Network Connection Access, Planning and Expansion
CHAPTER 5

5.	Network Connection Access, Planning and Expansion
Part A	Introduction
5.1	Introduction to Chapter 5
5.1.1	Structure of this Chapter
(a)	This Chapter deals with matters relating to networks.
(b)	It is divided into the following Parts:
(1)	this Part is introductory;
(2)	Part B provides a framework for connection and access to a transmission network or a distribution network and to the national grid;
(3)	Part C addresses the network related issues following the negotiation of a connection agreement under Part B, namely the design of connected equipment, inspection and testing, commissioning and disconnection and reconnection; and
(4)	Part D deals with the planning and expansion of networks and the national grid.
5.1.2	Overview of Part B and connection and access under the Rules
(a)	Rule 5.1A sets out the purpose, application and principles for Part B.
(b)	Rule 5.2 sets out the obligations of Registered Participants under Part B and other relevant Parts of this Chapter 5.
(c)	Rule 5.2A sets out obligations and principles relevant to connection and access to transmission networks and large dedicated connection assets. This includes the classification of certain services relating to assets relevant to connection as prescribed transmission services, negotiated transmission services and non-regulated transmission services. Rule 5.2A does not apply to the declared transmission system of an adoptive jurisdiction.
(d)	Rules 5.3, 5.3A and 5.3AA and Chapter 5A set out processes by which Connection Applicants can negotiate for connection and access to the national grid from a Network Service Provider. The process applicable will depend on the nature of the application. The table below sets out an overview of the relevant processes:

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	

(e)	In addition to the rules referred to in paragraph (d), in relation to connection and access to a distribution network:
(1)	a Distribution Network Service Provider must comply with its negotiating framework and Negotiated Distribution Service Criteria when negotiating the terms and conditions of access to negotiated distribution services;
(2)	disputes relating to the terms and conditions of access to a direct control service or to a negotiated distribution service, access charges or matters referred to in clause 5.3AA(f) (negotiated use of system charges) or 5.3AA(h) (avoided charges for the locational component of prescribed TUOS services) may be referred to the AER in accordance with Part L of Chapter 6;
(3)	Part G of Chapter 5A provides for dispute resolution by the AER for certain disputes under Chapter 5A; and
(4)	other disputes relating to connection and access may be subject to dispute resolution under rule 8.2.
(f)	In addition to the rules referred to in paragraph (d), in relation to connection and access to a transmission network:
(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);
(2)	rule 5.4 provides a framework for Connection Applicants and Transmission Network Service Providers to appoint an Independent Engineer to provide advice on certain technical matters; and
(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).
(g)	Part B also provides for a Dedicated Connection Asset Service Provider to have an access policy for a large dedicated connection asset and for commercial arbitration under rule 5.5 to apply to a large DCA services access dispute.
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.
Part B	Network Connection and Access
5.1A	Introduction to Part B
5.1A.1	Purpose and Application
(a)	This Part B:
(1)	[Deleted]
(2)	has the following aims:
(i)	to detail the principles and guidelines governing connection and access to a network;
(ii)	to establish the process to be followed by a Registered Participant or a person intending to become a Registered Participant for establishing or modifying a connection to a network or for altering generating plant connected to a network;
(iii)	to address a Connection Applicant's reasonable expectations of the level and standard of power transfer capability that the relevant network should provide; and
(iv)	to establish processes to ensure ongoing compliance with the technical requirements of this Part B to facilitate management of the national grid.
(b)	[Deleted]
(c)	If a person who is not a Registered Participant or a person intending to become a Registered Participant requests connection of a load to a transmission network and agrees to comply with this Part B as if that person was a Registered Participant, the relevant Transmission Network Service Provider must comply with this Part B as if that person was a Registered Participant.
(d)	Subject to paragraphs (e) and (g), the following Rules apply in the application of this Part B to transmission services provided by means of, or in connection with, the declared transmission system of an adoptive jurisdiction:
(1)	a reference to a Network Service Provider is, in relation to the provision of connection services, to be read as a reference to a declared transmission system operator; and
(2)	a reference to a Network Service Provider is, in relation to the provision of shared transmission services, to be read as a reference to AEMO.
(e)	A reference in any of the following provisions to a Network Service Provider will, in relation to the declaredtransmission system of an adoptive jurisdiction, be construed as a reference to AEMO:
(1)	clause 5.2.3(b);
(2)	clause 5.2.6;
(3)	clause 5.3A.12;
(4)	clause 5.7.6;
(5)	clause 5.7.7 (except clause 5.7.7(c));
(6)	rule 5.11;
(7)	clause 5.12.1;
(8)	clause 5.12.2 (except clause 5.12.2(c)(2));
(9)	clause 5.14.1;
(10)	schedule 5.1, clause S5.1.2.3;
(11)	schedule 5.3, clause S5.3.5.
(f)	Subject to clause (f1) a reference in:
(1)	the definition of RIT-T proponent in clause 5.10.2;
(2)	clause 5.14.3;
(3)	clause 5.16.4;
(3A)	clause 5.16A.4;
(4)	rule 5.16B;
(5)	rule 5.18;
(6)	rule 5.19;
(7)	rule 5.20B; and
(8)	rule 5.20C,
to a Transmission Network Service Provider will, in relation to the declared transmission system of an adoptive jurisdiction, be construed as a reference to AEMO.
(f1)	A reference in:
(1)	the definition of RIT-T proponent in clause 5.10.2;
(2)	clause 5.16.4; and
(2A)	clause 5.16A.4; and
(3)	rule 5.16B,
to a Transmission Network Service Provider will, in relation to the declared transmission system of an adoptive jurisdiction, be construed as a reference to the relevant declared transmission system operator where:
(4)	the relevant RIT-T project (as defined in clause 5.10.2) is to address an identified need that arises from the retirement or de-rating of network assets; and
(5)	a credible option (as defined in clause 5.10.2) for that RIT-T project (as defined in clause 5.10.2) is replacement of network assets.
(g)	A reference in any of the following provisions to a Network Service Provider will, in relation to the declaredtransmission system of an adoptive jurisdiction, be construed as a reference to the relevant declared transmission system operator:
(1)	clause 5.2.3(d)(12), (e) and (e1)(except 5.2.3(e1)(2));
(2)	clause 5.3.4A(c) and (d);
(3)	clause 5.9.3;
(4)	clause 5.9.4;
(5)	clause 5.9.6;
(6)	Schedule 5.1, clause S5.1.10.3(a);
(7)	Schedule 5.2 clause S5.2.3(a)(8).
5.1A.2	Principles
This Part B is based on the following principles relating to connection to the national grid:
(a)	all Registered Participants should have the opportunity to form a connection to a network and have access to the network services provided by the networks forming part of the national grid;
(b)	the terms and conditions on which connection to a network and provision of network service is to be granted are to be set out in commercial agreements on reasonable terms entered into between a Network Service Provider and other Registered Participants;
(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.
(d)	[Deleted]
(e)	the operation of the Rules should result in the achievement of:
(1)	long term benefits to Registered Participants in terms of cost and reliability of the national grid; and
(2)	open communication and information flows relating to connections between Registered Participants themselves, and between Registered Participants and NTESMO, while ensuring the security of confidential information belonging to competitors in the market.
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.
5.2	Obligations
5.2.1	Obligations of Registered Participants
(a)	All Registered Participants must maintain and operate (or ensure their authorised representatives maintain and operate) all equipment that is part of their facilities in accordance with:
(1)	relevant laws;
(2)	the requirements of the Rules; and
(3)	good electricity industry practice and relevant Australian Standards.
(b)	All Registered Participants must ensure that the connection agreements to which they are a party require the provision and maintenance of all required facilities consistent with good electricity industry practice and must operate their equipment in a manner:
(1)	to assist in preventing or controlling instability within the power system;
(2)	to comply with their performance standards;
(3)	to assist in the maintenance of, or restoration to, a satisfactory operating state of the power system; and
(4)	to prevent uncontrolled separation of the power system into isolated network elements, or network break-up, or cascading outages, following any power system incident.
5.2.2	Connection agreements
(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.)
(b)	The Rules apply to:
(1)	connection agreements made after 1 July 2019;
(2)	deemed connection agreements under paragraph (a); and
(3)	requests to establish connection after 1 July 2019.
(c)	This Chapter is neither intended to have, nor is it to be read or construed as having, the effect of:
(1)	altering any of the terms of a connection agreement; or
(2)	altering the contractual rights or obligations of any of the parties under the connection agreement as between those parties; or
(3)	relieving the parties under any such connection agreement of their contractual obligations under such an agreement.
(d)	Notwithstanding the provisions of clause 5.2.2(c), if any obligation imposed or right conferred on a Registered Participant by this Chapter is inconsistent with the terms of a connection agreement to which the Rules apply and the application of the inconsistent terms of the connection agreement would adversely affect the quality or security of network service to other Network Users, the parties to the connection agreement must observe the provisions of this Chapter as if they prevail over the connection agreement to the extent of the inconsistency.
5.2.3	Obligations of network service providers
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.
(a)	To be registered by AEMO as a Network Service Provider, a person must satisfy the relevant requirements specified in Chapter 2 and submit an application to AEMO in such form as AEMO may require.
(b)	A Network Service Provider must comply with the power system performance and quality of supply standards:
(1)	described in jurisdictional electricity legislation;
(2)	in accordance with any connection agreement with a Registered Participant,
and if there is an inconsistency between jurisdictional electricity legislation and such a connection agreement:
(3)	if compliance with the relevant provision of the connection agreement would adversely affect the quality or security of network service to other Network Users, the jurisdictional electricity legislation is to prevail;
(4)	otherwise the connection agreement is to prevail.
Note
This clause is classified as a civil penalty provision under the National Electricity (South Australia) Regulations. (See clause 6(1) and Schedule 1 of the National Electricity (South Australia) Regulations.)
Note
The requirements that will apply under jurisdictional electricity legislation for the purposes of paragraph (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.
(c)	Where the provisions of the connection agreement vary the technical requirements set out in jurisdictional electricity legislation, the relevant Network Service Provider must report on such variations to NTESMO on an annual basis.
Note
This clause is classified as a civil penalty provision under the National Electricity (South Australia) Regulations. (See clause 6(1) and Schedule 1 of the National Electricity (South Australia) Regulations.)
Note
The requirements that will apply under jurisdictional electricity legislation for the purposes of paragraph (c) will be requirements that correspond to the matters set out in the schedules to Chapter 5 in the Rules applying in other participating jurisdictions. The application of paragraph (c) will be revisited as part of the phased implementation of the Rules in this jurisdiction.
(d)	A Network Service Provider must:
(1)	review and process applications to connect or modify a connection which are submitted to it and must enter into a connection agreement with each Registered Participant and any other person to which it has provided a connection in accordance with rules 5.3 or 5.3A (as is relevant) to the extent that the connection point relates to its part of the national grid;
(1A)	co-operate with any other Network Service Provider who is processing a connection enquiry or application to connect to allow that connection enquiry or application to connect to be processed expeditiously and in accordance with rules 5.3 or 5.3A (as is relevant);
(2)	ensure that, to the extent that a connection point relates to its part of the national grid, every arrangement for connection with a Registered Participant or any other arrangement involving a connection agreement with that Network Service Provider complies with all relevant provisions of the Rules;
(3)	co-ordinate the design aspects of equipment proposed to be connected to its networks with those of other Network Service Providers in accordance with rule 5.6 in order to seek to achieve power system performance requirements in accordance with jurisdictional electricity legislation;
(4)	together with other Network Service Providers, arrange for and participate in planning and development of their networks and connection points on or with those networks in accordance with Part D of Chapter 5;
(5)	permit and participate in inspection and testing of facilities and equipment in accordance with rule 5.7;
(6)	permit and participate in commissioning of facilities and equipment which are to be connected to its network in accordance with rule 5.8;
(7)	advise a Registered Participant or other person with whom there is a connection agreement upon request of any expected interruption characteristics at a connection point on or with its network so that the Registered Participant or other person may make alternative arrangements for supply during such interruptions, including negotiating for an alternative or backup connection;
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.)
(8)	use its reasonable endeavours to ensure that modelling data used for planning, design and operational purposes is complete and accurate and order tests in accordance with rule 5.7 where there are reasonable grounds to question the validity of data;
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.)
(9)	provide to NTESMO and other Network Service Providers all data available to it and reasonably required for modelling the static and dynamic performance of the power system;
(10)	forward to NTESMO and other Network Service Providers subsequent updates of the data referred to in subparagraph (9) and, to the best of its ability and knowledge, ensure that all data used for the purposes referred to in rules 5.3 or 5.3A (as is relevant) is consistent with data used for such purposes by other Network Service Providers;
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.)
(11)	provide to NTESMO the information required from Generators and Customers to support a connection application under these Rules and jurisdictional electricity legislation; and
Note
This clause is classified as a civil penalty provision under the National Electricity (South Australia) Regulations. (See clause 6(1) and Schedule 1 of the National Electricity (South Australia) Regulations.)
Note
The requirements that will apply under jurisdictional electricity legislation for the purposes of paragraph (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.
(12)	where network augmentations, setting changes or other technical issues arise which could impact across regional boundaries, provide AEMO with a written report on the impact and its effects.
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.)
(e)	A Network Service Provider (including a Dedicated Connection Asset Service Provider) must arrange for operation of that part of the national grid over which it has control in accordance with instructions given by NTESMO.
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.)
(e1)	A Network Service Provider must, except in so far as its market network services and parts of its network which are used solely for the provision of market network services are concerned, arrange for:
(1)	management, maintenance and operation of its part of the national grid such that, in the satisfactory operating state, electricity may be transferred continuously at a connection point on or with its network up to the agreed capability;
(2)	operation of its network such that the fault level at any connection point on or with that network does not breach the limits that have been specified in a connection agreement;
(3)	management, maintenance and operation of its network to minimise the number of interruptions to agreed capability at a connection point on or with that network by using good electricity industry practice; and
(4)	restoration of the agreed capability at a connection point on or with that network as soon as reasonably practicable following any interruption at that connection point.
