National Electricity (Northern Territory) (National Uniform Legislation) (Modification) Regulations 2016 (NT)

The current version of the National Electricity Rules, as modified by these Regulations, is available at: NORTHERN TERRITORY OF AUSTRALIA

NATIONAL ELECTRICITY (NORTHERN TERRITORY) (NATIONAL UNIFORM LEGISLATION) (MODIFICATION) REGULATIONS 2016

As in force at 22 December 2021

Table of provisions Table of provisions NORTHERN TERRITORY OF AUSTRALIA

NORTHERN TERRITORY OF AUSTRALIA

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As in force at 22 December 2021

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NATIONAL ELECTRICITY (NORTHERN TERRITORY) (NATIONAL UNIFORM LEGISLATION) (MODIFICATION) REGULATIONS 2016

Regulations under the National Electricity (Northern Territory) (National Uniform) Legislation Act 2015

Part 1Preliminary matters 1Citation

These Regulations may be cited as the National Electricity (Northern Territory) (National Uniform Legislation) (Modification) Regulations 2016.

2Commencement

(1)
Regulation 9 and Schedule 3 commence on 1 December 2016.
(2)
The remaining provisions of these Regulations commence on 1 July 2016.

2ADefinitions

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 2Modifications to National Electricity Regulations 3National 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.

Part 3Modifications to National Electricity Rules 4Interpretation

(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.

5National 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.

5AApplication 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;
- (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).
6Modification to operation of clause 6.6.1
(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
- (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.

6AModification to operation of clause 6.6.1 in relation to NT transitional regulatory change event

In relation to a pass through event that is a NT transitional regulatory change event prescribed by regulation 10A, the operation of clause 6.6.1 of the National Electricity (NT) Rules is modified as follows:

(a)
the reference in clause 6.6.1(c) to "within 90 business days of the relevant positive change event occurring" must be regarded as a reference to "within 90 business days of the commencement of the 1st regulatory control period";
(b)
the reference in clause 6.6.1(c)(5), (d)(2) and (e)(2) to "in the regulatory year in which, and each regulatory year after that in which, the positive change event occurred" must be regarded as a reference to "in each regulatory year of the 1st regulatory control period";
(c)
the text in clause 6.6.1(f)(3)(i) and (ii) must be regarded as a reference to "the end of the 1st regulatory control period";
(d)
the reference in clause 6.6.1(f)(5) and (g)(2)(ii) to "in the regulatory year in which, and each regulatory year after that in which, the negative change event occurred" must be regarded as a reference to "in each regulatory year of the 1st regulatory control period";
(e)
the text in clause 6.6.1(j)(2)(i) and (ii) and (2A)(i) and (ii) must be regarded as a reference to "the end of the 1st regulatory control period";
(f)
the reference in clause 6.6.1(j)(4) to "regulatory control period in which the pass through event occurred" must be regarded as a reference to "1st regulatory control period";
(g)
the reference in clause 6.6.1(j)(7) to "regulatory control period in which the pass through event occurred or will be factored into the calculation of the Distribution Network Service Provider’s annual revenue requirement for a subsequent regulatory control period" must be regarded as a reference to "1st regulatory control period";
(h)
all references in clause 6.6.1 to "required pass through amount" must be regarded as references to "the costs of providing distribution services or transmission services that are direct control network services (as opposed to the revenue impact) that, as a result of the negative change event, the Network Service Provider has saved, and is likely to save, until the end of the 1st regulatory control period".

7Modification to operation of clause 6.6.1AB

(1)
This regulation applies in relation to an NT positive change event that is a retailer insolvency event as defined in the 2014 NT Network Price Determination, Part B, Schedule 1, clause 1.1.
(2)
Under clause 6.6.1AB(c) of the National Electricity (NT) Rules, the written statement in relation to the NT 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 6.6.1AB of the National Electricity (NT) Rules, the eligible pass through amount in relation to the NT 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
- (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 6.6.1AB of the National Electricity (NT) Rules, should be passed through to Distribution Network Users in respect of the NT positive change event must be taken to be a cost that can be passed through and not a revenue impact of the event.

8Further modifications to operation of Rules

Schedule 2 has effect.

9Further modifications to operation of Rules commencing on 1 December 2017

Schedule 3 has effect.

9AFurther modifications to operation of Rules commencing on 1 July 2019

Schedule 4 has effect.

Part 4Matters prescribed for National Electricity (NT) Rules 10Local event

(1)
For clause 6.6.1(a1)(1AA) of the National Electricity (NT) Rules, a local event is 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:
(a) an insolvency official has been appointed in respect of that retailer; and
(b) the provider is not entitled to payment of that amount in full under the terms of any local support in respect of that retailer.
(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.

