants, Metering Providers and Metering Data Providers.
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Insurance
(b) The Metering Data Provider must:
(1) hold public liability insurance for an amount not less than
$10,000,000 per occurrence; and
(2) hold professional indemnity insurance for an amount of not
less than $1,000,000 per occurrence.
Note
If a Metering Data Provider, Metering Provider and Metering Coordinator are the
same legal entity, a single insurance policy for public liability insurance for an
amount not less than $10,000,000 per occurrence and professional indemnity
insurance for an amount of not less than $1,000,000 per occurrence that covers
the operations of the Metering Data Provider, Metering Provider and Metering
Coordinator roles will satisfy the insurance requirements under this schedule.
Use of sub-contactors
(c) Where a Metering Data Provider engages a sub-contractor to
perform any of the Metering Data Provider's obligations specified in
the Rules, the Metering Data Provider:
(1) must have policies and procedures for assessing the sub-
contractor's capability, competency, processes, procedures
and systems, to ensure that the sub-contractor complies with
the Rules;
(2) must ensure that auditable processes are in place to certify
that all work performed by the sub-contractor complies with
the Rules;
(3) remains liable for all acts and omissions of its sub-contractor;
(4) must authorise the sub-contractor to provide any specific
opinion or interpretation of technical information where a
Metering Data Provider so engages a sub-contractor; and
(5) must provide the Utilities Commission, on request, with any
information pertaining to the sub-contractor that the Utilities
Commission reasonably considers necessary for the
discharge of the Metering Data Provider's responsibilities
under the Rules.
Specific obligations
(d) Each Metering Data Provider must:
(1) undertake validation, substitution and estimation of metering
data in accordance with schedule S7A.7 Part C;
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(2) provide metering data services;
(3) ensure registered details of the connection point are fully
recorded in the Metering Data Provider's metering data
services database;
(4) ensure metering details and parameters within the metering
data services database are correct such that the metering
data in the metering data services database is accurate;
(5) facilitate the timely commissioning and registration of the
metering installation; and
(6) establish and maintain a metering register in its metering data
services database.
Metering register
(e) Each Metering Data Provider must ensure that information in its
metering register is:
(1) registered in co-operation with the Metering Coordinator and
Metering Provider;
(2) provided on request to persons entitled to have access to that
information in accordance with paragraph 7A.13.5(c);
(3) communicated to other Metering Data Providers having the
right of access as a result of the transfer of a connection point;
(4) populated with the following:
(i) connection and metering point reference details,
including:
(A) agreed locations and reference details (for
example, drawing numbers);
(B) loss compensation calculation details;
(C) site identification names;
(D) details of financially responsible participants and
Local Network Service Providers associated with
the connection point;
(E) details of the Metering Coordinator;
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(ii) the identity and characteristics of metering equipment
(that is, instrument transformers, metering installation
and check metering installation), including:
(A) serial numbers;
(B) metering installation identification name;
(C) metering installation types and models;
(D) Metering Provider(s) and Metering Data Provider(s)
details;
(E) summation scheme values and multipliers; and
(F) data register coding details;
(iii) for types 1, 2, 3 and 4 metering installations, data
communication details, if relevant, including:
(A) telephone number(s) for access to energy data;
(B) communication equipment type and serial
numbers;
(C) communication protocol details or references;
(D) data conversion details;
(E) user identifications and access rights; and
(F) 'write' password (to be contained in a hidden or
protected field);
(iv) data validation, substitution and estimation processes
agreed between affected parties, including;
(A) algorithms;
(B) data comparison techniques;
(C) processing and alarms (for example, voltage
source limits; phase angle limits);
(D) check metering compensation details; and
(E) alternate data sources; and
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(5) for metering installations for connection points in a market
operated or administered by NTESMO, includes any relevant
matters identified by NTESMO in a communication guideline
issued from time to time in accordance with clause S7A.1.3.
S7A.8.9 Service requirements
S7A.8.9.1 System requirements
Each Metering Provider must maintain and operate a metering data
services database to facilitate the:
(a) collection of metering data;
(b) processing, calculation, validation, substitution and estimation
of metering data;
(c) delivery of metering data and metering register data to
NTESMO, Registered Participants, financially responsible
participants and other Service Providers;
(d) assignment and version control of participant roles for
connection points;
(e) commissioning of each metering installation into the Metering
Data Provider's metering data services database;
(f) loading of metering data relating to meter churn; and
(g) storage and archiving of metering data and validated metering
data from the metering installation.
S7A.8.9.2 Metering data services database
Each Metering Data Provider must maintain and operate a metering
data services database that provides a full audit trail and version
control capability. This functionality must be applied to:
(a) metering data;
(b) assigned data quality flags;
(c) substitution and estimation types;
(d) meter alarms;
(e) metering register information;
(f) the delivery of metering data to Registered Participants,
financially responsible participants and NTESMO; and
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(g) the mapping of all metering data streams (including logical
metering data streams).
S7A.8.9.3 Exception reports
Each Metering Data Provider must maintain, operate and monitor a
system that supports the detection of system or process errors.
These exception reports must include, but not be limited to:
(a) missed reads and missing intervals of metering data within the
metering data services database;
(b) long term substitutions and estimations;
(c) metering data errors and data overlaps;
(d) validation or metering register errors;
(e) failed batch processing, database errors and hardware
failures;
(f) the capture of file syntax errors, failed and rejected metering
data deliveries;
(g) status management of collection interfaces; and
(h) status management of metering installation malfunctions.
S7A.8.9.4 Collection process requirements
(a) Each Metering Data Provider must use reasonable endeavours to
ensure actual meter readings and occurrences of meter alarms are
collected for all connection points.
(b) Each Metering Data Provider must operate a process that:
(1) records and logs faults and problems associated with the
reading function of meters, and this process must record and
log, but is not limited to, any:
(i) access problems;
(ii) metering installation security problems;
(iii) metering installation faults;
(iv) read failures; and
(v) metering installation time synchronisation errors; and
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(2) supports the Metering Coordinator, the Metering Provider, or
both, in the rectification of any metering installation
malfunctions or problems associated with the reading function
of meters.
(c) On request by the financially responsible participant, a Metering
Data Provider must use reasonable endeavours to carry out a
special meter reading or final reading within 3 business days of the
receipt of the request unless an alternative timeframe has been
agreed.
S7A.8.9.5 Specific collection process requirements for remotely read
metering installations
(a) Each Metering Data Provider must be capable of initiating a remote
acquisition for metering data from type 1 to 3 metering installations
where relevant metering data is missing, erroneous or has failed
validation.
(b) Each Metering Data Provider must operate and maintain a process
that:
(1) initiates an alternative method to collect metering data where
remote acquisition becomes unavailable; and
(2) provides a log detailing successful reading events for each
metering installation, or alternatively an exception report of
failed meter readings.
S7A.8.9.6 Specific collection process requirements for manually read
metering installations
Each Metering Data Provider must:
(a) develop and maintain a meter reading schedule in accordance
with Schedule 7A.7 Part B;
(b) maintain reading routes with particular attention to any specific
access requirements and hazard information;
(c) use reasonable endeavours to ensure that metering data is
collected at least once every 3 months;
(d) ensure that scheduled reading date lists and programmed
reading equipment is provisioned, updated and maintained;
(e) use reasonable endeavours to ensure that metering data is
collected within 2 business days prior to or 2 business days
subsequent to a scheduled reading date; and
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(f) ensure that all metering data collected and any fault reason
codes associated with a reading failure are transferred to the
metering data services database within 1 business day of the
data being collected or attempted to be collected from the
metering installation.
S7A.8.9.7 Metering data processing requirements
General
(a) Each Metering Data Provider must have a process to:
(1) confirm and utilise the roles for connection points;
(2) assign and store the date/time stamp of when the metering
data was entered into the Metering Data Provider's metering
data services database;
(3) ensure that all metering data is stored in the metering data
services database with the correct:
(i) quality flag;
(ii) applicable substitution or estimation type code; and
(iii) applicable substitution or estimation reason code;
(4) check the metering data services database for missing
metering data and overlaps;
(5) aggregate interval metering data for a connection point into a
30-minute interval net metering data stream prior to delivery to
NTESMO or financially responsible participants in accordance
with the Rules;
(6) load metering data in an alternative format provided by a
Metering Provider where there is a communications error,
failed reading or metering installation malfunction that
prevents the normal collection of metering data from a
metering installation; and
(7) whenever any substitutions or estimations are carried out,
notify:
(i) NTESMO (in respect of a metering installation used for
the purposes of settlements);
(ii) Registered Participants for the connection point; and
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(iii) financially responsible participants (in respect of a
metering installation used for the purposes of billing
transactions).
Erroneous data
(b) Where the Metering Coordinator or Metering Provider informs a
Metering Data Provider of a situation that may cause metering data
to be erroneous, the Metering Data Provider must identify and
substitute any erroneous metering data.
(c) Where any Registered Participant for the connection point disputes
metering data, the Metering Data Provider must investigate, and, if
necessary correct the metering data in accordance with
Schedule 7A.7 Part C.