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.)
(f)	A Network Service Provider must comply with applicable regulatory instruments.
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.)
(g)	Each Network Service Provider must in respect of new or altered equipment owned, operated or controlled by it for the purpose of providing a market network service:
(1)	submit an application to connect and enter into a connection agreement with a Network Service Provider in accordance with rule 5.3 prior to that equipment being connected to the network of that Network Service Provider or altered (as the case may be);
(2)	comply with the reasonable requirements of AEMO and the relevant Network Service Provider in respect of design requirements of equipment proposed to be connected to the network of that Network Service Provider in accordance with rule 5.6 and schedule 5.3a;
(3)	provide forecast information to the relevant Network Service Provider in accordance with Part D of Chapter 5;
(4)	permit and participate in inspection and testing of facilities and equipment in accordance with rule 5.7;
(5)	permit and participate in commissioning of facilities and equipment which are to be connected to a network for the first time in accordance with rule 5.8; and
(6) 	 [Deleted]
(7)	give notice of intended voluntary permanent disconnection in accordance with rule 5.9.
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.)
(g1)	A Network Service Provider must comply with any terms and conditions of a connection agreement for its market network service facilities that provide for the implementation, operation, maintenance or performance of a system strength remediation scheme.
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.)
(h) 	 [Deleted]
(h1) 	 [Deleted]
(h2) 	 [Deleted]
(h3) 	 [Deleted]
(i)	This Chapter is neither intended to require, nor is it to be read or construed as having the effect of requiring, a Network Service Provider to permit connection to or to augment any part of its network which is solely used for the provision of market network services.
(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
This clause is classified as a civil penalty provision under the National Electricity (South Australia) Regulations. (See clause 6(1) and Schedule 1 of the National Electricity (South Australia) Regulations.)
Note
The application of paragraph (j) will be revisited as part of the phased implementation of the Rules in this jurisdiction.
(k)	If in AEMO's reasonable opinion, information of the type described in clause 4.3.4(o) is required to enable a Network Service Provider to conduct the assessment required by clause 5.3.4B, AEMO may request any other relevant Network Service Provider to provide the information, and following such a request, that Network Service Provider must provide the information to AEMO and the other relevant Network Service Provider.
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.)
(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.
5.2.3A	Obligations of Market Network Service Providers
(a)	If in AEMO's reasonable opinion, there is a risk a Market 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;
(2)	adversely affect the use of a network by a Network User; or
(3)	have an adverse system strength impact,
AEMO may request the Market Network Service Provider to provide information of the type described in clause S5.3a.1(a1), and following such a request, the Market Network Service Provider must provide the information to AEMO and the relevant Network Service Provider(s) in accordance with the requirements and circumstances specified in the Power System Model Guidelines, the Power System Design Data Sheet and the Power System Setting Data Sheet.
Note
This clause is classified as a civil penalty provision under the National Electricity (South Australia) Regulations. (See clause 6(1) and Schedule 1 of the National Electricity (South Australia) Regulations.)
(b)	If in AEMO's reasonable opinion, information of the type described in clause S5.3a.1(a1) is required to enable a Network Service Provider to conduct the assessment required by clause 5.3.4B, AEMO may request a Market Network Service Provider to provide the information, and following such a request, the Market Network Service Provider must provide the information to AEMO and the relevant Network Service Provider.
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.)
(c)	All information provided to AEMO and the relevant Network Service Provider(s) under paragraphs (a) and (b) must be treated as confidential information by those recipients.
5.2.4	Obligations of customers
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.
(a)	Each Customer must plan and design its facilities and ensure that its facilities are operated to comply with:
(1)	its connection agreement with a Network Service Provider;
(2)	subject to clause 5.2.4(a)(1), all applicable performance standards; and
(3)	subject to clause 5.2.4(a)(2), the system standards.
Note
This clause is classified as a civil penalty provision under the National Electricity (South Australia) Regulations. (See clause 6(1) and Schedule 1 of the National Electricity (South Australia) Regulations.)
(b)	A Customer must:
(1)	submit an application to connect in respect of new or altered equipment owned, operated or controlled by the Customer and enter into a connection agreement with a Network Service Provider in accordance with rule 5.3 prior to that equipment being connected to the network of that Network Service Provider or altered (as the case may be);
(2)	comply with the reasonable requirements of the relevant Network Service Provider in respect of design requirements of equipment proposed to be connected to the network of that Network Service Provider in accordance with rule 5.6 and any relevant technical requirements in jurisdictional electricity legislation;
(3)	provide load forecast information to the relevant Network Service Provider in accordance with Part B of Chapter 5;
(4)	permit and participate in inspection and testing of facilities and equipment in accordance with rule 5.7;
(5)	permit and participate in commissioning of facilities and equipment which are to be connected to a network for the first time in accordance with rule 5.8; and
(6) 	 [Deleted]
(7)	give notice of any intended voluntary permanent disconnection in accordance with rule 5.9.
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.
(c)	If in NTESMO’s reasonable opinion, there is a risk that a Customer’s plant will:
(1)	adversely affect network capability, power system security, quality or reliability of supply, inter-regional power transfer capability; or
(2)	adversely affect the use of a network by a Network User,
NTESMO may request a Customer to provide information relating to the protection systems and control systems of the equipment, and following such a request, the Customer must provide the information to NTESMO and the relevant Network Service Provider(s).
Note
This clause is classified as a civil penalty provision under the National Electricity (South Australia) Regulations. (See clause 6(1) and Schedule 1 of the National Electricity (South Australia) Regulations.)
Note
The application of paragraph (c) will be revisited as part of the phased implementation of the Rules in this jurisdiction.
(d)	If in AEMO's reasonable opinion, information of the type described in clause S5.3.1(a1) is required to enable a Network Service Provider to conduct the assessment required by clause 5.3.4B, AEMO may request a Customer to which Schedule 5.3 applies, to provide the information, and following such a request, the Customer must provide the information to AEMO and the relevant Network Service Provider.
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.)
(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.
5.2.5	Obligations of Generators
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.
(a)	A Generator must plan and design its facilities and ensure that they are operated to comply with:
(1)	the performance standards applicable to those facilities;
(2)	subject to subparagraph (1), its connection agreement applicable to those facilities; and
(3)	subject to subparagraph (2), the system standards.
Note
This clause is classified as a civil penalty provision under the National Electricity (South Australia) Regulations. (See clause 6(1) and Schedule 1 of the National Electricity (South Australia) Regulations.)
(b)	A Generator must:
(1)	submit an application to connect in respect of new generating plant owned, operated or controlled by the Generator, or to be owned, operated or controlled by the Generator, and enter into a connection agreement with a Network Service Provider in accordance with rule 5.3 prior to that generating plant being connected to the network of that provider;
(2)	comply with the reasonable requirements of the relevant Network Service Provider in respect of design requirements of generating plant proposed to be connected to the network of that provider in accordance with rule 5.6 and any relevant technical requirements in jurisdictional electricity legislation;
(3)	provide generation forecast information to the relevant Network Service Provider in accordance with Part D of Chapter 5;
(4)	permit and participate in inspection and testing of facilities and equipment in accordance with rule 5.7;
(5)	permit and participate in commissioning of facilities and equipment which are to be connected to a network for the first time in accordance with rule 5.8; and
(6)	give notice of intended voluntary permanent disconnection in accordance with rule 5.9.
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.
(c)	A Generator must comply with any terms and conditions of a connection agreement for its generating system that provide for the implementation, operation, maintenance or performance of a system strength remediation scheme.
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.)
(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
This clause is classified as a civil penalty provision under the National Electricity (South Australia) Regulations. (See clause 6(1) and Schedule 1 of the National Electricity (South Australia) Regulations.)
Note
The application of paragraph (d) will be revisited as part of the phased implementation of the Rules in this jurisdiction.
(e)	If in AEMO's reasonable opinion, information of the type described in clause S5.2.4 is required to enable a Network Service Provider to conduct the assessment required by clause 5.3.4B, AEMO may request a Generator to provide the information, and following such a request, the Generator must provide the information to AEMO and the relevant Network Service Provider.
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.)
(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.
5.2.6	Obligations of AEMO
AEMO must provide to Network Service Providers on request, a copy of any report provided to AEMO by a Network Service Provider under clause 5.2.3(d)(12). If a Registered Participant reasonably considers that it is or may be adversely affected by a development or change in another region, the Registered Participant may request the preparation of a report by the relevant Network Service Provider as to the technical impacts of the development or change. If so requested, the Network Service Provider must prepare such a report and provide a copy of it to AEMO, the Registered Participant requesting the report and, on request, any other Registered Participant.
5.2.6A	AEMO review of technical requirements for connection
(a)	AEMO must conduct a review of some or all of the technical requirements set out in Schedule 5.2, Schedule 5.3 and Schedule 5.3a at least once in every five year period (and may conduct a review more frequently if AEMO considers necessary) to assess whether those requirements should be amended, having regard to:
(1)	the national electricity objective;
(2)	the need to achieve and maintain power system security;
(3)	changes in power system conditions; and
(4)	changes in technology and capabilities of facilities and plant.
(b)	When conducting a review under this clause 5.2.6A, AEMO must consult with, among other affected parties, the Reliability Panel.
(c)	AEMO must commence a review under this clause 5.2.6A with the publication of an approach paper on its website, which must:
(1)	set out the scope of the review, including the nature and extent of the issues to be reviewed;
(2)	describe the technical requirements to be consulted on; and
(3)	state the date by which a draft report will be published.
(d)	AEMO must publish a draft report on its website that:
(1)	sets out AEMO's recommendations for any amendments to the technical requirements set out in Schedule 5.2, Schedule 5.3 and Schedule 5.3a and the reasons for those recommendations; and
(2)	includes an invitation for written submissions to be made to AEMO within a period specified in the invitation (which must be at least 30 business days) on the technical requirements and recommendations in the draft report and must publish any submissions on its website, subject to obligations in respect of confidential information.
(e)	AEMO must publish a final report on its website within 12 months of the approach paper's publication under paragraph (c), setting out AEMO's recommendations for any amendments to the technical requirements set out in Schedule 5.2, Schedule 5.3 and Schedule 5.3a, having regard to the matters set out in subparagraphs (a)(1) to (4) and any submissions made in response to its invitation under subparagraph (d)(2).
(f)	As soon as practicable following publication of a final report under paragraph (e), AEMO must provide written notification to the AEMC as to whether AEMO will be submitting a Rule change proposal that results from the review.
5.2.7	Obligations of Dedicated Connection Asset Service Providers
(a)	A Dedicated Connection Asset Service Provider must classify its dedicated connection asset as a small dedicated connection asset or a large dedicated connection asset in accordance with jurisdictional electricity legislation.
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.
(b)	A Dedicated Connection Asset Service Provider must plan and design its dedicated connection assets and ensure that they are operated to comply with:
(1)	the performance standards applicable to those facilities connected to those dedicated connection assets;
(2)	subject to subparagraph (1), its connection agreement applicable to those dedicated connection assets; and
(3)	subject to subparagraph (2), the system standards.
Note
This clause is classified as a civil penalty provision under the National Electricity (South Australia) Regulations. (See clause 6(1) and Schedule 1 of the National Electricity (South Australia) Regulations.)
(c)	A Dedicated Connection Asset Service Provider for a large dedicated connection asset must prepare, maintain and publish an access policy in accordance with clause 5.2A.8.
(d)	A Dedicated Connection Asset Service Provider must:
(1)	permit and participate in inspection and testing of facilities and equipment in accordance with rule 5.7;
(2)	permit and participate in commissioning of facilities and equipment which are to be connected to a network for the first time in accordance with rule 5.8;
(3)	give notice of intended voluntary permanent disconnection in accordance with rule 5.9; and
(4)	in relation to a connection to an identified user shared asset, ensure that there is a connection agreement between itself and the Primary Transmission Network Service Provider.
5.2A	Transmission network connection and access
5.2A.1	Application
(a)	This rule 5.2A does not apply in relation to connection and access to the declared transmission system of an adoptive jurisdiction.
(b)	In this rule 5.2A, a reference to ownership in relation to an asset includes a leasehold interest.
5.2A.2	Relevant assets
(a)	The assets relevant to connection and access to the transmission network and the person who is responsible for those assets are set out in the following table:

Asset	Responsible Person	
primary transmission network in the participating jurisdictions.	Primary Transmission Network Service Provider 	
identified user shared asset owned by the Primary Transmission Network Service Provider	Primary Transmission Network Service Provider 
(forms part of that provider's broader transmission network)	
third party IUSA 	Primary Transmission Network Service Provider (as controller and operator of the third party IUSA under a network operating agreement)
(forms part of that provider's broader transmission network)	
dedicated connection asset 	Dedicated Connection Asset Service Provider 	
network connection asset 	Transmission Network Service Provider 	
facility of a Transmission Network User	Transmission Network User (if registration required or obtained)	

(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.
5.2A.3	Connection and access to transmission services
(a)	The following transmission services are relevant to connection and access to the transmission network:

Service classification	TNSP obligations	Assets involved	
prescribed transmission services 	Subject to access under Chapter 5 and economic regulation under Chapter 6	transmission network and network connection assets	
negotiated transmission services 	Subject to access under Chapter 5 and economic regulation under Chapter 6	transmission network 	
large DCA services 	Subject to access under the access policy established under clause 5.2A.8	large dedicated connection assets 	
non-regulated transmission services 	Not subject to access under Chapter 5 or economic regulation under Chapter 6	transmission system 	

(b)	A Connection Applicant may apply to a Transmission Network Service Provider for provision of a prescribed transmission service or a negotiated transmission service in accordance with rule 5.3 and the relevant Transmission Network Service Provider must comply with this Chapter 5 in negotiating a connection agreement for the requested service.