10ANT transitional regulatory change event

(1)
For clause 6.6.1(a1)(1AB) of the National Electricity (NT) Rules, a NT transitional regulatory change event is the sum of the changes in relevant obligations that occur between 1 July 2017 and 30 June 2019 if those changes, taken as a sum:
- (a)
  substantially affect the manner in which a Network Service Provider provides direct control services; and
- (b)
  result in a material increase or material decrease in the costs of providing those services.
(2)
For regulation 10A(1)(b), a material increase or material decrease in the costs of providing direct control services occurs if the change in costs (as opposed to the revenue impact) incurred, or likely to be incurred, by a Network Service Provider in any regulatory year of the 1st regulatory control period exceeds 1% of the annual revenue requirement for the Network Service Provider for that regulatory year.
(3)
In this regulation:
direct control service means a distribution service or transmission service that is a direct control network service.
relevant obligation means a regulatory obligation or requirement, other than an obligation or requirement:
- (a)
  in an Act or instrument that was enacted or made on or before 1 July 2017 (even if the obligation or requirement commences after 1 July 2017); or
- (b)
  arising from any repeal, amendment, variation or modification to the National Electricity Law, National Electricity Regulations or National Electricity Rules except as made by or under the Act; or
- (c)
  that the AER has considered or accounted for in a distribution determination for the 1st regulatory control period.
(4)
An expression used in this regulation that is italicised has the same meaning as it has in the National Electricity (NT) Rules.
(5)
For subregulation (3), definition relevant obligation, the reference in section 2D of the National Electricity (NT) Law, definition regulatory obligation or requirement, subsection (1)(b)(v) to "materially affects" must be regarded as a reference to "affects".

Part 5Expiry of provisions 11Expiry 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;
- (b)
  1 July 2029.
Schedule 1Modifications to National Electricity Regulations
regulation 3

Part 1Preliminary matters 1Regulations modified

This Schedule modifies the regulations mentioned in regulation 3.

Part 2Modifications 2Regulation 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.

3Regulation 9 modified

(1) Before regulation 9(1)

insert

(1AA)
For the purposes of paragraph (a) of the definition of reviewable regulatory decision in section 71A of the new National Electricity Law, if a distribution determination accounts for an amount mentioned in clause 6.6.1AA, 6.6.1AB or 6.11.1(ba) of the Rules, the distribution determination is not a reviewable regulatory decision to the extent it accounts for that amount.
(2) After regulation 9(1)
insert
(1A)
However, a determination that, under clause 6.6.1AA of the Rules, is taken to have been made under clause 6.6.1(d) or 6.6.1(g) of the Rules is not a reviewable regulatory decision.
(3) Regulation 9, at the end
insert
Note–
The modifications to this regulation expire on 1 July 2024.

3ASchedule 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)

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

4Schedule 2 modified

Schedule 2, clause 22, at the end

insert

However, this clause has no effect in this jurisdiction.

Schedule 2Further modifications to operation of National Electricity Rules

regulation 8

Part 1Preliminary matters 1Rules modified

This Schedule modifies the operation of the National Electricity Rules.

Part 2Modifications 2Clauses 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.
(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.

3Clause 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)

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.

4Rule 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).

5Chapters 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.

6Clause 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)
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

(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).

7Clause 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.

8Clause 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

9Clause 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), 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.

10Clause 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,

11Clause 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.)

(2) Clause 5.2.2(b)(1) and (3)

omit

13 December 1998

insert

1 July 2019

12Clause 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

(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

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

(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,

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

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.

13Clause 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

(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

(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

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.

14Clause 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

(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

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

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.

15Clause 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.

16Clause 5.2A.2 modified

(1) Clause 5.2A.2(a)

omit

registered

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.

17Clause 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 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)

18Clause 5.2A.6 modified

Clause 5.2A.6(a)

omit

the negotiating principles

insert

Chapter 6

19Clause 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

20Clause 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;

(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

21Clause 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,

22Clause 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.

23Clause 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.

(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.

24Clause 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.

(2) Clause 5.3.4(b1)(d)

omit (all references)

or AEMO

25Clause 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.

25AClause 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.

25BClause 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.

(3) Clause 5.3.5(d) and (g)

omit (all references)

AEMO

insert

NTESMO

25CClause 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

(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

(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.

25DClause 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

(6) Clause 5.3.7(h)

omit

schedule 7.4

insert

schedule 7A.4

25EClause 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

25FClause 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.

(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

(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

25GClause 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

(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

25HClause 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.

25IClause 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

(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),

25JClause 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

25KClause 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.

25LClause 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.

25MClause 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

25NClause 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

25OClause 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.

25PRule 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

25QClause 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.

25RClause 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.

25SClause 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 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.

25TClause 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

25UClause 5.6.2 modified

Clause 5.6.2(a)(1)

omit

AEMO

insert

NTESMO

25VClause 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.

(3) Clause 5.7.1(l)

omit (all references)

AEMO

insert

NTESMO

25WClause 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

25XClause 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.

(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

(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

(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

(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

(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.

25YClause 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.

25ZClause 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

(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

25ZAClause 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.

(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

25ZBClause 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,

(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

AEMO

insert

NTESMO

25ZCClause 5.8.2 modified

Clause 5.8.2

omit

AEMO

insert

NTESMO

25ZDClause 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.