Meter alarms
(d) Where a meter alarm has occurred, the Metering Data Provider
must process the occurrence of the meter alarm along with the
metering data as part of the validation process in accordance with
Schedule 7A.7 Part C.
S7A.8.9.8 Specific metering data processing requirements for type 1, 2, 3
and 4 metering installations
Each Metering Data Provider must be able to undertake simple
cumulative or subtractive processes to manage complex metering
configurations. Typically, the system must support:
(a) an A+B+C or A-B-C aggregation configuration;
(b) validation capability for standard partial or check meter
connection points that incorporate a simple comparison of a
single metering data stream to a single check metering data
stream within an acceptable tolerance; and
(c) the calculation of the average of the 2 validated data sets for
metering installations where the check metering installation
duplicates the metering installation and accuracy level, and
the average of the 2 validated data sets must be delivered to:
(1) NTESMO (in respect of a metering installation used for
the purposes of settlements);
(2) Registered Participants; and
(3) financially responsible participants (in respect of a
metering installation used for the purposes of billing
transactions).
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S7A.8.9.9 Specific metering data processing requirements for type 7
metering installations
Inventory tables, load tables and on/off tables
(a) Each Metering Data Provider must store inventory tables, load
tables and on/off tables in the metering data services database
(b) Each Metering Data Provider must ensure:
(1) inventory tables are complete, correct and updated with any
changes provided by the Local Network Service Provider or
Metering Coordinator;
(2) on/off tables are complete and correct; and
(3) load tables are complete and correct.
(c) Each Metering Data Provider must ensure the inventory table, load
table and on/off table are versioned for metering data calculations.
Processing of calculated metering data
(d) Each Metering Data Provider must ensure that all calculated
metering data is validated and processed into recording intervals.
S7A.8.9.10 Specific metering data estimation requirements for
manually read and type 7 metering installations
(a) Each Metering Data Provider must have a process for the creation
of estimated metering data for type 4A, 5, 6 and 7 metering
installations.
(b) To meet metering data delivery requirements, this process must
either:
(1) create individual blocks of estimated metering data on a daily
basis; or
(2) create a single block of estimated metering data:
(i) from the date of the last meter reading to a period
beyond the next scheduled reading date for type 4A, 5
and 6 metering installations; or
(ii) from the date of the last calculation to a period beyond
the next scheduled calculation for type 7 metering
installations.
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S7A.8.9.11 Delivery performance requirements for metering data
Obligation to deliver information to NTESMO
(a) Where this clause S7A.8.9.11 imposes an obligation on a Metering
Data Provider to deliver metering data or other information to
NTESMO, that obligation only applies in respect of a metering
installation that is used for the purposes of settlements.
Obligation to deliver information to financially responsible
participants
(b) Where this clause S7A.8.9.11 (other than paragraph S7A.8.9.11(e))
imposes an obligation on a Metering Data Provider to deliver
metering data or other information to financially responsible
participants, that obligation only applies in respect of a metering
installation that is used for the purposes of billing transactions.
Validated metering data to be delivered
(c) Each Metering Data Provider must ensure only validated metering
data is delivered to NTESMO, Registered Participants and
financially responsible participants.
Delivery timing requirements
(d) Subject to any agreement to the contrary as contemplated by
clause S7A.8.13.1, each Metering Data Provider must:
(1) deliver to NTESMO, Registered Participants and financially
responsible participants all actual meter readings that passed
validation within 2 business days of the actual meter readings
being received into the metering data services database;
(2) substitute, validate and deliver to NTESMO, Registered
Participants and financially responsible participants the
substituted metering data within 2 business days of the actual
meter readings being received into the metering data services
database and failing validation;
(3) substitute, validate and deliver to NTESMO, Registered
Participants and financially responsible participants the
substituted metering data within 2 business days of the receipt
of any fault reason codes associated with a reading failure or
failed interrogation event, into the metering data services
database;
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(4) validate and deliver to NTESMO, Registered Participants and
financially responsible participants all substituted metering
data within 2 business days of the metering data being
substituted;
(5) ensure that all metering data is delivered to NTESMO,
Registered Participants and financially responsible
participants for the full period of any retrospectively created
metering data streams within 2 business days of that metering
data streams being created; and
(6) for type 4A, 5, 6 and 7 metering installations, validate and
deliver to NTESMO, Registered Participants and financially
responsible participants all estimated metering data within
2 business days of the metering data being estimated.
(e) Each Metering Data Provider must provide metering data to the
relevant financially responsible participants within 2 business days
of receiving a completed notification of a change of financially
responsible participants, including estimated metering data, for a
type 4A, 5, 6 or 7 metering installation.
Review of failed validations
(f) Each Metering Data Provider must ensure that all failed validations
are reviewed promptly so as to:
(1) where the initial review of the failed validation identifies that
the actual meter readings are valid, deliver the actual meter
readings to NTESMO, Registered Participants and financially
responsible participants within 2 business days of the
metering data being received into the metering data services
database; and
(2) where further information is required to validate the actual
meter readings, and the receipt of such information identifies
that the actual meter readings are valid, deliver the actual
meter readings to NTESMO, Registered Participants and
financially responsible participants within 2 business days of
the metering data passing validation.
Operational delays
(g) The Metering Data Provider must notify NTESMO and affected
Registered Participants immediately upon the identification of any
operational delays impacting on normal metering data delivery.
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S7A.8.10 Data management following the alteration of type
of metering installation at a connection point
S7A.8.10.1 Meter churn scenarios
(a) Meter churn can result in a change to the configuration of metering
data recorded by a metering installation. This change in metering
data may result in an alteration to the Metering Data File Format
file.
(b) Where a meter churn takes place, each Metering Data Provider
must:
(1) comply with the Metering Data File Format requirements when
constructing the Metering Data File Format file associated with
the change in type of metering installation; and
(2) for a meter churn scenario described in an item of column 1 of
the following table, comply with the requirements for the
management of metering data described in the provision listed
in column 2 of that item of the following table:
Column 1
Meter churn scenario
Column 2
Provision
A metering installation is changed from a
type 6 metering installation to a new type
6 metering installation (Scenario 1)
Clause S7A.8.10.2
A metering installation is changed from a
type 6 metering installation to a type 1,
2, 3, 4, 4A, or 5 metering installation
(Scenario 2)
Clause S7A.8.10.3
A metering installation is changed from a
type 1, 2, 3, 4, 4A, or 5 metering
installation to a type 6 metering
installation (Scenario 3)
Clause S7A.8.10.4
A metering installation is changed from a
type 1, 2, 3, 4, 4A, or 5 metering
installation to a new type 1, 2, 3, 4, 4A,
or 5 metering installation (Scenario 4)
Clause S7A.8.10.5
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S7A.8.10.2 Scenario 1
The Metering Data Provider must have a process to ensure that:
(a) the final accumulation meter reading(s) from the removed
type 6 metering installation are applied at the end of the day
prior to the meter churn;
(b) the start reading(s) for a new type 6 metering installation are
applied at the start of the day of the meter churn; and
(c) estimated metering data is provided for any metering data
streams made active as a result of the meter churn.
S7A.8.10.3 Scenario 2
(a) The Metering Data Provider must have a process to ensure that:
(1) the final accumulation meter reading(s) from the removed
type 6 metering installation are applied at the end of the day
prior to the meter churn;
(2) the metering data for the new type 1, 2, 3, 4, 4A, or 5 metering
installation commences at the start of the day of the meter
churn; and
(3) estimated metering data is provided for any metering data
streams made active as a result of the meter churn for a new
type 4A or type 5 metering installation.
(b) The Metering Data Provider must have a process to ensure that the
metering data for the period of the meter churn day between the
start of the day and the commissioning of the new metering
installation is provided as zeroes with a quality flag of F.
S7A.8.10.4 Scenario 3
Where reversion from a type 1, 2, 3, 4, 4A, or 5 metering installation
to a type 6 metering installation is permitted, the Metering Data
Provider must have a process to ensure that:
(a) the final reading(s) from the removed type 1, 2, 3, 4, 4A, or
5 metering installation cease at the end of the day of the meter
churn;
(b) the metering data for the period of the meter churn day
between commissioning of the new metering installation and
the end of the day of the meter churn is provided as zeroes
with a quality flag of F; and
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(c) the start reading(s) for the new type 6 metering installation are
applied at the start of the day following the day of the meter
churn.