(c)	If the prescribed transmission service or negotiated transmission service sought under paragraph (b) does not require the Connection Applicant to establish or modify a connection or alter a generating plant in the circumstances set out in clause 5.3.9, the processes in 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).
(d)	A Transmission Network Service Provider must provide prescribed transmission services or negotiated transmission services on terms and conditions of access that are consistent with the requirements of Chapters 4, 5 and 6A of the Rules (as applicable).
(e)	A Transmission Network Service Provider or a person who is provided prescribed transmission services or negotiated transmission services must not engage in conduct for the purpose of preventing or hindering access to those services.
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.)
(f)	The Connection Applicant may terminate negotiations with the Transmission Network Service Provider at any time during the connection process provided under rules 5.3 and 5.3A with at least three business days' prior written notice.
(g)	A Transmission Network Service Provider may terminate negotiations with the Connection Applicant with at least three business days' prior written notice if:
(1)	the Connection Applicant becomes insolvent or an equivalent event occurs;
(2)	the Connection Applicant has, in the Transmission Network Service Provider's reasonable opinion, provided false or misleading information;
(3)	the Transmission Network Service Provider has reasonable grounds to believe that the Connection Applicant is not negotiating in good faith; or
(4)	the Transmission Network Service Provider has formed the reasonable opinion that the Connection Applicant does not intend to obtain the service.
5.2A.4	Transmission services related to connection
(a)	If a service related to assets relevant for connection in the following table is classified as:
(1)	contestable – then the Primary Transmission Network Service Provider may (but is not obliged to) provide that service as a non-regulated transmission service on request from a Connection Applicant.
(2)	non-contestable – then the Primary Transmission Network Service Provider has the exclusive right to provide that service and must negotiate under rule 5.3 to do so as a negotiated transmission service  on request from a Connection Applicant.

Asset	Service	Example of service	Classification	
transmission network including identified user shared asset	Functional specification for IUSA	Specification of:
•	preferred equipment suppliers;
•	preferred equipment;
•	land/access requirements;
•	design specifications;
•	single line diagrams;
•	remote monitoring and communication requirements;
•	protection, control and metering requirements;
•	minimum operating conditions;
•	supervisory control and data aquisition system interface requirements;
•	equipment ratings;
•	equipment protection ratings; and
•	spare parts itineraries	non-contestable	
identified user shared asset 	Detailed design for IUSA	Provision of:
•	site plan;
•	asset layout and configuration;
•	the specification for vendor equipment;
•	civil, structural, mechanical and electrical detailed design;
•	issued for construction drawings;
•	as built drawings;
•	tender specifications;
•	cable schedules;
•	protection settings;
•	applicable technical studies;
•	earthing design;
•	the design of lightning protection; and
•	the design of insulation co-ordination,
consistent with the functional specification.	contestable 	
transmission network 	Cut-in works	Interface works which cut into the existing shared transmission network, these may include tower realignment, protection control and communications requirements	non-contestable	
contestable IUSA components 	Construction / ownership	Construction and/or ownership of a substation	contestable 	
non-contestable IUSA components 	Construction / ownership	Installation and ownership of supervisory control and data acquisition systems and cabling forming part of the Primary Transmission Network Service Provider's control system	non-contestable	
identified user shared asset owned by the Primary Transmission Network Service Provider	Control, operation and maintenance	Primary Transmission Network Service Provider provides operation and maintenance services	non-contestable	
third party IUSA 	Control, operation and maintenance under a network operating agreement	See clause 5.2A.7	non-contestable	
dedicated connection assets 	All development aspects	Design, construction, maintenance and ownership of a power line connecting a facility	contestable 	

(b)	If the capital cost of all the components that make up an identified user shared asset is reasonably expected by the Primary Transmission Network Service Provider to be $10 million or less, the Primary Transmission Network Service Provider must undertake the detailed design, construction and ownership of the identified user shared asset as a negotiated transmission service.
(c)	If the capital cost of all the components that make up an identified user shared asset is reasonably expected by the Primary Transmission Network Service Provider to exceed $10 million, the detailed design, construction and ownership of each component of the identified user shared asset is a non-regulated transmission service to the extent that it satisfies the following criteria:
(1)	the component being constructed is new or a complete replacement of existing assets (and does not involve the reconfiguration of existing assets); and
(2)	the detailed design and construction of the relevant component of the identified user shared asset is separable in that the new component will be distinct and definable from the existing transmission network,
("contestable IUSA components").
(d)	To the extent that any components of an identified user shared asset do not satisfy the criteria set out in paragraph (c) ("non-contestable IUSA components"), the Primary Transmission Network Service Provider must negotiate under rule 5.3 to undertake the detailed design, construction and ownership of the non-contestable IUSA components as a negotiated transmission service.
Note
Parties may seek the advice of an Independent Engineer under rule 5.4 if the parties cannot agree on whether a component of an identified user shared asset based on the criteria under subparagraph (c)(1) and (2) is a contestable IUSA component or a non-contestable IUSA component.
5.2A.5	Publication and provision of information
(a)	A Primary Transmission Network Service Provider must publish the information on its website, or provide the information to a Connection Applicant on request, as required by schedule 5.10.
(b)	A Primary Transmission Network Service Provider may charge a Connection Applicant a fee for providing information where specified under schedule 5.10, the amount of which must not be more than necessary to cover the reasonable costs of work required to prepare that information.
(c)	A Transmission Network Service Provider and a Connection Applicant must provide information (including commercial information) reasonably required by the other party that would facilitate effective negotiation for the provision of a negotiated transmission service in a timely manner.
(d)	The Connection Applicant must procure that any persons it engages to undertake services which are specified to be contestable in the table in clause 5.2A.4(a) provide information reasonably requested by the Primary Transmission Network Service Provider.
(e)	Information required to be provided under paragraphs (c) and (d) that is confidential may be provided subject to a condition that the receiving party must not provide any part of that information to any other person without the consent of the party who provided the information.
5.2A.6	Negotiating principles
(a)	If a Connection Applicant seeks access to negotiated transmission services, including in relation to an identified user shared asset, the Transmission Network Service Provider and the Connection Applicant must, in negotiating pursuant to rule 5.3 and other relevant Rules, negotiate in accordance with Chapter 6.
(b)	A Transmission Network Service Provider must, in accordance with the negotiating principles:
(1)	on request, identify and inform a Connection Applicant of the reasonable costs and/or the increase or decrease in costs (as appropriate) of providing a negotiated transmission service;
(2)	on request, demonstrate to a Connection Applicant that the charges for providing a negotiated transmission service reflect those costs and/or the cost increment or decrement (as appropriate);
(3)	determine the potential impact on other Transmission Network Users of the provision of a negotiated transmission service; and
(4)	notify and consult with any affected Transmission Network Users and ensure that the provision of a negotiated transmission service does not result in non-compliance with obligations in relation to other Transmission Network Users under the Rules.
(c)	If an applicant seeks large DCA services, the Dedicated Connection Asset Service Provider must comply with its access policy and the negotiating principles in schedule 5.12.
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.)
5.2A.7	Third party IUSAs
(a)	A person must not commission, or permit the commissioning of, a third party IUSA unless there is a network operating agreement between the owner of that third party IUSA and the Primary Transmission Network Service Provider.
Note
This clause is classified as a civil penalty provision under the National Electricity (South Australia) Regulations. (See clause 6(1) and Schedule 1 of the National Electricity (South Australia) Regulations.)
(b)	The person who owns or is intending to own a third party IUSA and the Primary Transmission Network Service Provider must:
(1)	include terms and conditions in the network operating agreement which give effect to the requirements of paragraphs (c) and (d);
(2)	include terms and conditions in the network operating agreement of the kind set out in Part B of schedule 5.6; and
(3)	negotiate the network operating agreement in accordance with the negotiating principles (where applicable).
(c)	The term of the network operating agreement must be for a period which is at least equal to the term of the longest connection agreement of a member of the initial identified user group for the third party IUSA.
(d)	The network operating agreement must provide for the Primary Transmission Network Service Provider to:
(1)	have operation and control of the third party IUSA (including the rights and obligations to maintain that asset) for an agreed charge or based on an agreed charging methodology;
(2)	have an option to purchase the third party IUSA at fair market value at the expiry or early termination of the network operating agreement;
(3)	alter, replace or augment the third party IUSA;
(4)	have the right to connect other persons to the third party IUSA in accordance with the Rules;
(5)	have unrestricted use of, and access to, the third party IUSA; and
(6)	treat the third party IUSA as forming part of the Primary Transmission Network Service Provider's transmission network in all material respects and provide transmission services to any Transmission Network User in accordance with the Rules.
(e)	A person who owns a third party IUSA must not:
(1)	own, operate or control a generating system;
(2)	own, operate or control a facility utilising electrical energy; or
(3)	be a related entity of a person owning, operating or controlling a generating system or facility utilising electrical energy,
that is connected to that third party IUSA.
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.)
(f)	In paragraph (e):
related entity means, in relation to an entity, an entity that controls, or is controlled by, that first mentioned entity;
entity has the meaning given in the Corporations Act 2001 (Cth) subject to section 64A of the Corporations Act 2001 (Cth) not applying to such meaning; and
control has the meaning given in the Corporations Act 2001 (Cth).
5.2A.8	Access framework for large dedicated connection assets
(a)	This clause 5.2A.8 applies only to large dedicated connection assets.
(b)	A Dedicated Connection Asset Service Provider must prepare, maintain and publish an access policy on its website to provide a framework for applicants to obtain access to large DCA services. An access policy must include, as a minimum, the following information:
(1)	a description of the routes, tenure arrangements and main components of the large dedicated connection asset and the facilities connected to it;
(2)	any material regulatory limitations relating to the development and operation of the large dedicated connection asset;
(3)	the pricing principles and the key terms which are proposed to apply to the provision of large DCA services where such principles and terms must be consistent with schedule 5.12;
(4)	the process by which an applicant may seek access to large DCA services, which must include a right for an applicant to obtain sufficient information to enable it to prepare a request for the large DCA services it requires and contact details for access enquiries; and
(5)	advice on the availability of commercial arbitration under rule 5.5 in the case of a dispute.
(c)	The AER has the function of:
(1)	approving an access policy and variations to it; and
(2)	enforcing compliance with an access policy.
(d)	Within 30 days of an asset being classified as a large dedicated connection asset under in accordance with jurisdictional electricity legislation, a Dedicated Connection Asset Service Provider must submit an access policy for approval by the AER.
Note
This clause is classified as a civil penalty provision under the National Electricity (South Australia) Regulations. (See clause 6(1) and Schedule 1 of the National Electricity (South Australia) Regulations.)
Note
The 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.
(e)	A Dedicated Connection Asset Service Provider may seek approval of a variation to an access policy from the AER at any time and must do so where required to keep the access policy up to date.
(f)	The AER must approve an access policy, or a variation to an access policy, if it is reasonably satisfied that it complies with paragraph (b). If the AER does not approve an access policy submitted under paragraph (d), the AER must notify of the changes required for it to be approved. If an access policy is not approved within 6 months of the AER's notification of required changes, the AER may itself propose an access policy.
(g)	The AER's proposal for an access policy is to be formulated with regard to:
(1)	the minimum requirements set out in paragraph (b);
(2)	the Dedicated Connection Asset Service Provider's proposed access policy; and
(3)	the AER's reasons for refusing to approve the proposed access policy.
(h)	The AER may (but is not obliged to) consult on its proposal.
(i)	If the AER decides to approve an access policy proposed by the AER, it must:
(1)	give a copy of the decision to the Dedicated Connection Asset Service Provider; and
(2)	publish the decision on the AER's website and make it available for inspection, during business hours, at the AER's public offices.
(j)	An access policy, or a variation to it, takes effect on a date fixed in the AER's decision to approve it.
(k)	A Dedicated Connection Asset Service Provider must report on requests for connection and access to a large dedicated connection asset to the AER when such requests are made and when an agreement for access is entered into, in the manner and form notified by the AER.
(l)	A Dedicated Connection Asset Service Provider or a person who is provided large DCA services must not engage in conduct for the purpose of preventing or hindering access to large DCA services.
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.)
(m)	A Dedicated Connection Asset Service Provider may, but is not required to, give access to an applicant for large DCA services if doing so would mean the large dedicated connection asset would no longer constitute a dedicated connection asset.
Note
An example of where clause 5.2A.8(m) may apply is where the applicant for access to large DCA services is a Distribution Network Service Provider or a person not seeking access to those services as part of the identified user group. The creation of a new connection point could change the nature of the services being provided by the large dedicated connection asset and therefore change its regulatory treatment.
5.3	Establishing or Modifying Connection
5.3.1	Process and procedures
(a)	For the purposes of this rule 5.3:
establish a connection includes modify an existing connection or alter plant but does not include alterations to generating plant in the circumstances set out in clause 5.3.9.
(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.
(c)	A Generator wishing to alter connected generating plant must comply with clause 5.3.9.
(d)	NTESMO must comply with clause 5.3.11 in relation to requests to change normal voltage.
(e)	For connection to a transmission network, there may be more than one Connection Applicant in relation to a connection where there are different persons developing and owning contestable IUSA components, dedicated connection assets and Transmission Network User facilities in relation to that connection.
5.3.1A	Application of rule to connection of embedded generating units
(a)	
(b)	If a Connection Applicant wishes to connect an embedded generating unit, then:
(1)	unless otherwise provided, rule 5.3A applies to the proposed connection and clauses 5.3.2, 5.3.3, 5.3.4 and 5.3.5 do not apply to the proposed connection; and
(2)	for the avoidance of doubt, the application of the balance of Chapter 5, Part B to the Connection Applicant is otherwise unaffected by this clause 5.3.1A.