(2) Clause 5.8.3(b)(1) and (2) and (d)

omit (all references)

AEMO

insert

NTESMO

25ZEClause 5.8.4 modified

Clause 5.8.4(a), (c), (d) and (e)

omit (all references)

AEMO

insert

NTESMO

25ZFClause 5.8.5 modified

Clause 5.8.5(a) and (e)

omit (all references)

AEMO

insert

NTESMO

25ZGClause 5.9.2 modified

Clause 5.9.2(b)

omit

AEMO

insert

NTESMO

25ZHClause 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.

25ZIClause 5.9.4 modified

Clause 5.9.4(a), (b) and (d)

omit (all references)

AEMO

insert

NTESMO

25ZJClause 5.9.4A modified

Clause 5.9.4A

omit

AEMO

insert

NTESMO

25ZKClause 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

25ZLClause 5.9.6 modified

(1) Clause 5.9.6(a) and (c)

omit (all references)

AEMO

insert

NTESMO

(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.

25ZMClause 5.10.1 modified

Clause 5.10.1(j2), note

omit

25ZNClause 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.

25ZOClause 5.11.1 modified

Clause 5.11.1(d)

omit

AEMO

insert

NTESMO

25ZPClause 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

25ZQClause 5.12.1 modified

Clause 5.12.1(b)(3)

omit

25ZRClause 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

(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.

25ZSClause 5.13.1 modified

Clause 5.13.1(g)

omit

31 August 2013

insert

31 August 2020

25ZTClause 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.

25ZUClause 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.

25ZVRule 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

25ZWClause 5.14.1 modified

Clause 5.14.1(c), after "dual function assets"

insert

or transmission assets that are regulated under Chapter 6

25ZXClause 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.

25ZYClause 5.15.1 modified

Clause 5.15.1

omit

National Electricity Market

25ZZClause 5.15.2 modified

Clause 5.15.2(b)(4)

omit

intra-regional or inter-regional trading of electricity

insert

trading of electricity within a local electricity system

25ZZAClause 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

25ZZBClause 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.

25ZZCClause 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.

25ZZDClause 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

25ZZEClause 5.16.5 modified

Clause 5.16.5(a)

omit

AEMO

insert

NTESMO

25ZZFClause 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

25ZZGClause 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

25ZZHClause 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.

25ZZIClause 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.

(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.

25ZZJClause 5.17.5 modified

Clause 5.17.5(a)

omit

AEMO

insert

NTESMO

25ZZKRule 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.

25ZZLRule 5.18A modified

Rule 5.18A, heading

omit

Large generator connections

insert

Generator connections

25ZZMClause 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.

25ZZNClause 5.18A.2 modified

(1) Clause 5.18A.2, heading

omit, insert

(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);

(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

(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.

25ZZOClause 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.

(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.

25ZZPClause 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.

25ZZQRule 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).

25ZZRRules 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.

25ZZSRules 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).

25ZZTSchedules 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.

25ZZUSchedule 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.

(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;

25ZZVSchedule 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

25ZZWSchedules 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).

25ZZXSchedule 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.

25ZZYSchedule 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

25ZZZSchedule 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.

25ZZZASchedule 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))

25ZZZBSchedule 5.12 modified

Schedule 5.12, paragraph 1, after "schedule 5.11"

insert

(other than principle 4)

26Clause 5A.A.1 modified

Clause 5A.A.1, definition confidential information

omit (all references)

AEMO

insert

NTESMO

27Clause 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

28Clause 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.

30Clause 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.

31Clause 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.

33Clause 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).

34Clause 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

38Clause 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.

39Clause 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).

41Clause 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).

42Rules 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).

(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):
- areferencetoa“
  (1) 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”.

43Clause 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

(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.

44Clause 6.2.1 modified

Clause 6.2.1, note

omit

Chapter 5A

insert

Chapters 5 and 5A

46Clause 6.2.5 modified

(1) Clause 6.2.5(c)(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

(2) Clause 6.2.5(c), at the end

insert

Note:

The modifications to this paragraph expire on 1 July 2024.

(3) Clause 6.2.5(d)(3)

omit, insert

(4) Clause 6.2.5(d), at the end

insert

Note:

The modifications to this paragraph expire on 1 July 2024.

47Clause 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.

48Clause 6.4.3 modified

(1) Clause 6.4.3(a)(6)

omit, insert

(5A) for a distribution determination for a Distribution Network Service Provider in this jurisdiction that will apply during the 1st regulatory control period – the other revenue increments or decrements (if any) for that year arising from the application during the 2014-19 NT regulatory control period of the control mechanism in the 2014 NT Network Price Determination, as modified by the 2014 NT Ministerial Direction – see paragraph (b)(5A); and

(6) for a distribution determination for a Distribution Network Service Provider in this jurisdiction that will apply after the 1st regulatory control period – the other revenue increments or decrements (if any) for that year arising from the application of a control mechanism in the previous regulatory control period – see paragraph (b)(6);

(2) Clause 6.4.3(a), at the end

insert

Note:

The modifications to this paragraph expire on 1 July 2024.