S7A.8.10.5 Scenario 4
Each Metering Data Provider must have a process to ensure
compliance with the following requirements:
(a) the final reading(s) from the removed type 1, 2, 3, 4, 4A, or
5 metering installation is collected up to the removal of the old
metering installation on the day of the meter churn;
(b) the metering data for the new type 1, 2, 3, 4, 4A, or 5 metering
installation commences at the start of the day of the meter
churn;
(c) the Metering Data Provider related to the new metering
installation must obtain metering data for the period of the
meter churn day between the start of the meter churn day and
the removal of the old metering installation from the Metering
Data Provider related to the old metering installation;
(d) the Metering Data Provider related to the new metering
installation must combine the metering data from the old
metering installation and the new metering installation for the
day of meter churn and deliver metering data for the whole
day of meter churn;
(e) where meter churn results in a change to the recording of
metering data from 15-minute to 30-minute intervals, the 15-
minute intervals of metering data from the start of the meter
churn day until the commissioning of the new metering
installation are to be aggregated to form interval metering
data;
(f) where meter churn results in a change to the recording of
metering data from 30-minute to 15-minute intervals:
(1) the 15-minute intervals of metering data from the
commissioning of the new metering installation to the
end of the meter churn day are to be aggregated to form
30-minute interval metering data; or
(2) the 30-minute intervals of metering data for the start of
the meter churn day may be disaggregated to form
15-minute interval metering data, where agreed with the
Metering Coordinator;
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(g) estimated metering data is provided for any metering data
streams made active as a result of the meter churn for a new
type 4A or type 5 metering installation;
(h) where meter churn results in a metering data stream being
made active, the Metering Data Provider related to the new
metering installation must provide metering data from the start
of the day to the commissioning of the new metering
installation by providing zeroes with a quality flag of F;
(i) where meter churn results in a metering data stream being
made inactive, the Metering Data Provider must provide
metering data from the commissioning of the new metering
installation to the end of the day by providing zeroes with a
quality flag of F; and
(j) the Metering Data Provider must create final substituted
metering data for the period between the existing metering
installation being removed and the commissioning of the new
metering installation.
S7A.8.11 System architecture and administration
S7A.8.11.1 Metering data archival and recovery
Each Metering Data Provider must have retrieval mechanisms (both
electronic and archived) that allow the metering data retained in its
metering data services database under clause 7A.8.3 to be
accessed, recovered, re-evaluated and delivered in agreed
timeframes to NTESMO, Registered Participants or financially
responsible participants.
S7A.8.11.2 Data backup
All metering data and metering register information must be
backed-up, at a minimum, on a daily basis and held in a secure
environment.
S7A.8.11.3 Disaster recovery
Requirement for disaster recovery plan
(a) Each Metering Data Provider must ensure that a disaster recovery
plan is established and in place to ensure that in the event of a
system failure, its IT systems can be returned to normal operational
service within 2 business days.
-- 251 of 290 --
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(b) The Metering Data Provider must ensure that the disaster recovery
plan is:
(1) up to date with all documentation showing revisions; and
(2) witnessed and dated at least annually by the Metering Data
Provider as being current for the systems and processes in
place.
Fall-over system approach
(c) Where a Metering Data Provider adopts a disaster recovery plan
that has a complete ‘fail-over' system approach, the disaster
recovery plan must be subjected to a test annually that facilitates a
full ‘fail-over' to the recovery system.
Segmented system approach
(d) Where the Metering Data Provider adopts a disaster recovery plan
that has a segmented system approach, the disaster recovery plan
must:
(1) detail the interfaces and relationships between system
segments;
(2) be established for each individual system segment;
(3) be tested annually with evidence retained to show disaster
recovery for each individual system segment; and
(4) have, for each individual system segment, a procedure that
clearly details the process to establish a return to full
operation.
Testing
(e) Expected evidence to support disaster recovery plan testing should
include, but not be limited to:
(1) a test plan of the fail-over;
(2) results of the fail-over including timing;
(3) system logs indicating fail-over and recovery; and
(4) logs or notations evidencing resumption of Metering Data
Provider operations.
-- 252 of 290 --
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Actions following system failure
(f) If a system failure occurs, the Metering Data Provider must ensure
that within 2 business days:
(1) its metering data services database is restored to operational
service; and
(2) all processing and delivery backlogs of metering data to
NTESMO and Registered Participants is completed.
Notice to NTESMO of activation of disaster recovery plan
(g) The Metering Data Provider must, at its earliest opportunity, notify
NTESMO of any failure where the Metering Data Provider has a
requirement to activate its disaster recovery plan.
S7A.8.11.4 System administration and data management
Metering data services database
(a) The metering data services database must be operated and
administered by a Metering Data Provider to facilitate:
(1) controlled access to systems and data using unique
identification and passwords for each user;
(2) the restriction of access to the underlying database tables to
nominated system administrators;
(3) the restriction of Registered Participant access to metering
data and NT NMI data in accordance with
paragraph 7A.13.5(c);
(4) a minimum of 95% system availability (that is, hardware and
systems downtime do not exceed a maximum of 438 hours
per annum).
Metering register
(b) Each Metering Data Provider must maintain full audit trails and
version control of metering register information, metering data for at
least 7 years so that any data output produced by the system can
be re-produced from source data.
-- 253 of 290 --
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S7A.8.12 Quality control
S7A.8.12.1 Audits
(a) Audits may be undertaken at any time by the Utilities Commission
in accordance with the Rules and may be carried out following a
request from a Registered Participant.
(b) Where an audit of a metering installation is conducted by the
Utilities Commission under clause 7A.7.4, and metering data must
be obtained from the Metering Data Provider in support of this
audit, the Metering Data Provider must provide the metering data
within 2 business days of the Utilities Commission's request.
(c) Each Metering Data Provider must assist the Utilities Commission
with reasonable requests for the provisioning of metering data and
relevant information relating to connection points that are part of the
audit process of Metering Coordinators, Metering Providers and
Metering Data Providers.
S7A.8.12.2 Corrective action
(a) Each Metering Data Provider must take corrective action on any
reported instances of non-compliance identified by NTESMO or
through a Metering Data Provider audit process.
(b) Where a Metering Data Provider becomes aware that incorrect
metering data has been delivered to NTESMO and Registered
Participants, the Metering Data Provider must provide corrected
metering data to all affected parties within 1 business day as
required by paragraph 7A.8.3(d).
(c) NTESMO may request corrective action where errors or omissions
are found within the settlements process and such requests are to
be actioned as a priority by the Metering Data Provider.
(d) Where the Metering Data Provider cannot deliver the corrected
metering data in the timeframe specified above, the Metering Data
Provider must advise NTESMO and agree on an alternative
delivery time.
S7A.8.13.1 Administration
Provision of data
(a) A Registered Participant may request a Metering Data Provider to:
(1) provide metering data in an alternative format, method or
timeframe;
-- 254 of 290 --
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(2) provide any other metering data services; or
(3) any combination of the above.
No data to be provided
(b) A Registered Participant may request a Metering Data Provider to
not provide or deliver any metering data to the Registered
Participant as required under this Part.
System changes not required
(c) There is no requirement for a Metering Data Provider to implement
system changes and processes to facilitate bilateral agreements.
Bilateral agreement not to impact metering data delivery to
NTESMO
(d) Any acceptance by a Metering Data Provider to deliver metering
data to a Registered Participant in accordance with any agreement
contemplated by this clause S7A.8.13.1 or acceptance to not
provide any metering data in accordance with such an agreement
must not impact on metering data delivery to NTESMO or any other
Registered Participant for the connection point(s) concerned.
Bilateral agreement to be auditable
(e) Any bilateral agreement established between a Registered
Participant and a Metering Data Provider must be in writing and
made available to the Utilities Commission on request for audit
purposes.
S7A.8.13.2 Quality systems
Each Metering Data Provider must operate and retain a quality
system that is at least equal to a quality accreditation to the
ISO9001 or ISO9002 standards.
88 Clause 8.1.3 modified
After clause 8.1.3, heading
insert
Note
Clause 8.1.3(b)(5) and (7) has no effect in this jurisdiction (see regulation 5A of
the National Electricity (Northern Territory) (National Uniform Legislation)
(Modification) Regulations).
-- 255 of 290 --
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89 Chapter 8, Part B modified
After Chapter 8, Part B, heading
insert
Note:
This Part has no effect in this jurisdiction (see regulation 5A of the National
Electricity (Northern Territory) (National Uniform Legislation) (Modification)
Regulations 2016).
90 Clause 8.6.1 modified
After clause 8.6.1, heading
insert
Note
Clause 8.6.1(d) and (e) has no effect in this jurisdiction (see regulation 5A of the
National Electricity (Northern Territory) (National Uniform Legislation)
(Modification) Regulations).
91 Clause 8.6.2 modified
After clause 8.6.2, heading
insert
Note
Clause 8.6.2(l) has no effect in this jurisdiction (see regulation 5A of the National
Electricity (Northern Territory) (National Uniform Legislation) (Modification)
Regulations).
92 Clause 8.6.5 replaced
Clause 8.6.5
repeal, insert
8.6.5 Indemnity to AER and AEMC
Each Registered Participant must indemnify the AER and the
AEMC against any claim, action, damage, loss, liability, expense or
outgoing which the AER or the AEMC pays, suffers, incurs or is
liable for in respect of any breach by that Registered Participant or
any officer, agent or employee of that Registered Participant of this
rule 8.6.