(c)	A reference to a Connection Applicant in paragraph (b) is to a:
(1)	person who intends to be an Embedded Generator;
(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)	non-registered embedded generator who has made an election under clause 5A.A.2(c); or
(4)	non-registered embedded generator above the relevant materiality threshold for the relevant local electricity system, or part of a local electricity system,
and who makes a connection enquiry under clause 5.3A.5 or an application to connect under clause 5.3A.9 in relation to any generating systems, or any network elements used in the provision of a network service, as the case may be.
5.3.2	Connection enquiry
(a)	A person referred to in clause 5.3.1(b) who wishes to make an application to connect must first make a connection enquiry by advising the Local Network Service Provider of the type, magnitude and timing of the proposed connection to that provider's network.
(b)	If the information submitted with a connection enquiry is inadequate to enable the Local Network Service Provider to process the enquiry the provider must within 5 business days, advise the Connection Applicant what other relevant preliminary information of the kind listed in schedule 5.4 is required before the connection enquiry can be further processed.
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.)
(c)	The Local Network Service Provider must advise the Connection Applicant within 10 business days of receipt of the connection enquiry and the further information required in accordance with paragraph (b) if the enquiry would be more appropriately directed to another Network Service Provider.
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.)
(d)	The Connection Applicant, notwithstanding the advice received under paragraph (c), may if it is reasonable in all the circumstances, request the Local Network Service Provider to process the connection enquiry and the provider must meet this request.
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.)
(e)	Where the Local Network Service Provider considers that the connection enquiry should be jointly examined by more than one Network Service Provider, with the agreement of the Connection Applicant, one of those Network Service Providers may be allocated the task of liaising with the Connection Applicant and the other Network Service Providers to process and respond to the enquiry.
(f)	A Network Service Provider must to the extent that it holds technical information necessary to facilitate the processing of a connection enquiry made in accordance with paragraph (a) or an application to connect in accordance with clause 5.3.4(a), provide that information to the Connection Applicant in accordance with the relevant requirements of jurisdictional electricity legislation.
Note
This clause is classified as a civil penalty provision under the National Electricity (South Australia) Regulations. (See clause 6(1) and Schedule 1 of the National Electricity (South Australia) Regulations.)
Note
The requirements that will apply under jurisdictional electricity legislation for the purposes of paragraph (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.
(g)	If applicable, a Primary Network Service Provider may charge a Connection Applicant an enquiry fee, the amount of which must not be more than necessary to cover the reasonable costs of work required to provide the information in clauses 5.3.3(b)(5A) and (7) to (10).
5.3.3	Response to connection enquiry
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.
(a)	In preparing a response to a connection enquiry, the Network Service Provider must liaise with other Network Service Providers with whom it has connection agreements, if the Network Service Provider believes, in its reasonable opinion, that compliance with the terms and conditions of those connection agreements will be affected. The Network Service Provider responding to the connection enquiry may include in that response the reasonable requirements of any such other Network Service Providers for information to be provided by the Connection Applicant.
(b)	The Network Service Provider must:
(1)	within 30 business days after receipt of the connection enquiry and all such additional information (if any) advised under clause 5.3.2(b); or
(2)	within 30 business days after receipt of a request from the Connection Applicant to the Local Network Service Provider to process the connection enquiry under clause 5.3.2(d),
provide the following information in writing to the Connection Applicant:
(3)	the identity of other parties that the Network Service Provider considers:
(i)	will need to be involved in planning to make the connection; and
(ii)	must be paid for transmission services or distribution services in the appropriate jurisdiction;
(4)	whether it will be necessary for any of the parties identified in subparagraph (3) to enter into an agreement with the Connection Applicant in respect of the provision of connection or other transmission services or distribution services or both, to the Connection Applicant;
(5)	in relation to Distribution Network Service Providers and Network Service Providers for declared transmission systems, whether any service the Network Service Provider proposes to provide is contestable in the relevant participating jurisdiction;
(5A)	whether any service a Transmission Network Service Provider proposes to provide in relation to the connection enquiry is a prescribed transmission service, a negotiated transmission service or a non-regulated transmission service including, if applicable:
(i)	whether the capital cost of any identified user shared asset is reasonably expected to exceed $10 million; and
(ii)	if so, the contestable IUSA components and non-contestable IUSA components;
(6)	a preliminary program showing proposed milestones for connection and access activities which may be modified from time to time by agreement of the parties, where such agreement must not be unreasonably withheld;
(7)	the specification of the interface required to provide the connection, including plant and equipment requirements for the connection of a dedicated connection asset to the transmission network and of the interface between the transmission network and any contestable IUSA components;
(8)	if applicable, the scope of work for any non-contestable IUSA components;
(9)	if the response to the connection enquiry specifies the need for an identified user shared asset the capital cost of which is reasonably expected to exceed $10 million, a functional specification:
(i)	setting out the technical parameters for that asset as described in the table in clause 5.2A.4 with sufficient detail to enable the Connection Applicant to obtain binding tenders for the provision of detailed design, construction and ownership services for the contestable IUSA components;
(ii)	at the Primary Transmission Network Service Provider's option, that is above those minimum requirements in subparagraph (i) subject to the Primary Transmission Network Service Provider separately identifying the additional requirements and agreeing to fund the additional works related to those requirements;
(10)	an indicative costing for operation and maintenance services for any identified user shared asset, based on the functional specification provided pursuant to subparagraph (9); and
(11)	the amount of any enquiry fee under clause 5.3.2(g).
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.)
(b1)	The Network Service Provider must:
(1)	within 30 business days after receipt of the connection enquiry and all such additional information (if any) advised under clause 5.3.2(b); or
(2)	within 30 business days after receipt of a request from the Connection Applicant to the Local Network Service Provider to process the connection enquiry under clause 5.3.2(d),
provide the Connection Applicant with the following written details of each technical requirement relevant to the proposed plant:
(3)	the access arrangements specified in the jurisdictional electricity legislation; and
(4)	
(5)	
(6)	
(7)	the normal voltage level, if that is to change from the nominal voltage level.
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.)
(b2)	A Registered Participant, AEMO or interested party may request the Reliability Panel to determine whether, in respect of one or more technical requirements for access, an existing Australian or international standard, or a part thereof, may be adopted as a plant standard for a particular class of plant.
(b3)	Where, in respect of a technical requirement for access, the Reliability Panel determines a plant standard for a particular class of plant in accordance with clause 8.8.1(a)(8) as an acceptable alternative to a particular minimum access standard or automatic access standard, a plant which meets that plant standard is deemed to meet the applicable automatic access standard or minimum access standard for that technical requirement.
(b4)	In making a determination in accordance with clause 5.3.3(b2) the Reliability Panel must consult Registered Participants and AEMO using the Rules consultation procedures.
(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.
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.)
(c)	Within 30 business days after receipt of the connection enquiry and all such additional information (if any) advised under clause 5.3.2(b) or, if the Connection Applicant has requested the Local Network Service Provider to process the connection enquiry under clause 5.3.2(d), within 30 business days after receipt of that request, the Network Service Provider must provide to the Connection Applicant written advice of all further information which the Connection Applicant must prepare and obtain in conjunction with the Network Service Provider to enable the Network Service Provider to assess an application to connect including:
(1)	details of the Connection Applicant's connection requirements, and the Connection Applicant's specifications of the facility to be connected, consistent with the requirements advised in accordance with clause 5.3.3(b1);
(2)	details of the Connection Applicant's reasonable expectations of the level and standard of service of power transfer capability that the network should provide;
(3)	a list of the technical data to be included with the application to connect, which may vary depending on the connection requirements and the type, rating and location of the facility to be connected and will generally be in the nature of the information set out in jurisdictional electricity legislation but may be varied by the Network Service Provider as appropriate to suit the size and complexity of the proposed facility to be connected;
(4)	commercial information to be supplied by the Connection Applicant to allow the Network Service Provider to make an assessment of the ability of the Connection Applicant to satisfy the prudential requirements set out in rule 6.21;
(4a)	the DER generation information that the Network Service Provider requires;
(5)	the amount of the application fee which is payable on lodgement of an application to connect, such amount:
(i)	not being more than necessary to cover the reasonable costs of all work anticipated to arise from investigating the application to connect and preparing the associated offer to connect and to meet the reasonable costs anticipated to be incurred by other Network Service Providers whose participation in the assessment of the application to connect will be required; and
(ii)	must not include any amount for, or in anticipation of, the costs of the person using an Independent Engineer; and
(6)	any other information relevant to the submission of an application to connect.
Note
This clause is classified as a civil penalty provision under the National Electricity (South Australia) Regulations. (See clause 6(1) and Schedule 1 of the National Electricity (South Australia) Regulations.)
Note
The 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.
5.3.4	Application for connection
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.
(a)	A person who has made a connection enquiry under clause 5.3.2 may, following receipt of the responses under clause 5.3.3, make an application to connect in accordance with this clause 5.3.4, clause 5.3.4A and clause 5.3.4B.
(b)	To be eligible for connection the Connection Applicant must submit an application to connect containing:
(1)	the information specified in clause 5.3.3(c);
(2)	the relevant application fee to the relevant Network Service Provider;
(3)	for services related to contestable IUSA components that the Connection Applicant has not obtained from the Primary Transmission Network Service Provider (as applicable):
(i)	the Connection Applicant's process for how the Primary Transmission Network Service Provider will undertake a review of the detailed design and inspect the construction of those components and how risks of defects will be addressed;
(ii)	the detailed design of those components; and
(iii)	if the Primary Transmission Network Service Provider will not own the contestable IUSA components, the Connection Applicant's proposed changes (if any) to the form of network operating agreement published pursuant to schedule 5.10; and
(4)	if the Connection Applicant has obtained services related to contestable IUSA components other than from the Primary Transmission Network Service Provider, all information reasonably required for the Primary Transmission Network Service Provider to properly provide operation and maintenance services for the life of those components, including details of the contestable IUSA components' construction, instructions for operation and maintenance and health safety and asset management manuals.
(b1)	The Connection Applicant's detailed design under paragraph (b)(3)(ii):
(1)	must be consistent with the minimum functional specification provided by the Primary Transmission Network Service Provider under clause 5.3.3(b)(9)(i);
(2)	must not unreasonably inhibit the capacity for future expansion of the identified user shared asset or preclude the possibility of future connections to that asset; and
(3)	subject to the Connection Applicant considering the Primary Transmission Network Service Provider's additional requirements under clause 5.3.3(b)(9)(ii) in good faith, may be (but is not required to be) consistent with those additional requirements.
(c)	In relation to Distribution Network Service Providers and Network Service Providers for declared transmission systems, the Connection Applicant may submit applications to connect to more than one Network Service Provider in order to receive additional offers to connect in respect of facilities to be provided that are contestable.
(d)	To the extent that an application fee includes amounts to meet the reasonable costs anticipated to be incurred by any other Network Service Providers in the assessment of the application to connect, a Network Service Provider who receives the application to connect and associated fee must pay such amounts to the other Network Service Providers, as appropriate.
(e)	For each technical requirement where the proposed arrangement will not meet the automatic access standards nominated by the Network Service Provider pursuant to clause 5.3.3(b1), the Connection Applicant must submit with the application to connect a proposal for a negotiated access standard for each such requirement to be determined in accordance with clause 5.3.4A.
(f)	The Connection Applicant may:
(1)	lodge separate applications to connect and separately liaise with the other Network Service Providers identified in clause 5.3.3(b) who may require a form of agreement;
(2)	lodge one application to connect with the Network Service Provider who processed the connection enquiry and require it to liaise with those other Network Service Providers and obtain and present all necessary draft agreements to the Connection Applicant; or
(3)	lodge a combined application to connect with the Primary Network Service Provider where the connection involves more than one Connection Applicant due to different persons developing and owning contestable IUSA components, dedicated connection assets and Transmission Network User facilities in relation to that connection.
(g)	A Connection Applicant who proposes a system strength remediation scheme under clause 5.3.4B must submit its proposal with the application to connect.
5.3.4A	Negotiated access standards
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.
(a)	AEMO must advise on AEMO advisory matters.
(b)	A negotiated access standard must:
(1)	subject to subparagraph (1A), be no less onerous than the corresponding minimum access standard provided by the Network Service Provider under clauses 5.3.3(b1)(4) or S5.4B(b)(2);
(1A)	with respect to a submission by a Generator under clause 5.3.9(b)(3), be no less onerous than the performance standard that corresponds to the technical requirement that is affected by the alteration to the generating system;
(2)	be set at a level that will not adversely affect power system security;
(3)	be set at a level that will not adversely affect the quality of supply for other Network Users; and
(4)	in respect of generating plant, meet the requirements applicable to a negotiated access standard in Schedule 5.2.
(b1)	When submitting a proposal for a negotiated access standard under clauses 5.3.4(e), 5.3A.9(f), 5.3.9(b)(3) or subparagraph (h)(3), and where there is a corresponding automatic access standard for the relevant technical requirement, a Connection Applicant must propose a standard that is as close as practicable to the corresponding automatic access standard, having regard to:
(1)	the need to protect the plant from damage;
(2)	power system conditions at the location of the proposed connection; and
(3)	the commercial and technical feasibility of complying with the automatic access standard with respect to the relevant technical requirement.
(b2)	When proposing a negotiated access standard under paragraph (b1), the Connection Applicant must provide reasons and evidence to the Network Service Provider and AEMO as to why, in the reasonable opinion of the Connection Applicant, the proposed negotiated access standard is appropriate, including:
(1)	how the Connection Applicant has taken into account the matters outlined in subparagraphs (b1)(1) to (3); and
(2)	how the proposed negotiated access standard meets the requirements of paragraph (b).
(c)	Following the receipt of a proposed negotiated access standard under clauses 5.3.4(e), 5.3A.9(f), 5.3.9(b)(3) or subparagraph (h)(3), the Network Service Provider must consult with AEMO as soon as practicable in relation to AEMO advisory matters for that proposed standard.
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.)