(3) After clause 6.4.3(b)(5)

insert

(5A) the other revenue increments or decrements referred to in paragraph (a)(5A) are those that are to be carried forward to the 1st regulatory control period as a result of the application during the 2014-19 NT regulatory control period of the control mechanism in the 2014 NT Network Price Determination, as modified by the 2014 NT Ministerial Direction and are apportioned to the relevant year under the distribution determination for the 1st regulatory control period;

Note:

This subparagraph expires on 1 July 2024.

49Clause 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.

50Clause 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.

51Rule 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.

52Clause 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.

53Clause 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.

54Clause 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.

55Clause 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.

56Clause 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).

57Clause 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.

58Clause 6.6.1 modified (expires on 1 July 2024)

(1) Before clause 6.6.1(a1)(1)

insert

(1AB) a NT transitional regulatory change event prescribed by the National Electricity (Northern Territory) (National Uniform Legislation) (Modification) Regulations;

Note:

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 NT transitional regulatory change event.
2
Subparagraph (1AB) expires on 1 July 2024.

(2) Clause 6.6.1(j)(7A), after "6.6.1"

insert

or clause 6.6.1AB

(3) After clause 6.6.1(j)(7A)

insert

Note:

The modification to subparagraph (7A) expires on 1 July 2024.

59Clauses 6.6.1AA and 6.6.1AB inserted

After clause 6.6.1

insert

6.6.1AA Cost pass through – deemed determinations

(a)
On and from 1 July 2019, an amount that:

(1) under clause 3.1.3(a)(ii) of Part B of the 2014 NT Network Price Determination, the AER had determined, on or after 1 July 2018, should be passed through to network users in a regulatory year of the 1st regulatory control period or a subsequent regulatory control period; or

(2) under clause 3.1.3(d)(ii) of Part B of the 2014 NT Network Price Determination, should be passed through to network users in a regulatory year of the 1st regulatory control period or a subsequent regulatory control period as a result of the AER, on or after 1 July 2018, failing to make a determination within the prescribed period,

is taken to be an amount determined under clause 6.6.1(d)(2).

(b)
On and from 1 July 2019, an amount that, under clause 3.1.5(a)(ii)(B) of Part B of the 2014 NT Network Price Determination, the AER had determined, on or after 1 July 2018, should be passed through to network users in a regulatory year of the 1st regulatory control period or a subsequent regulatory control period is taken to be an amount determined under clause 6.6.1(g)(2)(ii).

Note:

This clause expires on 1 July 2024.

6.6.1AB Cost pass through – NT events

(a)
A Distribution Network Service Provider may seek the approval of the AER to pass through to Distribution Network Users a positive pass through amount in relation to an NT positive change event.

Note:

See Part 3 of the National Electricity (Northern Territory) (National Uniform Legislation) (Modification) Regulations for modifications to the operation of this clause 6.6.1AB in relation to certain NT positive change events.

(b)
The AER may require a Distribution Network Service Provider to pass through to Distribution Network Users a negative pass through amount in relation to an NT negative change event as determined by the AER under paragraph (g).

Positive pass through

(c)
To seek the approval of the AER to pass through a positive pass through amount in relation to an NT positive change event, a Distribution Network Service Provider must submit to the AER, within 90 business days after the commencement of the 1st regulatory control period, a written statement that specifies:

(1) the details of the NT positive change event;

(2) the date on which the NT positive change event occurred;

(3) the eligible pass through amount in respect of that NT positive change event;

(4) the positive pass through amount the Distribution Network Service Provider proposes in relation to the NT positive change event;

(5) the amount of the positive pass through amount that the Distribution Network Service Provider proposes should be passed through to Distribution Network Users in each regulatory year after the NT positive change event occurred;

(6) evidence:

(i)
of the actual and likely increase in costs referred to in subparagraph (3); and
(ii)
that such costs occur solely as a consequence of the NT positive change event; and

(7) such other information as may be required under any relevant regulatory information instrument.

(d)
If the AER determines that an NT positive change event has occurred in respect of a statement under paragraph (c), the AER must determine:

(1) the approved pass through amount; and

(2) the amount of that approved pass through amount that should be passed through to Distribution Network Users in each regulatory year after the NT positive change event occurred,

taking into account the matters referred to in paragraph (j).

(e)
Subject to paragraph (k1), if the AER does not make the determinations referred to in paragraph (d) within 40 business days from the later of the date it receives the Distribution Network Service Provider’s statement and accompanying evidence under paragraph (c), and the date it receives any additional information required under paragraph (e1), then, on the expiry of that period, the AER is taken to have determined that:

(1) the positive pass through amount as proposed in the Distribution Network Service Provider’s statement under paragraph (c) is the approved pass through amount in respect of that NT positive change event; and

(2) the amount of that positive pass through amount that the Distribution Network Service Provider proposes in its statement under paragraph (c) should be passed through to Distribution Network Users in each regulatory year after the NT positive change event occurred, is the amount that should be so passed through in each such regulatory year.