-- 256 of 290 --
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93 Clauses 8.6.6 and 8.6.7 modified
After clauses 8.6.6 and 8.6.7, headings
insert
Note
This clause has no effect in this jurisdiction (see regulation 5A of the National
Electricity (Northern Territory) (National Uniform Legislation) (Modification)
Regulations).
94 Clause 8.7.1 modified
(1) Clause 8.7.1(b)(1)
omit
and AEMO
(2) Clause 8.7.1(c)(3)
omit
, all Registered Participants and AEMO
insert
and all Registered Participants
95 Clause 8.7.2 modified
(1) Clause 8.7.2, heading
omit, insert
8.7.2 Reporting requirements and monitoring standards for
Registered Participants
Note
Clause 8.7.2(a)(2) and (4) and (b)(2) has no effect in this jurisdiction (see
regulation 5A of the National Electricity (Northern Territory) (National Uniform
Legislation) (Modification) Regulations).
(2) Clause 8.7.2(a)(5)
omit
or AEMO
-- 257 of 290 --
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(3) Clause 8.7.2(b)(1)
omit
, AEMO
(4) Clause 8.7.2(b)(1)
omit
, (4)
(5) Clause 8.7.2(c)
omit
AEMO and
(6) Clause 8.7.2(e)
omit (all references)
and AEMO
(7) Clause 8.7.2(f)
omit
all words from "neither" to "be)"
insert
a Registered Participant must not recklessly or knowingly provide,
or permit any other person to provide on behalf of that Registered
Participant
(8) Clause 8.7.2(g)
omit
or AEMO
(9) Clause 8.7.2(g) and (h)
omit
and/or AEMO (as the case may be)
-- 258 of 290 --
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(10) Clause 8.7.2(g)
omit
and (to the extent relevant) AEMO
96 Clause 8.7.6 modified
After clause 8.7.6, heading
insert
Note
Clause 8.7.6 has no effect in this jurisdiction (see regulation 5A of the National
Electricity (Northern Territory) (National Uniform Legislation) (Modification)
Regulations).
97 Chapter 8, Parts E and G modified
After Chapter 8, Parts E and G, headings
insert
Note
This Part has no effect in this jurisdiction (see regulation 5A of the National
Electricity (Northern Territory) (National Uniform Legislation) (Modification)
Regulations).
98 Chapter 8, Parts H modified
After Chapter 8, Part H, heading
insert
Note:
This Part has no effect in this jurisdiction (see regulation 5A of the National
Electricity (Northern Territory) (National Uniform Legislation) (Modification)
Regulations 2016).
99 Chapter 10 modified
(1) Chapter 10, definitions accumulated energy data, accumulated
metering data, application to connect, business day,
calculated metering data, check meter, check metering data,
check metering installation, connection point, control centre,
Customer, customer authorised representative, day,
Distribution Network Service Provider, distribution system,
estimated metering data, facilities, financially responsible,
Generator, interval energy data, interval metering data,
Metering Coordinator, Metering Data Provider, metering data
services, metering data services database, metering
-- 259 of 290 --
Schedule 2 Further modifications to operation of National Electricity Rules
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Regulations 2016 254
installation malfunction, Metering Provider, National Electricity
Law, national grid, Network Service Provider, NMI, nominal
voltage, nominated pass through event considerations,
positive change event, power system, regulatory control
period, remote acquisition, Rules, substituted metering data,
telecommunications network, time, transmission network,
Transmission Network Service Provider, transmission or
distribution system and unmetered connection point
omit
(2) Chapter 10
insert (in alphabetical order)
1st regulatory control period
In relation to a Network Service Provider in this jurisdiction, means
the first period during which the provider will be or is subject to a
control mechanism imposed by a distribution determination, being
the period from 1 July 2019 to 30 June 2024.
2009-14 NT regulatory control period
The regulatory control period that commenced on 1 July 2009
under the NT Network Access Code.
2014-19 NT regulatory control period
The regulatory control period that commenced on 1 July 2014
under the NT Network Access Code.
2014 NT Ministerial Direction
The direction issued by the shareholding Minister of Power and
Water Corporation ABN 15 947 352 360 to the board of the
Corporation under section 8(4)(a) of the Government Owned
Corporations Act (NT), dated 19 June 2014.
2014 NT Network Price Determination
The "2014 Network Price Determination" made by the Utilities
Commission under the Utilities Commission Act (NT), Electricity
Reform Act (NT) and Chapter 6 of the NT Network Access Code
that:
(a) applies, or applied, from 1 July 2014 to 30 June 2019; and
-- 260 of 290 --
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(b) because of section 57 of the Electricity Networks (Third Party
Access) Act (NT), is, or was, a network pricing determination
made under section 6A(1) of that Act,
as amended, varied or substituted from time to time.
accumulated energy data
The data that results from the measurement of the flow of electricity
in a power conductor where the data represents a period in excess
of a recording interval. Accumulated energy data is held in the
metering installation. The measurement is carried out at a metering
point.
accumulated metering data
The accumulated energy data, once collected from a metering
installation, is accumulated metering data. Accumulated metering
data is held in a metering data services database.
application to connect
An application made by a Connection Applicant in accordance with
Chapter 5, Part A for connection to a network and/or the provision
of network services or modification of a connection to a network
and/or the provision of network services.
Australian Central Standard Time (ACST)
The time that is set at 9 hours and 30 minutes in advance of
Co-ordinated Universal Time.
business day
A day that is not:
(a) a Saturday or Sunday; or
(b) a public holiday as defined in section 17 of the Interpretation
Act (NT) (other than a public holiday that is part of a day) in
the City of Darwin.
calculated metering data
The recording interval data corresponding to the calculation of
consumed energy for a type 7 metering installation in accordance
with schedule 7A.7. Calculated metering data is held in the
metering data services database.
-- 261 of 290 --
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check meter
An additional meter used as a source of check metering data for
type 1 and type 2 metering installations as specified in
schedule 7A.4.
check metering data
The energy data, once collected from a check metering installation,
is check metering data. Check metering data is held in a metering
data services database.
check metering installation
A metering installation that includes a check meter which is used as
the source of check metering data for data validation.
connection point
The agreed point of supply established between Network Service
Provider(s) and another Registered Participant, Non-Registered
Customer or franchise customer.
control centre
The facilities used by NTESMO for managing power system
security and administering a market.
Customer
A person who:
(a) under Part 3 of the Electricity Reform Act (NT), holds a licence
authorising the selling of electricity; but
(b) does not hold a licence authorising the ownership or operation
of an electricity network under that Part.
customer authorised representative
A person authorised by a retail customer to request and receive
information under Chapter 7A on the retail customer's behalf.
day
Unless otherwise specified, the 24 hour period beginning and
ending at midnight Australian Central Standard Time.
-- 262 of 290 --
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Distribution Network Service Provider
A person who:
(a) engages in the activity of owning, controlling, or operating a
distribution system; and
(b) under Part 3 of the Electricity Reform Act (NT), holds a licence
authorising the ownership or operation of an electricity
network.
distribution system
Means:
(a) a distribution network, together with the connection assets
associated with the distribution network, which is connected to
another transmission or distribution system within the other
participating jurisdictions; or
(b) a distribution network that forms part or all of a local electricity
system, together with the connection assets associated with
the distribution network.
Connection assets on their own do not constitute a distribution
system.
estimated metering data
The estimated values of accumulated metering data, interval
metering data or calculated metering data that have been prepared
in accordance with schedule 7A.7. Estimated metering data is held
in a metering data services database.
facilities
A generic term associated with the apparatus, equipment, buildings
and necessary associated supporting resources provided at,
typically:
(a) a power station or generating unit;
(b) a substation or power station switchyard;
(c) a control centre (being an NTESMO control centre, or a
distribution or transmission network control centre);
(d) facilities providing an exit service.
-- 263 of 290 --
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Regulations 2016 258
financially responsible
In relation to a connection point, a term which is used to describe
the person authorised to have either:
1. the load connected at that connection point; or
2. the generating unit connected at that connection point.
Note:
The obligations on Customers (including retailers) and Generators in relation to
the authorisation of, respectively, load or generating units connected at a
connection point will be considered as part of the phased implementation of the
Rules in this jurisdiction.
Generator
A person who:
(a) engages in the activity of owning, controlling or operating a
generating system that is connected to, or who otherwise
supplies electricity to, a transmission or distribution system;
and
(b) is a Registered Participant who, under Part 3 of the Electricity
Reform Act 2000 (NT), holds a licence authorising the
generation of electricity.
For the purposes of Chapter 5, the term includes a person who:
(a) is required or intends to hold a licence authorising the
generation of electricity;
(b) is covered by an exemption from the requirement to hold a
licence for the generation of electricity;
(c) is a non-registered embedded generator (as defined in
clause 5A.A.1) who has made an election under
clause 5A.A.2(c); or
(d) is a non-registered embedded generator (as defined in
clause 5A.A.1) above the relevant materiality threshold (as
defined in Chapter 5).
interval energy data
The data that results from the measurement of the flow of electricity
in a power conductor where the data is prepared and recorded by
the metering installation in intervals which correspond to a
recording interval or are submultiples of a recording interval.