(d)	Within 20 business days following the later of:
(1)	receipt of a proposed negotiated access standard under clauses 5.3.4(e), 5.3A.9(f), 5.3.9(b)(3) or subparagraph (h)(3); and
(2)	receipt of all information required to be provided by the Connection Applicant under clauses S5.2.4, S5.5.6, S5.3.1(a1) or S5.3a.1(a1),
AEMO must advise the Network Service Provider in writing, in respect of AEMO advisory matters, whether the proposed negotiated access standard should be accepted or rejected.
(d1)	When advising the Network Service Provider under paragraph (d) to reject a proposed negotiated access standard, and subject to obligations in respect of confidential information, AEMO must:
(1)	provide detailed reasons in writing for the rejection to the Network Service Provider, including:
(i)	where the basis of AEMO's advice is lack of evidence from the Connection Applicant, details of the additional evidence of the type referred to in paragraph (b2) AEMO requires to continue assessing the proposed negotiated access standard; and
(ii)	the extent to which each of the matters identified at subparagraphs (b)(1), (b)(1A), (b)(2) and (b)(4) contributed to AEMO's decision to reject the proposed negotiated access standard; and
(2)	recommend a negotiated access standard that AEMO considers meets the requirements of subparagraphs (b)(1), (b)(1A), (b)(2) and (b)(4).
(e)	Within 30 business days following the later of:
(1)	receipt of a proposed negotiated access standard in accordance with clauses 5.3.4(e), 5.3A.9(f), 5.3.9(b)(3) or subparagraph (h)(3); and
(2)	receipt of all information required to be provided by the Connection Applicant under clauses S5.2.4, S5.5.6, S5.3.1(a1) or S5.3a.1(a1),
the Network Service Provider must accept or reject a proposed negotiated access standard.
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.)
(f)	The Network Service Provider must reject the proposed negotiated access standard where:
(1)	in the Network Service Provider's reasonable opinion, one or more of the requirements at subparagraphs (b)(1), (b)(1A), (b)(3) and (b)(4) are not met; or
(2)	AEMO has advised the Network Service Provider under paragraph (d) to reject the proposed negotiated access standard.
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.)
(g)	If a Network Service Provider rejects a proposed negotiated access standard, the Network Service Provider must, at the same time:
(1)	subject to obligations in respect of confidential information, provide to the Connection Applicant:
(i)	where the basis for the Network Service Provider's rejection is lack of evidence from the Connection Applicant, details of the additional evidence of the type referred to in paragraph (b2) the Network Service Provider requires to continue assessing the proposed negotiated access standard;
(ii)	detailed reasons in writing for the rejection, including the extent to which each of the matters identified at subparagraphs (b)(1), (b)(1A), (b)(3) and (b)(4) contributed to the Network Service Provider's decision to reject the proposed negotiated access standard; and
(iii)	the detailed reasons and recommendation (if any) provided by AEMO to the Network Service Provider in respect of an AEMO advisory matter under subparagraphs (d1)(1) and (2); and
(2)	advise the Connection Applicant of a negotiated access standard that the Network Service Provider considers meets the requirements of subparagraphs (b)(1), (b)(1A), (b)(3) and (b)(4).
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.)
(h)	The Connection Applicant may in relation to a proposed negotiated access standard advised by a Network Service Provider in accordance with subparagraph (g)(2):
(1)	accept the proposed negotiated access standard;
(2)	reject the proposed negotiated access standard;
(3)	propose an alternative negotiated access standard to be further evaluated in accordance with the criteria in paragraph (b); or
(4)	elect to adopt the relevant automatic access standard or a corresponding plant standard.
(i)	An automatic access standard or if the procedures in this clause 5.3.4A have been followed a negotiated access standard, that forms part of the terms and conditions of a connection agreement, is taken to be the performance standard applicable to the connected plant for the relevant technical requirement.
5.3.4B	System strength remediation for new connections
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.
(a)	A Network Service Provider must, in accordance with the system strength impact assessment guidelines, undertake a system strength impact assessment for each proposed new connection of a generating system or market network service facility and any proposed alteration to a generating system to which clause 5.3.9 applies. A Network Service Provider must make:
(1)	a preliminary assessment if it is in receipt of a connection enquiry or a request by a Generator under clause 5.3.9(c1); and
(2)	a full assessment if it is in receipt of an application to connect or submission from a Generator under clause 5.3.9, unless the preliminary assessment indicates that the full assessment is not needed.
Note
This clause is classified as a civil penalty provision under the National Electricity (South Australia) Regulations. (See clause 6(1) and Schedule 1 of the National Electricity (South Australia) Regulations.)
(b)	The Network Service Provider must give the results of the preliminary assessment and the full assessment to the Connection Applicant or Generator concerned following consultation with AEMO.
(c)	A dispute referred to in paragraph (d) between any of:
(1)	AEMO;
(2)	A Network Service Provider required to conduct an assessment under paragraph (a);
(3)	a Connection Applicant who has submitted an application to connect  for which a full assessment is required under paragraph (a); and
(4)	a Generator who proposes an alteration to a generating system to which clause 5.3.9 applies and for which a full assessment is required under paragraph (a),
may be determined under rule 8.2.
(d)	Paragraph (c) applies to any dispute relating to the assessment of an adverse system strength impact as a result of conducting a system strength impact assessment including a dispute in relation to:
(1)	whether the model specified by AEMO for the purposes of clause 4.6.6(b)(2) was reasonably appropriate for conducting the system strength impact assessment; and
(2)	the application of the system strength impact assessment guidelines when undertaking a system strength impact assessment.
(e)	Subject to paragraph (f), a Network Service Provider must undertake system strength connection works at the cost of the Connection Applicant or Generator (as applicable) if the full assessment undertaken in accordance with the system strength impact assessment guidelines indicates that the Connection Applicant's proposed new connection of a generating facility or market network service facility or the Generator's proposed alteration to a generating system to which clause 5.3.9 applies will have an adverse system strength impact.
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.)
(f)	Paragraph (e) does not require a Network Service Provider to undertake, nor permit a Network Service Provider to require, system strength connection works in the following circumstances:
(1)	the proposed new connection or alteration does not proceed;
(2)	to the extent that the adverse system strength impact referred to in paragraph (e) is or will be avoided or remedied by a system strength remediation scheme agreed or determined under this clause and implemented by the Registered Participant in accordance with its connection agreement; or
(3)	to the extent that the impact is below any threshold specified in the system strength impact assessment guidelines for this purpose.
(g)	A Connection Applicant must include any proposal for a system strength remediation scheme in its application to connect or its proposal under clause 5.3.9(b)(4).
(h)	A Connection Applicant proposing to install plant as part of a system strength remediation scheme must include a description of the plant, the ratings of the proposed plant (in MVA) and other information (including models) reasonably required by the Network Service Provider and AEMO to assess the system strength remediation scheme.
(i)	A Network Service Provider must, following the receipt of a proposal for a system strength remediation scheme, consult with AEMO as soon as practical in relation to the proposal.
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.)
(j)	Following the submission of a proposal for a system strength remediation scheme, AEMO must use reasonable endeavours to respond to the Network Service Provider in writing in respect of the proposal within 20 business days.
(k)	A Network Service Provider must within 10 business days following the receipt of a response from AEMO under paragraph (h) to a proposal for a system strength remediation scheme, accept or reject the proposal.
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.)
(l)	The Network Service Provider must reject a proposal for a system strength remediation scheme if the scheme is not reasonably likely to achieve its required outcome or would:
(1)	in the reasonable opinion of the Network Service Provider adversely affect quality of supply for other Network Users; or
(2)	on AEMO's reasonable advice, adversely affect power system security.
(m)	If a Network Service Provider rejects a proposal for a system strength remediation scheme, the Network Service Provider must give its reasons but has no obligation to propose a system strength remediation scheme that it will accept.
(n)	The Connection Applicant submitting a proposal for a system strength remediation scheme rejected by a Network Service Provider may:
(1)	propose an alternative system strength remediation scheme to be further evaluated following the process initiated under paragraph (i); or
(2)	request negotiations under paragraph (o).
(o)	If a Connection Applicant requests negotiations under this paragraph, the Connection Applicant, the Network Service Provider and AEMO must negotiate in good faith to reach agreement in respect of the proposal for a system strength remediation scheme.
(p)	If the matter is not resolved by negotiation under paragraph (o):
(1)	in the case of a connection to a transmission system other than the declared transmission system of an adoptive jurisdiction, the matter may be dealt with as a dispute under rule 5.5 (but not rule 8.2); or
(2)	otherwise, may be dealt with under rule 8.2 or as a distribution service access dispute as applicable.
(q)	The parties to a connection agreement containing a system strength remediation scheme must not modify the scheme unless the modified scheme has been agreed or determined under this clause. A Registered Participant proposing to modify a system strength remediation scheme must submit its proposal for modification to the Network Service Provider for evaluation by the Network Service Provider and AEMO under this clause. Once agreed or determined, the modified scheme must be incorporated as an amendment to the connection agreement and notified to AEMO under clause 5.3.7(g).
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.)
5.3.5	Preparation of offer to connect
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.
(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.
(b)	The Network Service Provider must use its reasonable endeavours to advise the Connection Applicant of all risks and obligations in respect of the proposed connection associated with planning and environmental laws not contained in the Rules.
(c)	The Connection Applicant must provide such other additional information in relation to the application to connect as the Network Service Provider reasonably requires to assess the technical performance and costs of the required connection (including the details of any person undertaking the construction, detailed design and/or ownership of contestable IUSA components) to enable the Network Service Provider to prepare an offer to connect. to prepare an offer to connect.
(d)	So as to maintain levels of service and quality of supply to existing Registered Participants in accordance with the Rules, the Network Service Provider in preparing the offer to connect must consult with NTESMO and other Registered Participants with whom it has connection agreements, if the Network Service Provider believes in its reasonable opinion, that compliance with the terms and conditions of those connection agreements will be affected, in order to assess the application to connect and determine:
(1)	the technical requirements for the equipment to be connected;
(2)	the extent and cost of augmentations and changes to all affected networks;
(3)	any consequent change in network service charges; and
(4)	any possible material effect of this new connection on the network power transfer capability including that of other networks.
(e)	The Network Service Provider preparing the offer to connect must specify in reasonable detail any system strength connection works to be undertaken by the Network Service Provider.
(f)	[Deleted]
(g)	The Network Service Provider preparing the offer to connect must include provision for payment of the reasonable costs associated with remote control equipment and remote monitoring equipment as required by NTESMO and it may be a condition of the offer to connect that the Connection Applicant pay such costs.
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.)
5.3.6	Offer to connect
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.
(a)	A Network Service Provider processing an application to connect must make an offer to connect the Connection Applicant's facilities to the network within the following timeframes:
(1)	where the application to connect was made under clause 5.3.4(a), the timeframe specified in the preliminary program, subject to clause 5.3.3(b)(6); and
(2)	where the application to connect was made under clause 5.3A.9(b), a period of time no longer than 4 months from the date of receipt of the application to connect and any additional information requested under clause 5.3A.9(d), unless agreed otherwise.
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.)
(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.
(a2)	In relation to the timeframes fixed in paragraph (a)(2), for the purposes of calculating elapsed time, the following periods shall be disregarded:
(1)	the period that commences on the day when a dispute is initiated under clause 8.2.4(a) and ends of the day on which the dispute is withdrawn or is resolved in accordance with clauses 8.2.6D or 8.2.9(a);
(2)	any time taken to resolve a distribution services access dispute; and
(3)	any time taken by AEMO to respond under clause 5.3.4B(j) in excess of 20 business days.
(b)	In relation to an application to connect made under clause 5.3.4(a), the offer to connect must contain the proposed terms and conditions for connection to the network including:
(1)	each technical requirement identified by the Network Service Provider under clause 5.3.3(b1); and
(2)	the terms and conditions of the kind set out in Part A and (where applicable) Part B of schedule 5.6,
and must be capable of acceptance by the Connection Applicant so as to constitute a connection agreement and (where applicable) a network operating agreement.
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.)
(b1)	The proposed terms and conditions detailed in the offer to connect must be no lower than allowed under jurisdictional electricity legislation.
Note
This clause is classified as a civil penalty provision under the National Electricity (South Australia) Regulations. (See clause 6(1) and Schedule 1 of the National Electricity (South Australia) Regulations.)
(b2)	An offer to connect made under paragraph (a)(2), must be accompanied by:
(1)	so far as is relevant, and in relation to services the Distribution Network Service Provider intends to provide, an itemised statement of connection costs including:
(i)	connection service charges;
(ii)	costs associated with metering requirements contained in the offer to connect;
(iii)	costs of network extension;
(iv)	details of augmentation required to provide the connection and associated costs;
(v)	details of the interface equipment required to provide the connection and associated costs;
(vi)	details of any ongoing operation and maintenance costs and charges by the Distribution Network Service Provider; and
(vii)	other incidental costs and their basis of calculation;
(2)	if any item in the statement of costs in subparagraph (1) differs substantially from the estimate provided under clause S5.4B(h), an explanation of the differences;
(3)	a connection agreement capable of execution by the Connection Applicant, which must contain the proposed terms and conditions for connection to the distribution network (of the kind set out in Part A of schedule 5.6) including, for each technical requirement identified by the Distribution Network Service Provider in the detailed response provided under clause 5.3A.8(c), the access standards determined in accordance with jurisdictional electricity legislation; and
(4)	an explanation:
(i)	of how the offer to connect can be accepted; and
(ii)	that the offer to connect remains open for 20 business days, unless otherwise agreed.
(b3)	An offer to connect made under paragraph (a)(2) must remain open for acceptance for 20 business days from the date it is made and, if not accepted within that period, lapses unless the Connection Applicant has sought an extension of the period of time from the Distribution Network Service Provider. The Distribution Network Service Provider may not unreasonably withhold consent to the extension.