(e1) A Distribution Network Service Provider must provide the AER with such additional information as the AER requires for the purpose of making a determination under paragraph (d) within the time specified by the AER in a notice provided to the Distribution Network Service Provider by the AER for that purpose.

Negative pass through

(f)
A Distribution Network Service Provider must submit to the AER, within 90 business days after the later of the commencement of the 1st regulatory control period and the date on which the provider becomes aware of the occurrence of an NT negative change event for the provider, a written statement that specifies:

(1) the details of the NT negative change event;

(2) the date on which the NT negative change event occurred;

(3) the costs in the provision of direct control services and NT equivalent services that the Distribution Network Service Provider has saved and is likely to save as a result of the negative change event until the end of the 1st regulatory control period;

(4) the aggregate amount of those saved costs that the Distribution Network Service Provider proposes should be passed through to Distribution Network Users;

(5) the amount of the costs referred to in subparagraph (4) the Distribution Network Service Provider proposes should be passed through to Distribution Network Users in each regulatory year after the NT negative change event occurred; and

(6) such other information as may be required under any relevant regulatory information instrument.

(f1) If the occurrence of the NT negative change event is not notified by the Distribution Network Service Provider to the AER under paragraph (f) then, as soon as is reasonably practicable and before making a determination referred to in paragraph (g), the AER must notify the Distribution Network Service Provider of the occurrence of that NT negative change event.

(g)
If an NT negative change event occurs (whether or not the occurrence of that NT negative change event is notified by the Distribution Network Service Provider to the AER under paragraph (f)) and the AER determines to impose a requirement on the provider in relation to that NT negative change event as described in paragraph (b), the AER must determine:

(1) the required pass through amount; and

(2) taking into account the matters referred to in paragraph (j):

(i)
how much of that required pass through amount should be passed through to Distribution Network Users (the “negative pass through amount”); and
(ii)
the amount of that negative pass through amount that should be passed through to Distribution Network Users in each regulatory year after the NT negative change event occurred.

(g1) Subject to paragraph (k1), if the AER does not make the determinations referred to in paragraph (g) within 40 business days from:

(1) where the Distribution Network Service Provider notifies the AER of the occurrence of the NT negative change event under paragraph (f) – the later of the date the AER receives the Distribution Network Service Provider’s statement under paragraph (f) and the date the AER receives any information required by the AER under paragraph (h); or

(2) where the Distribution Network Service Provider does not notify the AER of the occurrence of the NT negative change event under paragraph (f) – the later of the date the AER notifies the Distribution Network Service Provider under paragraph (f1) and the date the AER receives any information required by the AER under paragraph (h),

then the AER is taken to have determined that the required pass through amount is zero.

(h)
A Distribution Network Service Provider must provide the AER with such information as the AER requires for the purpose of making a determination under paragraph (g) within the time specified by the AER in a notice provided to the Distribution Network Service Provider by the AER for that purpose.

Consultation

(i)
Before making a determination under paragraph (d) or (g), the AER may consult with the relevant Distribution Network Service Provider and such other persons as the AER considers appropriate, on any matters arising out of the relevant NT positive change event or NT negative change event the AER considers appropriate.

Relevant factors

(j)
In making a determination under paragraph (d) or (g) in respect of a Distribution Network Service Provider, the AER must take into account:

(1) the matters and proposals set out in any statement given to the AER by the Distribution Network Service Provider under paragraph (c) or (f);

(2) in the case of an NT positive change event, the increase in costs in the provision of direct control services or NT equivalent services that, as a result of the NT positive change event, the Distribution Network Service Provider has incurred and is likely to incur until the end of the 1st regulatory control period;

(2A) in the case of a NT negative change event, the costs in the provision of direct control services or NT equivalent services that, as a result of the NT negative change event, the Distribution Network Service Provider has saved and is likely to save until the end of the 1st regulatory control period;

(3) in the case of an NT positive change event, the efficiency of the Distribution Network Service Provider’s decisions and actions in relation to the risk of the NT positive change event, including whether the Distribution Network Service Provider has failed to take any action that could reasonably be taken to reduce the magnitude of the eligible pass through amount in respect of that NT positive change event and whether the Distribution Network Service Provider has taken or omitted to take any action where such action or omission has increased the magnitude of the amount in respect of that NT positive change event;

(4) the time cost of money based on the allowed rate of return for the Distribution Network Service Provider for the 1st regulatory control period;

(5) the need to ensure that the Distribution Network Service Provider only recovers any actual or likely increment in costs under this paragraph (j) to the extent that such increment is solely as a consequence of an NT positive change event or NT negative change event;

(6) in the case of a tax change event(as defined in Part B of the 2014 NT Network Price Determination), any change in the way another tax is calculated, or the removal or imposition of another tax, which, in the AER’s opinion, is complementary to the tax change event concerned;

(7) whether the costs of the NT positive change event or NT negative change event have already been factored into the calculation of the Distribution Network Service Provider’s annual revenue requirement for the 1st regulatory control period or will be factored into the calculation of the Distribution Network Service Provider’s annual revenue requirement for a subsequent regulatory control period;

(7A) the extent to which the costs that the Distribution Network Service Provider has incurred and is likely to incur are the subject of a previous determination made by the AER under this clause or clause 6.6.1; and

(8) any other factors that the AER considers relevant.