Interval energy data is held in the metering installation.
-- 264 of 290 --
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interval meter
A meter that records interval energy data.
interval metering data
The interval energy data, once collected from a metering
installation, is interval metering data. Interval metering data is held
in a metering data services database.
Metering Coordinator
A person appointed to the role of Metering Coordinator in this
jurisdiction.
Metering Data Provider
A person appointed to be a Metering Data Provider for a connection
point.
metering data services
The services that involve the collection, processing, storage and
delivery of metering data and the management of relevant NT NMI
data in accordance with the Rules.
metering data services database
The database established and maintained by the Metering Data
Provider that holds metering data and NT NMI data relating to each
metering installation for which the Metering Coordinator has
appointed the Metering Data Provider to provide metering data
services.
metering installation malfunction
The full or partial failure of the metering installation in which the
metering installation:
(a) does not meet the requirements of schedule 7A.4;
(b) does not record, or incorrectly records, energy data; or
(c) does not allow, or provide for, collection of energy data.
Metering Provider
A person appointed to be a Metering Provider for a connection
point.
-- 265 of 290 --
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Regulations 2016 260
National Electricity Law
The National Electricity (NT) Law.
national grid
The sum of:
(a) all connected transmission systems and distribution systems
within the other participating jurisdictions; and
(b) the transmission systems and distribution systems in this
jurisdiction.
Network Service Provider
A Distribution Network Service Provider or Transmission Network
Service Provider.
NMI
A National Metering Identifier issued by the relevant Network
Service Provider.
nominal voltage
The design voltage level, nominated for a particular location on the
power system, such that power lines and circuits that are
electrically connected other than through transformers have the
same nominal voltage regardless of operating voltage.
nominated pass through event considerations
The nominated pass through event considerations are:
(a) whether the event proposed is an event covered by a category
of pass through event specified in clause 6.6.1(a1)(1AA) to (4)
(in the case of a distribution determination) or
clause 6A.7.3(a1)(1) to (4) (in the case of a transmission
determination);
(b) whether the nature or type of event can be clearly identified at
the time the determination is made for the service provider;
(c) whether a prudent service provider could reasonably prevent
an event of that nature or type from occurring or substantially
mitigate the cost impact of such an event;
-- 266 of 290 --
Schedule 2 Further modifications to operation of National Electricity Rules
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(d) whether the relevant service provider could insure against the
event, having regard to:
(1) the availability (including the extent of availability in
terms of liability limits) of insurance against the event on
reasonable commercial terms; or
(2) whether the event can be self-insured on the basis that:
(i) it is possible to calculate the self-insurance
premium; and
(ii) the potential cost to the relevant service provider
would not have a significant impact on the service
provider's ability to provide network services; and
(e) any other matter the AER considers relevant and which the
AER has notified Network Service Providers is a nominated
pass through event consideration.
NT equivalent services
Regulated network access services (as defined in clause 3 of the
NT Network Access Code) that are designated as direct control
services in Table 3.1 of Part A of the 2014 NT Network Price
Determination.
NT Network Access Code
The Network Access Code as defined in section 2A(1) of the
Electricity Networks (Third Party Access) Act (NT).
NT NMI data
The following data in respect of a connection point:
(a) the NMI of the connection point and the street address of the
relevant connection point to which that NMI is referable;
(b) the NMI checksum for the connection point;
(c) the identity of the relevant Network Service Provider;
(d) the relevant distribution loss factor applicable to the
connection point;
(e) the Network Tariff (identified by a code) applicable in respect
of the connection point;
-- 267 of 290 --
Schedule 2 Further modifications to operation of National Electricity Rules
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(f) the read cycle date, or date of next scheduled read or date in
a relevant code representing the read cycle date or date of
next scheduled read, for that connection point,
and, to avoid doubt, does not include any metering data or other
details of an end-user's consumption at that connection point.
positive change event
For a Distribution Network Service Provider, a pass through event
which entails the Distribution Network Service Provider incurring
materially higher costs in providing direct control services than it
would have incurred but for that event, but does not include a
contingent project or an associated trigger event.
For a Transmission Network Service Provider, a pass through event
which entails the Transmission Network Service Provider incurring
materially higher costs in providing prescribed transmission
services than it would have incurred but for that event, but does not
include a contingent project or an associated trigger event.
power system
The electricity power system of the national grid including
associated generation and transmission and distribution networks
for the supply of electricity, operated as an integrated arrangement
or arrangements.
recording interval
A 30 minute period ending on the hour (Australian Central Standard
Time) or on the half-hour and, if identified by a time, means the 30
minute period ending at that time.
regulatory control period
In respect of a Network Service Provider, a period of not less than
5 regulatory years for which the provider is subject to a control
mechanism imposed by a distribution determination.
remote acquisition
The acquisition of interval metering data from a telecommunications
network connected to a metering installation that:
(a) does not, at any time, require the presence of a person at, or
near, the interval metering installation for the purposes of data
collection or data verification (whether this occurs manually as
a walk-by reading or through the use of a vehicle as a close
proximity drive-by reading); and
-- 268 of 290 --
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(b) includes but is not limited to methods that transmit data via:
(1) fixed-line telephone (‘direct dial-up');
(2) satellite;
(3) the internet;
(4) wireless or radio, including mobile telephone networks;
(5) power line carrier; or
(6) any other equivalent technology.
Rules
The National Electricity Rules as defined in section 2(1) of the
National Electricity Law.
substituted metering data
The substituted values of accumulated metering data, interval
metering data or calculated metering data prepared in accordance
with schedule 7A.7. Substituted metering data is held in a metering
data services database.
telecommunications network
A telecommunications network that provides access for public use.
time
Australian Central Standard Time.
transmission network
Any of the following:
(a) a network in this jurisdiction operating at nominal voltages of
66kV and above;
(b) a network or part of a network prescribed by local instrument
to be a transmission network or part of a transmission
network,
but does not include a network or part of a network prescribed by
local instrument not to be a transmission network or part of a
transmission network.
-- 269 of 290 --
Schedule 2 Further modifications to operation of National Electricity Rules
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Regulations 2016 264
For a participating jurisdiction other than the State of Victoria, an
identified shared user asset owned, controlled or operated by a
Primary Transmission Network Service Provider (including a third
party IUSA that is the subject of a network operating agreement)
forms part of that Primary Transmission Network Service Provider's
transmission network.
Note:
The National Electricity (Northern Territory) (National Uniform Legislation)
(Modification) Regulations 2016 are a local instrument.
Transmission Network Service Provider
A person who:
(a) engages in the activity of owning, controlling or operating a
transmission system; and
(b) under Part 3 of the Electricity Reform Act (NT), holds a licence
authorising the ownership or operation of an electricity
network.
transmission or distribution system
A transmission system or a distribution system.
unmetered connection point
A connection point at which a meter is not necessary under
schedule 7A.1.
Utilities Commission
The Utilities Commission of the Northern Territory established by
section 5 of the Utilities Commission Act (NT).
(3) Chapter 10, definition applicable regulatory instruments, at the
end
insert
(6A) Northern Territory:
(a) the Electricity Reform Act (NT);
(b) all instruments made and licences granted under the
Electricity Reform Act (NT);
(c) the Utilities Commission Act (NT); and
(d) all instruments made under the Utilities Commission Act (NT).
-- 270 of 290 --
Schedule 2 Further modifications to operation of National Electricity Rules
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Regulations 2016 265
(4) Chapter 10, definition franchise customer, at the end
insert
Note:
There are no franchise customers in this jurisdiction.
99A Chapter 10 modified (further definitions substituted and
inserted)
(1) Chapter 10, definitions access standard, connection alteration,
connection contract, Dedicated Connection Asset Service
Provider, dispatch, distribution network user access,
embedded network, funded augmentation, generating system,
Incoming Retailer, Local Network Service Provider, market,
market load, metering register, normal voltage, performance
standard, plant, power system security, profile, retail
customer, satisfactory operating state, secure operating state,
settlements, settlements ready data, system standard and
transmission consultation procedures
omit
(2) Chapter 10
insert
access standard
A particular technical requirement as recorded in a connection
agreement.
billing transaction
The activity of producing bills and credit notes in markets that are
not operated or administered by NTESMO.
connection alteration
Has (in the context of Chapters 5A and 7A) the meaning given in
clause 5A.A.1.
connection contract
Has (in the context of Chapters 5A and 7A) the meaning given in
clause 5A.A.1.
-- 271 of 290 --
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Dedicated Connection Asset Service Provider
A Transmission Network Service Provider to the extent that it owns
or operates a dedicated connection asset in accordance with a
licence under the Electricity Reform Act 2000 (NT).
dispatch
The act of initiating or enabling all or part of the response to an
instruction issued to a Generator to synchronise, supply ancillary
services, or supply energy.
distribution network user access
The power transfer capability of the distribution network in respect
of:
(a) generating units or a group of generating units; and
(b) network elements,
at a connection point which has been negotiated in accordance with
rules 5.3, 5.3A and 5.3AA.