(b4)	An offer to connect by a Primary Transmission Network Service Provider made under paragraph (a)(1) must include:
(1)	the Primary Transmission Network Service Provider's requirements in relation to the matters proposed in clause 5.3.4(b)(3) and (b)(4); and
(2)	the costs of the services proposed to be provided by the Primary Transmission Network Service Provider separated between negotiated transmission services and non-regulated transmission services (if applicable).
(b5)	A Connection Applicant may seek amendments to the offer to connect provided that the Connection Applicant agrees to changes to the preliminary program to reflect the additional time required to agree the amendments.
(c)	The offer to connect must be fair and reasonable and must be consistent with the safe and reliable operation of the power system in accordance with the Rules and any relevant jurisdictional electricity legislation. Without limitation, unless the parties otherwise agree, to be fair and reasonable an offer to connect must offer connection and network services consistent with any relevant jurisdictional electricity legislation and must not impose conditions on the Connection Applicant which are more onerous than those contemplated in relevant jurisdictional electricity legislation.
Note
This clause is classified as a civil penalty provision under the National Electricity (South Australia) Regulations. (See clause 6(1) and Schedule 1 of the National Electricity (South Australia) Regulations.)
Note
The requirements that will apply under jurisdictional electricity legislation for the purposes of paragraph (c) will be requirements that correspond to the matters set out in schedules 5.1, 5.2 and 5.3 in the Rules applying in other participating jurisdictions. The application of paragraph (c) will be revisited as part of the phased implementation of the Rules in this jurisdiction.
(c1)	[Deleted]
(d)	The Network Service Provider must use its reasonable endeavours to provide the Connection Applicant with an offer to connect in accordance with the reasonable requirements of the Connection Applicant, including without limitation, the location of the proposed connection point and the level and standard of power transfer capability that the network will provide.
(e)	An offer to connect may contain options for connection to a network at more than one point in a network and/or at different levels of service and with different terms and conditions applicable to each connection point according to the different characteristics of supply at each connection point.
(f)	Both the Network Service Provider and the Connection Applicant are entitled to negotiate with each other in respect of the provision of connection and any other matters relevant to the provision of connection and, if negotiations occur, the Network Service Provider and the Connection Applicant must conduct such negotiations in good faith.
(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.
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.)
(h)	An offer to connect must define the basis for determining distribution service charges in accordance with Chapter 6, including the prudential requirements set out in Part K of Chapter 6.
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.)
(i)	[Deleted]
(j)	An offer to connect in respect of a distribution network made to an Embedded Generator or a Market Network Service Provider, must conform with the relevant access arrangements set out in rule 5.3AA.
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.)
(k)	[Deleted]
5.3.7	Finalisation of connection agreements and network operating agreements
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.
(a)	If a Connection Applicant wishes to accept an offer to connect, the Connection Applicant must negotiate and enter into:
(1)	a connection agreement with each relevant Network Service Provider identified in accordance with clauses 5.3.3(b)(3) and (4) or clauses S5.4.A(d) and (e); and
(2)	if applicable, a network operating agreement with the Primary Transmission Network Service Provider,
and in doing so must use its reasonable endeavours to negotiate in good faith with all parties with which the Connection Applicant must negotiate such a connection agreement and (if applicable) network operating agreement.
(b)	The connection agreement must include proposed performance standards with respect to each of the technical requirements identified in accordance with jurisdictional electricity legislation and each proposed performance standard must have been established in accordance with the relevant technical requirement.
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.
(c)	The proposed performance standards must be based on the automatic access standard or, if the procedures in clause 5.3.4A have been followed, the negotiated access standard.
(d)	The provision of connection by any Network Service Provider may be made subject to gaining environmental and planning approvals for any necessary augmentation or extension works to a network.
(e)	Where permitted by the applicable law in the relevant participating jurisdiction, the connection agreement may assign responsibility to the Connection Applicant for obtaining the approvals referred to in paragraph (d) as part of the project proposal and the Network Service Provider must provide all reasonable information and may provide reasonable assistance for a reasonable fee to enable preparation of applications for such approvals.
(f)	Subject to paragraph (e), each connection agreement must be based on the offer to connect as varied by agreement between the parties.
(f1)	The parties may agree to have one connection agreement between a Primary Transmission Network Service Provider, Dedicated Connection Asset Service Provider and a Transmission Network User for a connection.
(f2)	A network operating agreement must be based on the offer to connect as varied by agreement between the parties.
(g)	Within 20 business days of execution of the connection agreement, the Network Service Provider responsible for the connection point and the Registered Participant must jointly notify NTESMO that a connection agreement has been entered into between them and forward to NTESMO relevant technical details of the proposed plant and connection, including as applicable:
(1)	details of all performance standards that form part of the terms and conditions of the connection agreement;
(2)	if a Generator, the arrangements for:
(i)	updating the releasable user guide and other information required under clause S5.2.4(b); and
(ii)	informing NTESMO when the connection agreement expires or is terminated;
(3)	the proposed metering installation;
(4)	arrangements to obtain physical access to the metering installation for the Metering Provider and the Metering Data Provider for metering installations type 4A, 5 and 6;
(5)	the terms upon which a Registered Participant is to supply any ancillary services under the connection agreement; and
(6)	the details of any system strength remediation scheme agreed, determined or modified under clause 5.3.4B.
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.)
(h)	NTESMO must, within 20 business days of receipt of the notice under paragraph (g), advise the relevant Network Service Provider and the Registered Participant of whether the proposed metering installation is acceptable for those metering installations associated with those connection points which are classified as metering installation types 1, 2, 3 and 4 as specified in schedule 7A.4.
5.3.8	Provision and use of information
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.
(a)	The data and information provided under rules 5.2A, 5.3 and 5.3A is confidential information and must:
(1)	be prepared, given and used in good faith; and
(2)	not be disclosed or made available by the recipient to a third party except as set out in rule 3.7F, clause 3.13.3, this clause 5.3.8 or in accordance with rule 8.6.
(a1)	The data and information provided to a Primary Transmission Network Service Provider in relation to its provision of non-contestable services as specified under clause 5.2A.4(a) must not be used by the Primary Transmission Network Service Provider for the purpose of tendering for, or negotiating, contestable services specified under clause 5.2A.4(a) in the connection process in which the data or information was given, or in future connection processes, without the consent of the Connection Applicant.
(b)	The data and information to be provided under this rule 5.3 may be shared between a Network Service Provider and NTESMO for the purpose of enabling:
(1)	the Network Service Provider to advise NTESMO of ancillary services ; and
(2)	either party to:
(i)	assess the effect of a proposed facility or proposed alteration to generating plant (as the case may be) on:
(A)	the performance of the power system; or
(B)	another proposed facility or another proposed alteration;
(ii)	assess proposed negotiated access standards;
(iii)	determine the extent of any required augmentation or extension; or
(iv)	assess system strength remediation scheme proposals.
(c)	A Network Service Provider may disclose the data and information to be provided under rules 5.2A, 5.3 and 5.3A to another Network Service Provider if the Network Service Provider considers the information or data is materially relevant to that provider for connection.
(d)	A person intending to disclose information under paragraphs (b) or (c) must first advise the relevant Connection Applicant of the extent of the disclosure, unless the information may be disclosed in accordance with rule 8.6.
(d1)	If a Connection Applicant becomes aware of any material change to information contained in or relevant to a connection enquiry under rule 5.3 following receipt of the response from the Network Service Provider under clause 5.3.3, that Connection Applicant must promptly notify the Network Service Provider of that change.
(e)	If a Connection Applicant or Network Service Provider becomes aware of any material change to any information contained in or relevant to an application to connect, it must promptly notify the other party in writing of that change.
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.)
(f)	A Registered Participant must, within 5 business days of becoming aware that any information provided to NTESMO in relation to a performance standard or other information of a kind required to be provided to NTESMO under clause 5.3.7 is incorrect, advise NTESMO of the correct information.
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.)
5.3.9	Procedure to be followed by a Generator proposing to alter a generating system
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.
(a)	Subject to paragraph (a1), 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.
(a1)	This clause 5.3.9 does not apply in relation to any modifications made to a generating system by a Scheduled Generator or Semi-Scheduled Generator in order to comply with the Primary Frequency Response Requirements as applicable to that generating system.
(b)	A Generator to which this clause applies, must submit to the Network Service Provider with a copy to NTESMO:
(1)	a description of the nature of the alteration and the timetable for implementation;
(2)	in respect of the proposed alteration to the generating system, details of the generating unit design data and generating unit setting data;
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.)
(3)	in relation to each relevant technical requirement for which the proposed alteration to the equipment will affect the performance of the generating system, the proposed amendments to the plant's existing corresponding performance standard for that technical requirement; and
(4)	where relevant, the Generator's proposed system strength remediation scheme.
(c)	Clause 5.3.4A applies to a submission by a Generator under subparagraph (b)(3).
(c1)	Clause 5.3.4B applies to a submission by a Generator under subparagraph (b)(4). A Generator may request the Network Service Provider to undertake a preliminary assessment in accordance with the system strength impact assessment guidelines before making a submission under paragraph (b).
(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.
(e)	The Network Service Provider may as a condition of considering a submission made under paragraph (b), require payment of a fee to meet the reasonable costs anticipated to be incurred by the Network Service Provider, and other Network Service Providers, in the assessment of the submission.
(f)	The Network Service Provider must require payment of a fee under paragraph (e) if so requested by AEMO.
(g)	On payment of the required fee referred to in paragraph (e), the Network Service Provider must pay such amounts as are on account of the costs anticipated to be incurred by the other Network Service Providers and NTESMO, as appropriate.
(h)	If the application of this clause 5.3.9 leads to a variation to an existing connection agreement the Network Service Provider and the Generator must immediately jointly advise NTESMO, including the details of any performance standards amended pursuant to this clause 5.3.9.
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.)
5.3.10	Acceptance of performance standards for generating plant that is altered
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.
(a)	A person to whom clause 5.3.9 applies must not commission altered generating plant until the Network Service Provider has advised the Generator that it is satisfied in accordance with paragraph (b).
Note
This clause is classified as a civil penalty provision under the National Electricity (South Australia) Regulations. (See clause 6(1) and Schedule 1 of the National Electricity (South Australia) Regulations.)
(b)	In relation to altered generating plant, the Network Service Provider must be satisfied that:
(1)	the relevant person has complied with clause 5.3.9;
(2)	each amended performance standard that has been submitted to the Network Service Provider meets the relevant technical requirements under jurisdictional electricity legislation; and
(3)	any system strength remediation scheme satisfies clause 5.3.4B.
(c)	For the purposes of paragraph (a), NTESMO must advise the Network Service Provider as to whether it is satisfied with the matters referred to paragraph (b).
5.3.11	Notification of request to change normal voltage
(a)	On receipt of a request from a Network Service Provider to change normal voltage, NTESMO must publish a notice to Registered Participants advising:
(1)	the change in normal voltage requested; and
(2)	the connection point to which the request relates.
(a1)	A request from a Network Service Provider to change normal voltage must be assessed in accordance with the Rules consultation procedures.
(b)	Within a reasonable period after publication of the notice in paragraph (a), NTESMO must publish a further notice to Registered Participants advising:
(1)	whether the normal voltage at the relevant connection point will change; and
(2)	the nature of, and reasons for, any such change.
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.
5.3A	Establishing or modifying connection - embedded generation
5.3A.1	Application of rule 5.3A
(a)	For the purposes of this rule 5.3A:
non-registered embedded generator has the same meaning as in clause 5A.A.1
(b)	Where a Connection Applicant wishes to connect an embedded generating unit, this rule 5.3A applies.
(c)	For the purposes of this rule 5.3A and Schedules 5.4A and 5.4B:
(1)	a reference to a Connection Applicant is to a:
(i)	person who intends to be an Embedded Generator;
(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;
(iii)	non-registered embedded generator who has made an election under clause 5A.A.2(c); or
(iv)	non-registered embedded generator above the relevant materiality threshold for the local electricity system (or part of the local electricity system),
and who makes a connection enquiry under clause 5.3A.5 or an application to connect under clause 5.3A.9 in relation to any generating systems, or any network elements used in the provision of a network service, as the case may be.
(2)	the Distribution Network Service Provider is the Distribution Network Service Provider required under clause 5.3A.5 to process and respond to a connection enquiry or required under clause 5.3A.10 to prepare an offer to connect for the establishment or modification of a connection to the distribution network owned, controlled or operated by that Distribution Network Service Provider or for the provision of a network service.
5.3A.2	Definitions and miscellaneous
(a)	In this rule 5.3A and Schedules 5.4A and 5.4B:
detailed response means the response to a connection enquiry prepared under clause 5.3A.8.
establish a connection has the same meaning as in clause 5.3.1.
information pack means information relevant to the making of an application to connect specified in clause 5.3A.3(b).
preliminary response means the response to a connection enquiry prepared under clause 5.3A.7.
sub-transmission line has the same meaning as in clause 5.10.2.
zone substation has the same meaning as in clause 5.10.2.
(b)	To the extent a Distribution Network Service Provider has provided information required to be provided under this clause 5.3A by the inclusion of that information in:
(1)	its demand side engagement document under clause 5.13.1(g); or
(2)	a Distribution Annual Planning Report,
it will comply with the relevant information provision requirements of rule 5.3A by including hyperlinks to the relevant information in information provided to a Connection Applicant.
(c)	Where this rule 5.3A fixes a time limit for the provision of information or a response then, for the purposes of calculating elapsed time, the period that:
(1)	commences on the day when a dispute is initiated under clause 8.2.4(a); and
(2)	ends on the day on which the dispute is withdrawn or is resolved in accordance with clauses 8.2.6D or 8.2.9(a),
is to be disregarded.
5.3A.3	Publication of Information
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.
(a)	A Distribution Network Service Provider must publish the following in the same location on its website:
(1)	an enquiry form for connection of an embedded generating unit;
(2)	a register of completed embedded generation projects under rule 5.18B; and
(3)	an information pack.