Extension of time limits

(k)
The AER must, by written notice to a Distribution Network Service Provider, extend a time limit fixed in paragraph (c) or (f) if the AER is satisfied that the difficulty of assessing or quantifying the effect of the relevant NT positive change event or NT negative change event justifies the extension.

(k1) If the AER is satisfied that the making of a determination under paragraph (d) or (g) involves issues of such complexity or difficulty that the time limit fixed in paragraph (e) or (g1) should be extended, the AER may extend that time limit by a further period of up to 60 business days, provided that it gives written notice to the Distribution Network Service Provider of that extension not later than 10 business days before the expiry of that time limit.

(k2) If the AER extends a time limit under paragraph (k1), it must make available on its website a notice of that extension as soon as is reasonably practicable.

(k3) Subject to paragraph (k6), if the AER gives a written notice to the Distribution Network Service Provider stating that it requires information from an Authority in order to make a determination under paragraph (d) or (g) then, for the purpose of calculating elapsed time, the period between when the AER gives that notice to the Distribution Network Service Provider and when the AER receives that information from that Authority is to be disregarded.

(k4) Subject to paragraph (k6), if the AER gives a written notice to the Distribution Network Service Provider stating that, in order to make a determination under paragraph (d) or (g), it requires information that it anticipates will be made publicly available by a judicial body or royal commission then, for the purpose of calculating elapsed time, the period between when the AER gives that notice to the Distribution Network Service Provider and when that information is made publicly available is to be disregarded.

(k5) Where the AER gives a notice to the Distribution Network Service Provider under paragraph (k3) or (k4), it must:

(1) as soon as is reasonably practicable make available on its website a notice stating when the period referred to in paragraph (k3) or (k4), as the case may be, has commenced;

(2) as soon as is reasonably practicable make available on its website a notice stating when the period referred to in paragraph (k3) or (k4), as the case may be, has ended; and

(3) if the information specified in that notice is required from an Authority, promptly request that information from the relevant Authority.

(k6) Paragraphs (k3) and (k4) do not apply if the AER gives the notice specified in those paragraphs to the Distribution Network Service Provider later than 10 business days before the expiry of the time limit fixed in paragraphs (e) or (g1).

Note:

This clause expires on 1 July 2024.

60Clause 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.

61Clause 6.6.3 modified

Clause 6.6.3(c)(3)

omit

in the market

insert

via a transmission or distribution system in this jurisdiction

62Clause 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.

63Clause 6.6A.1 modified

Clause 6.6A.1(b)(2)(iii)

omit

$30

insert

$15

63AClause 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 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.

63BClause 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)

(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 transmissionservices 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)

63CClause 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,

64Clause 6.8.1 modified

After clause 6.8.1(e)

insert

(ea)
Despite paragraph (e), for a Distribution Network Service Provider in this jurisdiction, the AER must:

(1) after consulting with the Distribution Network Service Provider and other persons as the AER considers appropriate, make a framework and approach paper by 1 August 2017; and

(2) give a copy of the paper to the Distribution Network Service Provider, and publish it, as soon as is reasonably practicable.

Note:

This paragraph expires on 1 July 2019.

65Clause 6.8.1A modified

After clause 6.8.1A(b)

insert

(ba)
Despite paragraph (b), for a distribution determination for a Distribution Network Service Provider in this jurisdiction that will apply during the 1st regulatory control period, the provider must submit the information referred to in paragraph (a) on or before 1 July 2017.

Note:

This paragraph expires on 1 July 2019.

66Clause 6.10.1 modified

After clause 6.10.1(b)

insert

(ba)
In addition, if the draft distribution determination will apply to a distribution system in this jurisdiction during the 1st regulatory control period, the AER must have regard to:

(1) any amount that, under clause 3.1.3(a)(ii) or 3.1.5(a)(ii)(B) of Part B of the 2014 NT Network Price Determination, the AER determined, before 1 July 2018, should be passed through to network users in a regulatory year of the 1st regulatory control period or a subsequent regulatory control period; and

(2) any amount that, under clause 3.1.3(d)(ii) of Part B of the 2014 NT Network Price Determination, should be passed through to network users in a regulatory year of the 1st regulatory control period or a subsequent regulatory control period as a result of the AER failing, before 1 July 2018, to make a determination within the prescribed period.

Note:

This paragraph expires on 1 July 2024.

67Clause 6.11.1 modified

After clause 6.11.1(b)

insert

(ba)
In addition, if the distribution determination will apply to a distribution system in this jurisdiction during the 1st regulatory control period, the AER must have regard to:

Note:

This paragraph expires on 1 July 2024.

68Rule 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

(2) the AER is taken to have complied with the requirements of paragraphs (a) and (b) in making and publishing the Distribution Confidentiality Guidelines.

69Clause 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.

70Clause 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.