Note:
For the avoidance of doubt, distribution network user access extends to the
transmission network for the purposes of Chapter 6.
electricity retail supply code
The Electricity Retail Supply Code made by the Utilities
Commission under section 24 of the Utilities Commission Act 2000
(NT) (as published by the Utilities Commission from time to time).
embedded network
A distribution system that is connected to a distribution system
controlled or operated by the Local Network Service Provider (other
than a distribution system that is owned, controlled or operated by
the Local Network Service Provider).
energy ombudsman
The person holder or occupying the office of Ombudsman for the
Northern Territory established by section 9 of the Ombudsman
Act 2009 (NT).
-- 272 of 290 --
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funded augmentation
A transmission network augmentation for which the Transmission
Network Service Provider is not entitled to receive a charge
pursuant to Chapter 6.
generating system
(a) Subject to paragraph (b), for the purposes of the Rules, a
system comprising one or more generating units.
(b) For the purposes of Chapter 5, a system comprising one or
more generating units and includes auxiliary or reactive plant
that is located on the Generator's side of the connection point
and is necessary for the generating system to meet its
performance obligations.
Incoming Retailer
A retailer that:
(a) that has a contract with a customer at a connection point; and
(b) has initiated the customer transfer process in accordance with
the electricity retail supply code,
but which is not yet designated the financially responsible
participant for that connection point.
Local Network Service Provider
Power and Water Corporation ABN 15 947 352 360.
market
Means:
(a) except for the purposes of Chapter 7A:
(i) a market or exchange operated or administered by
NTESMO, whether being a market for energy or any
other market or exchange; or
(ii) a market or exchange for energy that is not operated or
administered by NTESMO; and
(b) for the purposes of Chapter 7A, a market or exchange for
energy.
-- 273 of 290 --
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market load
A load for an NMI classified by the relevant retailer or, with the
consent of the financially responsible person for that load, by some
other person, as a market load. There can be more than one
market load at any one connection point.
metering register
A register of information associated with a metering installation as
required by schedule 7A.1.
new meter deployment
The replacement of an existing electricity meter of one or more
small customers which is arranged by a retailer, other than where
the replacement is:
(a) at the request of the relevant small customer or to enable the
provision of a product or service the customer has agreed to
acquire from the retailer or any other person;
(b) a maintenance replacement; or
(c) required as a result of a metering installation malfunction.
normal voltage
In respect of a connection point, its nominal voltage or such other
voltage up to 10% higher or lower than normal voltage, as approved
by NTESMO, for that connection point, at the request of the
Network Service Provider who provides connection to the power
system.
NTESMO (being the Northern Territory Electricity System and
Market Operator)
As the case requires:
(a) the entity that undertakes the performance of the functions set
out in the Rules that relate to monitoring or controlling the
operation of the power system in respect of one or more of the
local electricity systems; or
(b) the entity that undertakes the performance of the functions set
out in the Rules that relate to operating or administering a
market in respect of one or more of the local electricity
systems.
-- 274 of 290 --
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performance standard
A standard of performance that:
(a) is established as a result of it being taken to be an applicable
performance standard in accordance with jurisdictional
electricity legislation; and
(b) forms part of the terms and conditions of a connection
agreement.
plant
In relation to a connection point, includes all equipment involved in
generating, utilising or transmitting electrical energy.
power system security
The safe scheduling, operation and control of the power system on
a continuous basis in accordance with the principles set out in
jurisdictional electricity legislation.
Note:
The principles that will be set out in jurisdictional electricity legislation in the
above definition will correspond to principles set out in clause 4.2.6 in the Rules
applying in other participating jurisdictions.
profile
Metering data or costs for a longer period than a recording interval
allocated into recording intervals.
retail customer
Has the same meaning as in the National Electricity Law.
Note:
In the context of Chapter 5A, the above definition has been supplemented by a
definition specifically applicable to that Chapter. See clause 5A.A.1.
satisfactory operating state
In relation to the power system, has the meaning given in
jurisdictional electricity legislation.
Note:
The meaning given in jurisdictional electricity legislation in the above definition
will correspond to the meaning given in clause 4.2.2 in the Rules applying in
other participating jurisdictions.
-- 275 of 290 --
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secure operating state
In relation to the power system, has the meaning given in
jurisdictional electricity legislation.
Note:
The meaning given in jurisdictional electricity legislation in the above definition
will correspond to the meaning given in clause 4.2.4 in the Rules applying in
other participating jurisdictions.
settlements
The activity of producing bills and credit notes in markets operated
or administered by NTESMO.
settlement ready data
The metering data that has undergone a validation and substitution
process by NTESMO for the purposes of settlements and is held in
the metering database.
system standard
A standard for the performance of the power system as set out in
jurisdictional electricity legislation that:
(a) is necessary for the safe and reliable operation of the power
system;
(b) is necessary for the safe and reliable operation of the facilities
of Registered Participants; and
(c) is consistent with good electricity industry practice.
transmission consultation procedures
The procedures set out in Part H of Chapter 6A (as applying in the
other participating jurisdictions) that must be followed by:
(a) the AER in making, developing or amending guidelines,
models or schemes or in reviewing methodologies; or
(b) the AEMC in developing or amending guidelines.
-- 276 of 290 --
Schedule 2 Further modifications to operation of National Electricity Rules
National Electricity (Northern Territory) (National Uniform Legislation) (Modification)
Regulations 2016 271
102 Chapter 10 modified (expires on 1 July 2029)
Chapter 10
insert (in alphabetical order)
2nd regulatory control period
In relation to a Network Service Provider in this jurisdiction, means
the second period during which the provider will be or is subject to a
control mechanism imposed by a distribution determination, being
the period from 1 July 2024 to 30 June 2029.
Note:
This definition expires on 1 July 2029.
103 Chapter 10 modified (expires when NERL is applied)
Chapter 10, definition energy laws
omit, insert
energy laws
Means:
(a) the national electricity legislation as defined in the National
Electricity Law;
(b) these Rules and instruments made under these Rules;
(c) the national gas legislation as defined in the National Gas
(NT) Law;
(d) the National Gas Rules as defined in the National Gas (NT)
Law and instruments made under those Rules; and
(e) any other Northern Territory legislation that regulates energy.
Note:
The modifications to this definition expire when the National Energy Retail Law is
applied as a law of this jurisdiction.
-- 277 of 290 --
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Regulations 2016 272
104 Chapter 11 modified
After Chapter 11, heading
insert
Note:
Parts A to ZZI, ZZK, ZZL, ZZN (except for clause 11.86.8), ZZO to ZZT, ZZV and
ZZX have no effect in this jurisdiction (see regulation 5A of the National Electricity
(Northern Territory) (National Uniform Legislation) (Modification) Regulations).
The application of those Parts may be revisited as part of the phased
implementation of the Rules in this jurisdiction.
105 Clause 11.93.1 modified
Clause 11.93.1, definition subsequent regulatory control period
omit, insert
subsequent regulatory control period of:
(a) Power and Water Corporation – means the 1st regulatory
control period; or
(b) another affected DNSP or affected TNSP – means the
regulatory control period for that affected DNSP or affected
TNSP that immediately follows the current regulatory control
period.
106 Chapter 11A inserted
After Chapter 11
insert
11A. NT Savings and Transitional Rules
Part A Savings and transitional rules for Chapter 5
11A.1 Chapter 5 provisions
(1) In this Rule:
regulatory investment test means a regulatory investment test
under Part D of Chapter 5.
(2) A Primary Transmission Network Service Provider is not required to
publish or provide information under clause 5.2A.5(a) until
1 July 2020.
-- 278 of 290 --
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(3) A Distribution Network Service Provider is not required to have and
publish its first information pack under clause 5.3A.3(a)(3) until
1 July 2020.
(4) A Distribution Network Service Provider is not required to include in
its first Distribution Annual Planning Report published under
clause 5.13.2 the information specified in clause S5.8(a)(5) if
information on energy and demand forecasts was not required to be
reported by the Distribution Network Service Provider under
jurisdictional electricity legislation applicable at the time the
previous report was prepared.
(5) The requirement to undertake a regulatory investment test does not
apply in relation to:
(a) a project that was assessed by the AER for the purposes of its
distribution determination for Power and Water Corporation
(ABN 15 947 352 360) for the period of 5 years commencing
on 1 July 2019; or
(b) a project where an assessment equivalent to a regulatory
investment test has been commenced by Power and Water
Corporation before 1 July 2019.
(6) A Transmission Network Service Provider is not required to comply
with clause 5.18A.3(f) until 1 July 2024 in relation to the content of
an impact assessment under that clause.
Part B Savings and transitional rules for Chapter 5A
Note
Part B of this Chapter has no effect in this jurisdiction until 1 July 2019 (see
regulation 5A of the National Electricity (Northern Territory) (National Uniform
Legislation) (Modification) Regulations).