(b)	An information pack must include:
(1)	a description of the process for lodging an application to connect for an embedded generating unit, including:
(i)	the purpose of each stage of the connection enquiry and application processes;
(ii)	the steps a Connection Applicant will need to follow at each stage of the connection enquiry and application processes;
(iii)	the information that is to be included by the Connection Applicant with a connection enquiry and the information that will be made available to the Connection Applicant by the Distribution Network Service Provider at each stage of the connection enquiry;
(iv)	the information that is to be included with an application to connect and the type of information that will be made available to the Connection Applicant by the Distribution Network Service Provider after lodgement of the application;
(v)	the factors taken into account by the Distribution Network Service Provider, at each stage of the connection enquiry and application, when assessing an application to connect for an embedded generating unit;
(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
(vii)	a list of services, if any, relevant to the connection that are contestable in the relevant participating jurisdiction;
(2)	single line diagrams of the Distribution Network Service Provider's preferred connection arrangements, and a range of other possible connection arrangements for integration of an embedded generating unit, showing the connection point, the point of common coupling, the embedded generating unit(s), load(s), meter(s), circuit breaker(s) and isolator(s);
(3)	a sample schematic diagram of the protection system and control system relevant to the connection of an embedded generating unit to the distribution network, showing the protection system and control system, including all relevant current circuits, relay potential circuits, alarm and monitoring circuits, back-up systems and parameters of protection and control system elements;
(4)	worked examples of connection service charges, enquiry and application fees for the connection of embedded generating units, based on the preferred and possible connection arrangements set out in paragraph (b)(2);
(5)	details of any minimum access standards or plant standards the Distribution Network Service Provider considers are applicable to embedded generating units and generating plant;
(6)	technical requirements relevant to the processing of a connection enquiry or an application to connect, including information of the type, but not limited to:
(i)	protection systems and protection schemes;
(ii)	fault level management principles;
(iii)	reactive power capability and power factor correction;
(iv)	power quality and how limits are allocated;
(v)	responses to frequency and voltage disturbances;
(vi)	voltage control and regulation;
(vii)	remote monitoring equipment, control and communication requirements;
(viii)	earthing requirements and other relevant safety requirements;
(ix)	circumstances in which augmentation may be required to facilitate integration of an embedded generating unit into the network;
(x)	commissioning and testing requirements;
(xi)	circumstances in which a system strength remediation scheme or system strength connection works will be required as a condition of connection; and
(xii)	other technical matters relevant to any access standard under jurisdictional electricity legislation; and
(7)	model connection agreements used by that Distribution Network Service Provider.
5.3A.4	Fees
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.
(a)	A Distribution Network Service Provider may charge a Connection Applicant an enquiry fee, the amount of which must not be more than necessary to cover the reasonable costs of work required to prepare a detailed response to the enquiry.
(b)	The Distribution Network Service Provider may specify that an enquiry fee is payable in components.
(c)	The enquiry fee, or such component of it identified by the Distribution Network Service Provider, is payable either:
(1)	on lodgement of the further information identified in S5.4A(o); or
(2)	on receipt of advice from the Distribution Network Service Provider provided pursuant to clause 5.3A.7(b).
(d)	A Distribution Network Service Provider must not charge a fee for the provision of a preliminary response.
(e)	A Distribution Network Service Provider may charge an application fee, payable on lodgement of an application to connect, provided that the fee must not:
(1)	include an amount for work that was completed in preparing the detailed response to the enquiry; and
(2)	be more than necessary to:
(i)	cover the costs of work and expenses reasonably incurred by the Distribution Network Service Provider in assessing the application to connect and making an offer to connect; and
(ii)	meet the reasonable costs anticipated to be incurred by AEMO and other Network Service Providers whose participation in the assessment of the application to connect will be required.
5.3A.5	Enquiry
(a)	A Connection Applicant who wishes to make an application to connect must first make a connection enquiry with the Local Network Service Provider.
(b)	Subject to paragraph (c), an enquiry must be in the form determined by the Local Network Service Provider.
(c)	An enquiry form under paragraph (b) must require the Connection Applicant to provide:
(1)	a qualitative description of the objectives of the project proposal the subject of the application to connect;
(1a)	the DER generation information that the Distribution Network Service Provider requires;
(2)	the information specified in Schedule 5.4; and
(3)	a list of the information required from the Local Network Service Provider in relation to its application to connect and supporting reasons for its requests.
(d)	A Local Network Service Provider must, within 5 business days after receiving an enquiry, provide written acknowledgment of receipt of the connection enquiry.
(e)	If the Local Network Service Provider considers that the connection enquiry should be jointly examined by more than one Distribution Network Service Provider, then, with the agreement of the Connection Applicant, one of those Distribution Network Service Providers may be allocated the task of liaising with the Connection Applicant and the other Distribution Network Service Providers to process and respond to the enquiry.
(f)	If the enquiry is incomplete in a material respect, or the Connection Applicant has lodged an enquiry other than in accordance with the form determined by a Local Network Service Provider, that Local Network Service Provider must, within 5 business days after receipt of the enquiry, advise the Connection Applicant of the deficiency, and may require the Connection Applicant to provide the necessary information.
(g)	A Connection Applicant may request in a connection enquiry made under paragraph (a), that the Local Network Service Provider provide only a detailed response under clause 5.3A.8(c) to its enquiry. The Local Network Service Provider must, within 5 business days after receipt of the enquiry and all such additional information (if any) requested under paragraph (f), advise the Connection Applicant if it agrees to the request.
5.3A.6	Response to Enquiry
(a)	In response to a connection enquiry, the Distribution Network Service Provider must provide:
(1)	subject to clause 5.3A.5(g) or receiving any further information requested under clause 5.3A.5(f), a preliminary response; and
(2)	subject to receiving the enquiry fee and the further information requested under clause 5.3A.8(b), if relevant, a detailed response.
(b)	In preparing either the detailed response or preliminary response, the Distribution Network Service Provider must liaise with other Network Service Providers with whom it has connection agreements, if the Distribution Network Service Provider believes, in its reasonable opinion, that compliance with the terms and conditions of those connection agreements will be affected. The Distribution Network Service Provider responding to the connection enquiry may include in its preliminary response or detailed response, the reasonable requirements of any such other Network Service Providers for information to be provided by the Connection Applicant.
5.3A.7	Preliminary Response to Enquiry
(a)	Unless agreed otherwise, a preliminary response must:
(1)	be provided within 15 business days of receipt of a connection enquiry and all such additional information (if any) requested under clause 5.3A.5(f); and
(2)	include the information specified in Schedule 5.4A.
(b)	If the Distribution Network Service Provider has agreed under clause 5.3A.5(g) to not provide a preliminary response, it must advise the Connection Applicant of the:
(1)	estimate of the enquiry fee payable by the Connection Applicant for the detailed response, including details of how components of the fee were calculated; and
(2)	the component of the estimate of the enquiry fee payable by the Connection Applicant to request the detailed response,
within 15 business days of receipt of a connection enquiry and all such additional information (if any) requested under clause 5.3A.5(f), unless agreed otherwise.
(c)	A Distribution Network Service Provider may seek an extension of a time period specified in paragraphs (a) or (b) by giving notice, in writing to the Connection Applicant, specifying the reasons required for the extension. The Connection Applicant may not unreasonably withhold consent to that extension.
(d)	Nothing in paragraph (a) or Schedule 5.4A is to be read or construed as requiring the Distribution Network Service Provider to undertake detailed design or to perform detailed technical studies or analysis to prepare a preliminary response.
5.3A.8	Detailed Response to Enquiry
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.
(a)	Subject to clause 5.3A.5(g), a Distribution Network Service Provider must within 5 business days after receiving the further information identified in clause S5.4A(o) provide written acknowledgment of receipt of it.
(b)	If the further information provided under paragraph (a) is incomplete in a material respect the Distribution Network Service Provider must within 10 business days after receipt of it, advise the Connection Applicant of the deficiency and what is required to address it.
(c)	Unless:
(1)	agreed otherwise; or
(2)	the proposed connection requires the application of the regulatory investment test for distribution,
the Distribution Network Service Provider must provide a detailed response within 30 business days of the date specified under paragraph (d).
(d)	For the purposes of paragraph (c), the relevant date is the date on which the Distribution Network Service Provider has received all of the following:
(1)	the enquiry fee, or any component of the enquiry fee requested by the Distribution Network Service Provider;
(2)	if the Connection Applicant was required to remedy a deficiency in further information provided under paragraph (b), that further information; and
(3)	if the Connection Applicant was required under clause S5.4A(o) to provide further information, that information.
(e)	A Distribution Network Service Provider may seek an extension of the time period specified in paragraph (c) by giving notice, in writing to the Connection Applicant, specifying the reasons required for the extension. The Connection Applicant may not unreasonably withhold consent to that extension.
(f)	Where the proposed connection requires the application of the regulatory investment test for distribution, the Distribution Network Service Provider and the Connection Applicant are to agree a timeframe for the provision of a detailed response, taking into account the status of the relevant RIT-D project (as defined in clause 5.10.2).
(g)	A detailed response must include the information specified in:
(1)	paragraphs (f), (g) and (m) of Schedule 5.4B;
(2)	paragraphs (a) - (e1), (h) - (l) and (n)-(o) of Schedule 5.4B.
Note
Clause 5.3A.8(g) requires that a detailed response include all information specified in Schedule 5.4B. The above division may be of relevance for enforcement purposes only.
(h)	A Connection Applicant that is a Registered Participant, AEMO or an interested party may make a request in relation to technical requirements for access to the Reliability Panel in accordance with clause 5.3.3(b2)-(b4).
5.3A.9	Application for connection
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.
(a)	Following receipt of a detailed response under clause 5.3A.8, a Connection Applicant may make an application to connect in accordance with this clause 5.3A.9, and clause 5.3.4A.
(b)	To be eligible for connection, the Connection Applicant must submit an application to connect containing the information specified in the detailed response provided under clause 5.3A.8(c) and the application fee specified under clause S5.4B(m) to the Distribution Network Service Provider.
(c)	The Connection Applicant may submit an application to connect to more than one Distribution Network Service Provider in order to receive additional offers to connect in respect of facilities to be provided that are contestable.
(d)	If the application to connect is incomplete in a material respect the Distribution Network Service Provider must, within 10 business days after receipt of it, advise the Connection Applicant of the deficiency, and the steps required to address it.
(e)	To the extent that an application fee includes amounts to meet the reasonable costs anticipated to be incurred by any other Network Service Providers or AEMO in the assessment of the application to connect, a Distribution Network Service Provider who receives the application to connect and associated fee must pay such amounts to the other Network Service Providers or AEMO, as appropriate.
(f)	For each technical requirement where the proposed arrangement will not meet the automatic access standards nominated by the Distribution Network Service Provider pursuant to clause S5.4B(b), the Connection Applicant must submit with the application to connect a proposal for a negotiated access standard for each such requirement to be determined in accordance with clause 5.3.4A.
(g)	The Connection Applicant may:
(1)	lodge separate applications to connect and separately liaise with the other Network Service Providers identified in clause 5.3A.5(e) who may require a form of agreement; or
(2)	lodge one application to connect with the Distribution Network Service Provider who processed the connection enquiry and require it to liaise with those other Network Service Providers and obtain and present all necessary draft agreements to the Connection Applicant.
(h)	A Connection Applicant who proposes a system strength remediation scheme under clause 5.3.4B must submit its proposal with the application to connect.
5.3A.10	Preparation of offer to connect
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.
(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.
(b)	So as to maintain levels of service and quality of supply to existing Registered Participants in accordance with the Rules, the Distribution Network Service Provider in preparing the offer to connect must consult with NTESMO and other Registered Participants with whom it has connection agreements, if the Distribution Network Service Provider believes in its reasonable opinion, that compliance with the terms and conditions of those connection agreements will be affected, in order to assess the application to connect and determine:
(1)	the technical requirements for the equipment to be connected;
(2)	the extent and cost of augmentations and changes to all affected networks;
(3)	any consequent change in network service charges; and
(4)	any possible material effect of this new connection on the network power transfer capability including that of other networks.
(c)	If the application to connect involves the connection of embedded generating units having a nameplate rating of 10 MW or greater, the Distribution Network Service Provider must consult the relevant Transmission Network Service Provider regarding the impact of the connection contemplated by the application to connect on fault levels, line reclosure protocols, and stability aspects.
(d)	The Transmission Network Service Provider consulted under paragraph (c) must determine the reasonable costs of addressing those matters for inclusion in the offer to connect and the Distribution Network Service Provider must make it a condition of the offer to connect that the Connection Applicant pay these costs.
(e)	The Distribution Network Service Provider preparing the offer to connect must include provision for payment of the reasonable costs associated with remote control equipment and remote monitoring equipment as required by NTESMO and it may be a condition of the offer to connect that the Connection Applicant pay these costs.
(f)	The Distribution Network Service Provider preparing the offer to connect must specify in reasonable detail any system strength connection works to be undertaken by the Distribution Network Service Provider.
5.3A.11	Technical Dispute
(a)	Rule 8.2 applies to any dispute between a Distribution Network Service Provider and a Connection Applicant as to the technical requirements to establish or modify a connection sought by a Connection Applicant in a connection enquiry made under clause 5.3A.5 or an application to connect under clause 5.3A.9.
5.3A.12	Network support payments and functions
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.
(a)	When negotiating the amount of a network support payment with an Embedded Generator, the Transmission Network Service Provider must take into account the:
(1)	nature of the network  support services being provided by the Embedded Generator; and
(2)	extent to which the Embedded Generator is being, or will be, compensated for providing those network  support services by receiving avoided Customer TUOS charges.