71Clause 6.17.1A inserted

After clause 6.17.1

insert

6.17.1A Distribution Ring-Fencing Guidelines deferred until 1 July 2019

Despite clause 6.17.1, the Distribution Ring-Fencing Guidelines have no effect in this jurisdiction until 1 July 2019.

72Clause 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 “DNSP s.”;

(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.

73Clause 6.18.5 modified

After clause 6.18.5(h)

insert

(ha)
For a distribution determination for a Distribution Network Service Provider in this jurisdiction that will apply or applies during the 1st regulatory control period, the reference in paragraph (h) to “the previous regulatory year” must be regarded as a reference to “the year that precedes the relevant regulatory year of the 1st regulatory control period (which may be the last year of the 2014-19 NT regulatory control period)”.

Note:

This paragraph expires on 1 July 2024.

74Clause 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).

75Chapter 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.

75ARule 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

(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

(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

75BRule 6.21.3 modified

Clause 6.21.3(a)

omit

13 December 1998

insert

1 July 2019

75CRule 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

(5) Clause 6.22.2(c)(3)

omit, insert

(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.

76Rule 6.27A inserted

After rule 6.27, in Part O

insert

6.27A Application in this jurisdiction

(a)
Despite rule 6.27, an annual benchmarking report published before 1 January 2018 must not relate to a Distribution Network Service Provider in this jurisdiction.
(b)
For an annual benchmarking report that is to be published between 1 January 2018 and 30 June 2019, the reference in rule 6.27(a) to “direct control services” must, in relation to Distribution Network Service Providers in this jurisdiction, be regarded as a reference to “NT equivalent services”.

Note:

This rule expires on 1 July 2019.

77Clause 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:

(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:

(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.

78Clause 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 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.

79Clause 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

insert

S6.2.3 and S6.2.3A

80Clause 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.

82Clause 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.

83Clause 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).

84Clause 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.

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)

(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.

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.
(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.

85Chapters 6A and 6B modified

After Chapters 6A and 6B, headings

insert

Note:

86Chapter 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.

87Chapter 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.

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.

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 the Metering Data File Format Specification NEM 12 and NEM 13, published by AEMO, with an effective date of 1 December 2017 (Version 1.06).

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.

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.)

(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.

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

(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;
(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 Qualification and requirements of Metering Providers

(a)
This clause applies in respect of the 1st regulatory control period.

Note

The application of this clause in respect of subsequent regulatory control periods will be considered as part of the phased implementation of the Rules in this jurisdiction.

(b)
A Metering Provider must have an ISO 9000 series quality system in place.
(c)
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.

(d)
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:

(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.

(e)
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, provided that person meets all relevant safety and technical requirements in any applicable regulatory instruments or other relevant law.

7A.4.2 Qualification and requirements of Metering Data Providers

(a)
This clause applies in respect of the 1st regulatory control period.

Note:

The application of this clause in respect of subsequent regulatory control periods will be considered as part of the phased implementation of the Rules in this jurisdiction.

(b)
A Metering Data Provider must have an ISO 9000 series quality system in place.
(c)
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.

(d)
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:

(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.

(e)
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, provided 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

(a)
This rule applies in respect of the 1st regulatory control period.

Note:

The application of this rule in respect of subsequent regulatory control periods will be considered as part of the phased implementation of the Rules in this jurisdiction.

(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).
(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.)

(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.)

(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

(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.

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.
(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.

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 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.

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.

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.

(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.

(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.

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,

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.)

(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.
(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.

(1) the Metering Coordinator;

(2) NTESMO; and

(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.
(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.
(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;

(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.

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
(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).
(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,

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.

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.

(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.

(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).

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.)

(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

(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.
(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.

(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).
(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.

(b)
For the 1st regulatory control 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 this Chapter 7A, to be registered with NTESMO.

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

(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).

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.
(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;

(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.)

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
(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.)

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.

(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;
(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.

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
Type	Volume limit per annum per connection point	active	reactive	Minimum acceptable class or standard of components
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
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

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 (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%

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

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.
(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.

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

(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.

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.

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

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).

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.

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.

S7A.5.3.4 Remote and local reading of meters

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.

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.

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

Meters excluding CT connected meters must have a supply contactor.

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.

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.

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.
(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:

closing of the supply contactor performed locally;

remote communication of the status (open/closed) of the supply contactor (if communications are active) from the meter to the NMS;

event logging of local reconnection at that meter.

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.

Tamper detection

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;

(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 (±)

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

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
(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;

(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.
(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.

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.

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;

(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.

88Clause 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).

89Chapter 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).

90Clause 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).

91Clause 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).

92Clause 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.

93Clauses 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).

94Clause 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

95Clause 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

(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)

(10) Clause 8.7.2(g)

omit

and (to the extent relevant) AEMO

96Clause 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).

97Chapter 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).

98Chapter 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).

99Chapter 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 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
(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.

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.

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.

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.

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.

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;
(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;
(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
(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.

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).

(4) Chapter 10, definition franchise customer, at the end

insert

Note:

There are no franchise customers in this jurisdiction.

99AChapter 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.

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).

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.

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.

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.

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.