11A.2 Model standing offers
11A.2.1 Definitions
In this Rule:
NT distributor means Power and Water Corporation ABN 15 947
352 360.
relevant provisions means Chapter 5A and Chapter 6, Part DA.
transition date means the date on which the transition period
ends.
-- 279 of 290 --
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Regulations 2016 274
transition period means the period from the commencement of the
1st regulatory control period (being 1 July 2019) to 30 June 2020.
11A.2.2 Extended meaning of some terms
During the transition period:
(a) a basic connection service includes not only a connection
service for which a model standing offer has been approved
by the AER (see paragraph (c) of the definition in
clause 5A.A.1) but also one for which the AER's approval of a
model standing offer is not required;
(b) a standard connection service includes not only a connection
service for which a model standing offer has been approved
by the AER (see the definition in clause 5A.A.1) but also one
for which the AER's approval of a model standing offer is not
required; and
(c) a model standing offer includes a document prepared and
published by the NT distributor, without the AER's approval,
as a model standing offer to have effect during the transition
period (but not beyond the end of that period).
11A.2.3 Transitional operation of relevant provisions
(a) During the transition period, the relevant provisions operate subject
to the exclusions, qualifications and modifications prescribed by this
Rule.
(b) However, the relevant provisions operate without the exclusions,
qualifications and modifications prescribed by this Rule insofar as
they relate to:
(1) a period beyond the transition period; or
(2) a person (such as a new entrant to the industry) that is not the
NT distributor.
Example
If the NT distributor submits a regulatory proposal for the regulatory control
period that follows the transition period, the distributor is bound by the relevant
provisions (without exclusion, qualification or modification) in relation to the
regulatory proposal even though the proposal is submitted during the transition
period.
(c) A transaction commenced by or with the NT distributor during the
transition period may be continued and completed after the
transition period without regard to changes to the rules governing
the transaction that take effect at the end of the transition period.
-- 280 of 290 --
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11A.2.4 Exclusions, qualifications and modifications
During the transition period, the relevant provisions apply to, and in
relation to, the NT distributor subject to the following exclusions,
qualifications and modifications:
Model standing offers (basic connection services)
(a) A document, prepared by the NT distributor and published on
the NT distributor's website, will (although not approved by the
AER) be regarded as a model standing offer to provide basic
connection services during the transition period if it complies
with the requirements of clause 5A.B.2(b) as to its terms and
conditions.
(b) If, during the transition period, the AER approves a model
standing offer for the same basic connection services, the
approved model standing offer supersedes the former model
standing offer under this clause.
(c) The NT distributor's obligation to have a model standing offer
to provide basic connection services (clause 5A.B.1) operates
during the transition period but the AER's approval of the
model standing offer is not required until the transition date.
(d) The NT distributor's obligation to submit for the AER's
approval a proposed model standing offer to provide basic
connection services (clause 5A.B.2(a)) does not arise until
31 December 2019.
Model standing offer (standard connection services)
(e) A document, prepared by the NT distributor and published on
the NT distributor's website, will (although not approved by the
AER) be regarded as a model standing offer to provide
standard connection services during the transition period if it
complies with the requirements of clause 5A.B.4(c) as to its
terms and conditions.
(f) If, during the transition period, the AER approves a model
standing offer for the same standard connection services, and
the approved model standing offer is to take effect before the
end of the transition period, the approved model standing offer
supersedes the former model standing offer.
(g) The NT distributor may submit for the AER's approval a model
standing offer to provide standard connection services
(clause 5A.B.4) during the transition period but the AER's
approval of the standing offer is not required until the transition
date.
-- 281 of 290 --
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Regulations 2016 276
Amendment of standing offers
(h) During the transition period, the NT distributor may amend a
standing offer to provide basic connection services or
standard connection services during the transition period by
publishing the amendments and the amended text on its
website. (This paragraph applies during the transition period to
the exclusion of clause 5A.B.6.)
11A.2.5 References
A reference to any of the relevant provisions in a legislative or other
instrument will be construed, during the transition period, as a
reference to the provision as modified by this Rule.
Part C Savings and transitional rules for Chapter 7A
Note
Part C of this Chapter has no effect in this jurisdiction until 1 July 2019 (see
regulation 5A of the National Electricity (Northern Territory) (National Uniform
Legislation) (Modification) Regulations). The application of Part C will be
revisited as part of the phased implementation of the Rules in this jurisdiction.
11A.3 Existing metering installations
(a) This rule applies in relation to a metering installation installed at a
connection point on a transmission network or distribution network
in this jurisdiction that is in service immediately before 1 July 2019.
(b) The following requirements must be complied with in relation to the
metering installation:
(1) the requirements imposed on a metering installation at a
connection point on a distribution network or transmission
network in this jurisdiction by, under or for the purposes of a
law of this jurisdiction that is in force immediately before
1 July 2019 (the NT requirements); and
(2) the requirements imposed in respect of the metering
installation by the Rules.
(c) The requirements imposed in respect of the metering installation by
the following provisions are taken to be complied with:
(1) clause 7A.6.2(a);
(2) clause 7A.6.3(a);
(3) clause 7A.6.4, other than paragraph (b);
(4) clause 7A.6.5;
-- 282 of 290 --
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Regulations 2016 277
(5) schedule 7A.1, other than clause S7A.1.3;
(6) clause S7A.3.2.2;
(7) schedule 7A.5.
(d) For the purposes of the operation of Chapter 7A in respect of the
metering installation, a reference in:
(1) clause 7A.7.2 to "the technical requirements";
(2) clause 7A.7.3 to "requirements of the Rules";
(3) clause 7A.7.4 to "schedule 7A.1" or "relevant accuracy
requirement";
(4) clause 7A.8.7 to "schedule 7A.1";
(5) clause S7A.3.2.2(c) to "requirements of the Rules"; and
(6) Chapter 10, definition metering installation malfunction, to
"the requirements of schedule 7A.1",
must be regarded as a reference to "the NT requirements".
(e) If the metering installation is replaced on or after 1 July 2019,
paragraphs (b) to (d) no longer apply in respect of the metering
installation.
11A.4 Testing metering installations
The time periods for testing of metering installations under
Table S7A.6.1.2 do not apply to metering installations that are at
least 10 years old on 1 July 2019 until 1 July 2022.
11A.5 Metering data services database and related requirements
(1) The Metering Data Provider for this jurisdiction on 1 July 2019 is
not, on or after that date, required to comply with all the
requirements under rule 7A.8 relating to establishing and
maintaining a metering data services database but the following
requirements will apply:
(a) the Metering Data Provider must ensure that all of those
requirements under rule 7A.8 are complied with by
31 March 2025 (with the period between 1 July 2019 and
31 March 2025 being referred to as the transitional period),
including by acquiring, gaining or upgrading computing
capabilities, equipment and other assets and materials, and
establishing or enhancing processes and systems, to ensure
-- 283 of 290 --
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National Electricity (Northern Territory) (National Uniform Legislation) (Modification)
Regulations 2016 278
compliance;
(b) during the transitional period, the Metering Data Provider
must, insofar as is reasonably practicable, use its existing
resources and capabilities (and any upgraded, enhanced,
additional or new resources and capabilities as they become
reasonably available) to comply with those requirements
under rule 7A.8, especially in relation to the validation,
substitution and estimation of metering data in its metering
data services database; and
(c) without limiting paragraph (b), the Metering Data Provider
must use its best endeavours to:
(i) maximise the quality of metering data; and
(ii) maximise transparency in processes for verifying,
validating, calculating and estimating metering data.
(2) During the transitional period:
(a) the requirements imposed by clause S7A.7.13.5(c)(4) and (5)
will not apply in relation to the Metering Data Provider;
(b) the Metering Data Provider is only required to include
information, data and matters on its metering register in
accordance with the requirements of clause S7A.8.8.2(e)(4) to
the extent that it is reasonably able to do so; and
(c) the reference in clause S7A.8.8.2(e)(5) to a communication
guideline, in its application to the Metering Data Provider, will
be taken to be a reference to the interim communication
guideline prepared by NTESMO under rule 11A.6.
(3) In addition, during the transitional period:
(a) the Metering Provider is only required to include information,
data and matters on a register of metering installations in
accordance with the requirements of clause S7A.8.7.1(a)(1) to
the extent that it is reasonably able to do so; and
(b) the reference in clause S7A.8.7.1(a)(2) to a communication
guideline, in its application to the Metering Provider, will be
taken to be a reference to the interim communication guideline
prepared by NTESMO under rule 11A.6.
(4) For the transitional period, if information about a metering
installation is included in the metering register, then the metering
installation is to be taken, for the purposes of Chapter 7A, to be
registered with NTESMO.
-- 284 of 290 --
Schedule 2 Further modifications to operation of National Electricity Rules
National Electricity (Northern Territory) (National Uniform Legislation) (Modification)
Regulations 2016 279
11A.6 Communication guideline
NTESMO is not required to have a comprehensive communication
guideline in place under clause S7A.1.3 until the Metering Data
Provider is in a position to comply with its obligations under
rule 7A.8 relating to establishing and maintaining a metering data
services database, after taking into account the operation of
rule 11A.5, but the following requirements will apply:
(a) NTESMO must have an interim communication guideline in
place by 1 January 2020;
(b) the interim communication guideline must comply with the
requirements of clause S7A.1.3(c), (d) and (e) insofar as is
reasonably practicable and after taking into account the
Metering Data Provider's resources and capabilities during the
period applying under clause 11A.5(1)(a);
(c) NTESMO must maintain the interim communication guideline
until the Metering Data Provider is in a position to comply the
obligations under rule 7A.8, and may review and vary the
interim communication guideline from time to time; and
(d) NTESMO must revise or replace the interim communication
guideline so that a comprehensive communication guideline is
in place when the Metering Data Provider is in a position to
comply with its obligations under rule 7A.8.
11A.7 Timeframes for meters to be installed
(1) In this rule:
commencement date means 1 July 2019.
maintenance replacement means the replacement of a retail
customer's existing meter arranged by a retailer that is based on
the results of sample testing of a meter population carried out in
accordance with Chapter 7A:
(a) which indicates that it is necessary or appropriate, in
accordance with good electricity industry practice, for the
meter to be replaced to ensure compliance with Chapter 7A;
and
(b) details of which have been provided to the retailer under
Chapter 7A, together with the results of the sample testing that
support the need for the replacement.
-- 285 of 290 --
Schedule 2 Further modifications to operation of National Electricity Rules
National Electricity (Northern Territory) (National Uniform Legislation) (Modification)
Regulations 2016 280
new meter deployment means the replacement of an existing
meter of one or more retail customers which is arranged by a
retailer other than where the replacement is:
(a) at the request of the relevant retail customer or to enable the
provision of a product or service the retail customer has
agreed to acquire from the retailer or any other person;
(b) a maintenance replacement; or
(c) as a result of a metering installation malfunction.
(2) This rule applies where, before the commencement date, a retailer
has an outstanding request for a meter to be installed, including in
relation to a new connection, at a retail customer's premises and
that request does not relate to a new meter deployment or a
metering installation malfunction (an existing metering
installation request).
(3) On and from the commencement date, Chapter 7A will apply to an
existing metering installation request as if:
(a) the timeframe for the meter to be installed for the purposes of
clause 7A.6.10(a)(2) ends at the later of:
(i) 6 business days from the date the retailer is informed
that the connection service (as defined in clause 5A.A.1)
is complete; and
(ii) 6 business days from the commencement date;
(b) for the purposes of clause 7A.6.11(a)(2), the retailer received
the request from the retail customer on the commencement
date; and
(c) for the purposes of clause 7A.6.12(a)(1)(ii) and (d), the retailer
received the request from the retail customer on the
commencement date.
-- 286 of 290 --
Schedule 3 Further modifications to operation of National Electricity Rules commencing
on 1 December 2017
National Electricity (Northern Territory) (National Uniform Legislation) (Modification)
Regulations 2016 281
Schedule 3 Further modifications to operation of National
Electricity Rules commencing on
1 December 2017
regulation 9
1 Rules modified
This Schedule modifies the operation of the National Electricity
Rules with effect on and from 1 December 2017.
2 Clause 8.6.1A replaced
Clause 8.6.1A
repeal, insert
8.6.1A Application
For the purposes of this Part only, "Registered Participant" is
deemed to include not just Registered Participants but also
Metering Providers and Metering Data Providers.
3 Chapter 10 modified
Chapter 10, definition retail customer
omit, insert
retail customer
Has the same meaning as in the National Electricity Law.
Otherwise, a person to whom electricity is sold by a retailer, and
supplied in respect of connection points, for the premises of the
person, and includes a person (or a person who is of a class of
persons) prescribed by these Rules for the purposes of this
definition.
Note:
In the context of Chapter 5A, the above definition has been supplemented by a
definition specifically applicable to that Chapter. See clause 5A.A.1.
-- 287 of 290 --
Schedule 4 Further modifications to operation of National Electricity Rules commencing
on 1 July 2019
National Electricity (Northern Territory) (National Uniform Legislation) (Modification)
Regulations 2016 282
Schedule 4 Further modifications to operation of National
Electricity Rules commencing on 1 July 2019
regulation 9A
1 Rules modified
This Schedule modifies the operation of the National Electricity
Rules with effect on and from 1 July 2019.
2 Chapter 10 modified
Chapter 10, definition Registered Participant
omit, insert
Registered Participant
Each of the following:
(a) a Registered participant as defined in the National Electricity
Law;
(b) for the purposes of the Rules, other than Chapter 5, Part A – a
Metering Coordinator;
(c) as set out in clause 8.6.1A, for the purposes of Chapter 8, Part
C – a Metering Provider or Metering Data Provider.
-- 288 of 290 --
ENDNOTES
National Electricity (Northern Territory) (National Uniform Legislation) (Modification)
Regulations 2016 283
ENDNOTES
1 KEY Key to abbreviations
amd = amended od = order
app = appendix om = omitted
bl = by-law pt = Part
ch = Chapter r = regulation/rule
cl = clause rem = remainder
div = Division renum = renumbered
exp = expires/expired rep = repealed
f = forms s = section
Gaz = Gazette sch = Schedule
hdg = heading sdiv = Subdivision
ins = inserted SL = Subordinate Legislation
lt = long title sub = substituted
nc = not commenced
2 LIST OF LEGISLATION
National Electricity (Northern Territory) (National Uniform Legislation) (Modification)
Regulations 2016 (SL No. 17, 2016)
Notified 27 April 2016
Commenced r 9 and sch 3: 1 December 2016; rem:1 July 2016 (r 2)
National Electricity (Northern Territory) (National Uniform Legislation) (Modification)
Amendment Regulations 2017 (SL No. 17, 2017)
Notified 29 June 2017
Commenced 1 July 2017 (r 2)
National Electricity (Northern Territory) (National Uniform Legislation) (Modification)
Amendment Regulations 2018 (SL No. 26, 2018)
Notified 19 December 2018
Commenced 19 December 2018
National Electricity (Northern Territory) (National Uniform Legislation) (Modification)
Amendment Regulations 2019 (SL No. 15, 2019)
Notified 1 July 2019
Commenced 1 July 2019 (r 2)
Statute Law Revision Act 2020 (Act No. 26, 2020)
Assent 19 November 2020
Commenced 20 November 2020 (s 2)
National Electricity (Northern Territory) (National Uniform Legislation) (Modification)
Amendment Regulations 2021(SL No. 21, 2021)
Notified 22 December 2021
Commenced 22 December 2021
National Electricity (Northern Territory) (National Uniform Legislation) (Modification)
Amendment Regulations 2024 (SL No. 12, 2024)
Date made 27 June 2024
Commenced 28 June 2024 (r 2)
-- 289 of 290 --
ENDNOTES
National Electricity (Northern Territory) (National Uniform Legislation) (Modification)
Regulations 2016 284
Electricity Legislation Amendment Regulations 2024 (SL No. 13, 2024)
Date made 27 June 2024
Commenced 1 July 2024 (r 2, s 2(2) Electricity Legislation Amendment
Act 2024 (Act No. 26, 2023) and Gaz S54, 26 June 2024)
3 GENERAL AMENDMENTS
General amendments of a formal nature (which are not referred to in the table
of amendments to this reprint) are made by the Interpretation Legislation
Amendment Act 2018 (Act No. 22, 2018) to: r 1.
4 LIST OF AMENDMENTS
r 2A ins No. 17, 2017, r 4
r 4 amd No. 17, 2017, r 5
r 5A ins No. 17, 2017, r 6
amd No. 15, 2019, r 4
r 6 amd No. 17, 2017, r 7
r 6A ins No. 17, 2017, r 8
exp No. 17, 2016, r 11(2) as sub by No. 17, 2017, r 12
r 7 exp No. 17, 2016, r 11(2) as sub by No. 17, 2017, r 12
r 9 sub No. 17, 2017, r 9
r 9A ins No. 17, 2017, r 9
r 10 amd No. 13, 2024, r 14
pt 4 hdg amd No. 17, 2017, r 10
r 10A ins No. 17, 2017, r 11
exp No. 17, 2016, r 11(2) as sub by No. 17, 2017, r 12
r 11 sub No. 17, 2017, r 12
sch 1 amd No. 17, 2017, r 13; No. 15, 2019, r 5; No. 17, 2016, r 11(2) as sub by
No. 17, 2017, r 12
sch 2 amd No. 17, 2016, r 11(6); No. 17, 2017, r 14; No. 26, 2018, r 4; No. 17,
2016, r 11(1) as sub by No. 17, 2017, r 12; No. 15, 2019, rr 6 to 22; Act
No. 26, 2020, s 3; No. 21, 2021, r 4; No. 17, 2016, r 11(2) as sub by No. 17,
2017, r 12; No. 12, 2024, r 4
sch 3 sub No. 17, 2017, r 15
sch 4 ins No. 17, 2017, r 15
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