101Chapter 10 modified (expires on 1 July 2024)

(1) Chapter 10, definitions approved pass through amount, negative pass through amount and positive pass through amount

omit

(2) Chapter 10

insert (in alphabetical order)

approved pass through amount

In respect of a positive change event for a Transmission Network Service Provider:

(a)
the amount which the AER determines should be passed through to Transmission Network Users under clause 6A.7.3(d)(2); or
(b)
the amount which the AER is taken to have determined under clause 6A.7.3(e)(1),

as the case may be.

In respect of a positive change event or NT positive change event for a Distribution Network Service Provider:

(a)
the amount the AER determines should be passed through to Distribution Network Users under clause 6.6.1(d)(2) or 6.6.1AB(d)(2); or
(b)
the amount the AER is taken to have determined under clause 6.6.1(e)(1) or 6.6.1AB(e)(1),

as the case may be.

Note:

The modification to this definition expires on 1 July 2024.

negative pass through amount

In respect of a negative change event for a Transmission Network Service Provider, an amount that is not greater than a required pass through amount as determined by the AER under clause 6A.7.3(g).

In respect of a negative change event or NT negative change event for a Distribution Network Service Provider, an amount that is not greater than a required pass through amount as determined by the AER under clause 6.6.1(g) or 6.6.1AB(g).

Note:

The modification to this definition expires on 1 July 2024.

NT negative change event

A negative change event (as defined in Part B of the 2014 NT Network Price Determination) for a Distribution Network Service Provider:

(a)
that occurred during the 2014-19 NT regulatory control period; and
(b)
in relation to which, on or before 30 June 2019, a determination had not been made under clause 3.1.5(a) of Part B of the 2014 NT Network Price Determination and the time for making it had not expired.

Note:

This definition expires on 1 July 2024.

NT positive change event

A positive change event (as defined in Part B of the 2014 NT Network Price Determination) for a Distribution Network Service Provider:

(a)
that occurred during the 2014-19 NT regulatory control period; and
(b)
in relation to which, on or before 30 June 2019, either:
(i)
a statement had not been submitted under clause 3.1.2 of Part B of the 2014 NT Network Price Determination and the time fixed for submitting it had not expired; or
(ii)
a statement had been submitted under clause 3.1.2 of Part B of the 2014 NT Network Price Determination but a determination had not been made under clause 3.1.3(a) of Part B of the Determination and the time for making it had not expired.

Note:

This definition expires on 1 July 2024.

positive pass through amount

For a Transmission Network Service Provider, an amount (not exceeding the eligible pass through amount) proposed by the provider under clause 6A.7.3(c).

For a Distribution Network Service Provider, an amount (not exceeding the eligible pass through amount) proposed by the provider under clause 6.6.1(c) or 6.6.1AB(c).

Note:

The modification to this definition expires on 1 July 2024.

(3) Chapter 10, definition eligible pass through amount, at the end

insert

In respect of an NT positive change event for a Distribution Network Service Provider, the increase in costs in the provision of direct control services or NT equivalent services that, as a result of that NT positive change event, the Distribution Network Service Provider has incurred and is likely to incur (as opposed to the revenue impact of that event) until the end of the 1st regulatory control period.

Note:

The modification to this definition expires on 1 July 2024.

(4) Chapter 10, definition required pass through amount, at the end

insert

In respect of an NT negative change event for a Distribution Network Service Provider, the costs in the provision of direct control services or NT equivalent services that, as a result of the NT negative change event, the Distribution Network Service Provider has saved and is likely to save (as opposed to the revenue impact of that event) until the end of the 1st regulatory control period.

Note:

The modification to this definition expires on 1 July 2024.

102Chapter 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.

103Chapter 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.

104Chapter 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.

105Clause 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.

106Chapter 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.
(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.
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.
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.
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;
(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 1 January 2024 (with the period between 1 July 2019 and 1 January 2024 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 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.
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.
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.
Schedule 3Further modifications to operation of National Electricity Rules commencing on 1 December 2017
regulation 9

1Rules modified

This Schedule modifies the operation of the National Electricity Rules with effect on and from 1 December 2017.

2Clause 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.

3Chapter 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.

Schedule 4Further modifications to operation of National Electricity Rules commencing on 1 July 2019

regulation 9A

1Rules modified

This Schedule modifies the operation of the National Electricity Rules with effect on and from 1 July 2019.

2Chapter 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.

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

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

r 9 sub No. 17, 2017, r 9

r 9A ins No. 17, 2017, r 9

pt 4 hdg amd No. 17, 2017, r 10

r 10A ins No. 17, 2017, r 11

r 11 sub No. 17, 2017, r 12

sch 1 amd No. 17, 2017, r 13; No., 2019, r 5

sch 2 amd No. 17, 2016, r 11(6); No. 17, 2017, r 14; No. 26, 2018, r 4; No. 15, 2019, rr 6 to 22; Act No. 26, 2020, s 3; No. 21, 2021, r 4

sch 3 sub No. 17, 2017, r 15

sch 4 ins No. 17, 2017, r 15