(b)	Where the relevant Transmission Network Service Provider or Distribution Network Service Provider decides to implement a generation option as an alternative to network augmentation, the Network Service Provider must:
(1)	register the generating unit with AEMO and specify that the generating unit may be periodically used to provide a network support function and will not be eligible to set spot prices when constrained on in accordance with clause 3.9.7; and
(2)	include the cost of this network support service in the calculation of transmission service and distribution service prices determined in accordance with Chapter 6 or Chapter 6A, as the case may be.
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.)
5.3AA	Access arrangements relating to Distribution Networks
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.
(a)	In this rule 5.3AA:
(1)	the Distribution Network Service Provider is the Distribution Network Service Provider required under clauses 5.3.3 or 5.3A.5 to process and respond to a connection enquiry or required under clauses 5.3.5 or 5.3A.10 to prepare an offer to connect for the establishment or modification of a connection to the distribution network owned, controlled or operated by that Distribution Network Service Provider or for the provision of network service; and
(2)	the references to a Connection Applicant are to an Embedded Generator or Market Network Service Provider who makes a connection enquiry under clauses 5.3.2 or 5.3A.5 or an application to connect under clauses 5.3.4 or 5.3A.10 in relation to any generating units or group of generating units, or any network elements used in the provision of network service, as the case may be.
(b)	If requested by a Connection Applicant, whether as part of a connection enquiry, application to connect or the subsequent negotiation of a connection agreement, the Distribution Network Service Provider must negotiate in good faith with the Connection Applicant to reach agreement in respect of the distribution network user access arrangements sought by the Connection Applicant.
(c)	As a basis for negotiations under paragraph (b):
(1)	the Connection Applicant must provide to the Distribution Network Service Provider such information as is reasonably requested relating to the expected operation of:
(i)	its generating units (in the case of an Embedded Generator); or
(ii)	its network elements used in the provision of network service (in the case of a Market Network Service Provider); and
(2)	the Distribution Network Service Provider must provide to the Connection Applicant such information as is reasonably requested to allow the Connection Applicant to fully assess the commercial significance of the distribution network user access arrangements sought by the Connection Applicant and offered by the Distribution Network Service Provider.
(d)	A Connection Applicant may seek distribution network user access arrangements at any level of power transfer capability between zero and:
(1)	in the case of an Embedded Generator, the maximum power input of the relevant generating units or group of generating units; and
(2)	in the case of a Market Network Service Provider, the power transfer capability of the relevant network elements.
(e)	The Distribution Network Service Provider must use reasonable endeavours to provide the distribution network user access arrangements being sought by the Connection Applicant subject to those arrangements being consistent with good electricity industry practice considering:
(1)	the distribution connection assets to be provided by the Distribution Network Service Provider or otherwise at the connection point; and
(2)	the potential augmentations or extensions required to be undertaken on all affected transmission networks or distribution networks to provide that level of power transfer capability over the period of the connection agreement taking into account the amount of power transfer capability provided to other Registered Participants under distribution network user access arrangements in respect of all affected distribution networks.
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.)
(f)	The Distribution Network Service Provider and the Connection Applicant must negotiate in good faith to reach agreement as appropriate on:
(1)	the connection service charge to be paid by the Connection Applicant in relation to distribution connection assets to be provided by the Distribution Network Service Provider;
(2)	in the case of a Market Network Service Provider, the service level standards to which the Market Network Service Provider requires the Distribution Network Service Provider to adhere in providing its services;
(3)	the use of system services charge to be paid:
(i)	by the Connection Applicant in relation to any augmentations or extensions required to be undertaken on all affected transmission networks and distribution networks; and
(ii)	where the Connection Applicant is a Market Network Service Provider, to the Market Network Service Provider in respect of any reduction in the long run marginal cost of augmenting the distribution network as a result of it being connected to the distribution network,
(negotiated use of system charges); and
(4)	the following amounts:
(i)	the amount to be paid by the Connection Applicant to the Distribution Network Service Provider in relation to the costs reasonably incurred by the Distribution Network Service Provider in providing distribution network user access;
(ii)	where the Connection Applicant is an Embedded Generator:
(A)	the compensation to be provided by the Distribution Network Service Provider to the Embedded Generator in the event that the generating units or group of generating units of the Embedded Generator are constrained off or constrained on during a trading interval; and
(B)	the compensation to be provided by the Embedded Generator to the Distribution Network Service Provider in the event that dispatch of the Embedded Generator's generating units or group of generating units causes another Generator's generating units or group of generating units to be constrained off or constrained on; and
(iii)	where the Connection Applicant is a Market Network Service Provider:
(A)	the compensation to be provided by the Distribution Network Service Provider to the Market Network Service Provider in the event that the distribution network user access is not provided; and
(B)	the compensation to be provided by the Market Network Service Provider to the Distribution Network Service Provider in the event that dispatch of the relevant market network service causes a Generator's generating units or group of generating units to be constrained off or constrained on during a trading interval or causes the dispatch of another market network service to be constrained.
(g)	The maximum negotiated use of system charges applied by a Distribution Network Service Provider must be in accordance with the applicable requirements of Chapter 6 and the Negotiated Distribution Service Criteria applicable to the Distribution Network Service Provider.
(h)	A Distribution Network Service Provider must pass through to a Connection Applicant the amount calculated in accordance with paragraph (i) for the locational component of prescribed TUOS services that would have been payable by the Distribution Network Service Provider to a Transmission Network Service Provider had the Connection Applicant not been connected to its distribution network.
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.)
(i)	To calculate the amount to be passed through to a Connection Applicant in accordance with paragraph (h), a Distribution Network Service Provider must, if prices for the locational component of prescribed TUOS services were in force at the relevant transmission network connection point throughout the relevant financial year:
(1)	determine the charges for the locational component of prescribed TUOS services that would have been payable by the Distribution Network Service Provider for the relevant financial year:
(i)	where the Connection Applicant is an Embedded Generator, if that Embedded Generator had not injected any energy at its connection point during that financial year;
(ii)	where the Connection Applicant is a Market Network Service Provider, if the Market Network Service Provider had not been connected to the Distribution Network Service Provider's distribution network during that financial year; and
(2)	determine the amount by which the charges calculated in subparagraph (1) exceed the amount for the locational component of prescribed TUOS services actually payable by the Distribution Network Service Provider, which amount will be the relevant amount for the purposes of paragraph (h).
(j)	Where prices for the locational component of prescribed TUOS services were not in force at the relevant distribution network connection point throughout the relevant financial year, as referred to in paragraph (i), the Distribution Network Service Provider must apply an equivalent procedure to that referred to in paragraph (i) in relation to that component of its transmission use of system service charges which is deemed by the relevant Transmission Network Service Provider to represent the marginal cost of transmission, less an allowance for locational signals present in the spot market, to determine the relevant amount for the purposes of paragraph (h).
5.3B	Application for connection to declared shared network
(a)	In relation to a declared transmission system, the powers, functions and responsibilities of the Network Service Provider are divided between AEMO and the declared transmission system operator as follows:
(1)	AEMO is the Network Service Provider in respect of the provision of shared transmission services; and
(2)	the relevant declared transmission system operator is the Network Service Provider in respect of the provision of connection services.
(b)	If:
(1)	a declared transmission system operator receives a connection inquiry or an application to connect to a declared shared network; and
(2)	the inquiry or application relates in whole or part to the provision of shared transmission services;
the declared transmission system operator must pass on to AEMO the information provided by the applicant in connection with the inquiry or application.
(c)	Clauses 5.3.1(e), 5.3.2(g), 5.3.3(b)(5A), (7) to (11), 5.3.3(c)(5)(ii), 5.3.4(b)(3) and (4), 5.3.4(b1), 5.3.4(f)(3), 5.3.6(b4) and (b5), 5.3.7(a2), 5.3.7(f1) and (f2) and 5.3.8(a2) do not apply in respect of a declared transmission system.
5.4	Independent Engineer
5.4.1	Application
(a)	This rule 5.4 does not apply to the declared transmission system of an adoptive jurisdiction.
(b)	This rule 5.4 applies only if a relevant Transmission Network Service Provider or a Connection Applicant requires independent advice in order to reach agreement on or resolve:
(1)	a technical issue in relation to negotiated transmission services related to a connection sought by the Connection Applicant;
(2)	whether assets or components form part of a dedicated connection asset or form part of an identified user shared asset;
(3)	whether or not a component of an identified user shared asset is a contestable IUSA component pursuant to clause 5.2A.4(c)(1) and (2); or
(4)	whether the detailed design of a contestable IUSA component is consistent with the functional specification for the relevant identified user shared asset,
("technical matter").
(c)	A technical matter does not include issues relating to:
(1)	the cost or commercial terms of;
(2)	the process relating to; or
(3)	the timing of,
the connection.
5.4.2	Establishment of a pool
(a)	The Adviser must establish and maintain a pool of persons (who may be individuals or firms) from whom the Independent Engineer may be selected in accordance with clauses 5.4.3(d)(2) or 5.4.4(a)(4).
(b)	In selecting persons for the pool, the Adviser must have regard to the need for the person to have sufficient experience and expertise in technical matters involved in connections to the transmission network.
(c)	The Adviser must review the composition of the pool at least every two years.
5.4.3	Initiating the Independent Engineer process
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.
(a)	If a technical matter arises that requires independent advice in order to reach an agreement or resolution, a Transmission Network Service Provider or a Connection Applicant may serve a notice on the other party that:
(1)	requires the parties to engage an Independent Engineer;
(2)	includes a statement setting out the technical matter; and
(3)	may request the receiving party to provide information about the technical matter.
(b)	If another Transmission Network Service Provider:
(1)	has the task of liaising with the Connection Applicant under clause 5.3.2(e); or
(2)	has been identified as a party with whom the Connection Applicant must enter into an agreement with under clause 5.3.3(b)(4),
and has an interest in the technical issue under clause 5.4.1(b)(1), that Transmission Network Service Provider must also be served with a copy of the notice under paragraph (a) and must participate in the Independent Engineer process.
(c)	If the technical matter involves a matter that relates to an AEMO advisory matter, then AEMO must also be served with a copy of the notice under paragraph (a) and may participate in the Independent Engineer process.
(d)	Within 10 business days of service of a notice under paragraph (a), a party may:
(1)	agree that the technical matter be resolved through an alternative means as agreed by the parties on the terms agreed between the parties; or
(2)	agree to appoint an Independent Engineer from the pool and the scope of work the Independent Engineer is to undertake.
(e)	If the parties appoint an Independent Engineer in accordance with subparagraph (d)(2), the parties are not required to notify the Adviser of the agreed selection in which case clauses 5.4.5 and 5.4.6 apply.
5.4.4	Referral to the Adviser
(a)	If the parties do not reach an agreement under clause 5.4.3(d) within 10 business days of service of a notice under clause 5.4.3(a), any party may refer the technical matter to the Adviser by serving on the Adviser a notice, which must:
(1)	be in a form approved and published by the Adviser;
(2)	contain the names of the parties who seek advice on the technical matter;
(3)	contain a statement setting out the technical matter;
(4)	if the parties have agreed on an Independent Engineer, the name of that Independent Engineer or in the absence of such agreement, contain a request for the Adviser to select an Independent Engineer;
(5)	contain the scope of advice required in respect of the technical matter, as agreed by the parties and in the absence of such agreement, request the Adviser to assist in determining the scope (which the Adviser may do in consultation with the parties and the Independent Engineer once appointed); and
(6)	specify a time frame by which the advice from the Independent Engineer is required so as to allow the Adviser to consider the availability of potential Independent Engineers.
(b)	If the Adviser is requested to select an Independent Engineer from the pool under clause 5.4.2, it must:
(1)	use reasonable endeavours to ensure the cost, availability, independence and expertise and experience of the selected Independent Engineer is appropriate to the technical matter;
(2)	consult with the parties prior to appointment, and
(3)	unless the parties otherwise agree, make the appointment within 15 business days of the notice under paragraph (a).
(c)	Despite the requirement to consult set out in subparagraph (b)(3), a selection of the Adviser is final and binding upon all parties.
5.4.5	Proceedings and decisions of the Independent Engineer
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.
(a)	The Independent Engineer may request documents and information from the parties that it reasonably considers is required to provide advice on the technical matter and a party must comply with such a request.
(b)	As a condition of providing documents and information, a party may require the Independent Engineer to agree to be bound to the confidentiality obligations under rule 8.6 as if the Independent Engineer was a Registered Participant.
(c)	The Independent Engineer must provide its written advice on a technical matter promptly, and in any case must do so within 30 business days after the Independent Engineer is appointed unless the parties otherwise agree.
(d)	The Transmission Network Service Provider may amend the time period referred to in any stage of the connection process under the preliminary program to allow for the additional time reasonably required for the Independent Engineer process under this rule 5.4.
(e)	The Independent Engineer must have regard to the following matters in forming their advice:
(1)	the technical requirements of the connection proposed by either of the parties;
(2)	the requirement under clause 5.3.4(b1)(2) that the technical requirements of the connection must not unreasonably inhibit the capacity for future expansion of an identified user shared asset or preclude the possibility of future connections;
(3)	the technical requirements of the connection should be consistent with good electricity industry practice and contribute to a safe, reliable and secure transmission system;
(4)	any submissions made by AEMO on an AEMO advisory matter; and
(5)	any relevant requirements and obligations under the applicable jurisdictional electricity legislation.
(f)	The Independent Engineer is not bound by the rules of evidence and may inform itself in any manner it thinks fit.
(g)	The Independent Engineer is a person who facilitates the resolution of disputes on technical matters, and is a protected person for the purposes of section 120B of the National Electricity Law in relation to the exercise of its powers and functions carried out under this clause 5.4.5.
(h)	The Independent Engineer's advice is not binding on the parties.
5.4.6	Costs of the Independent Engineer
The costs of any Independent Engineer, including any costs incurred by the Adviser in performing the functions of the Adviser in clause 5.4.4 are to be borne equally by the parties, unless otherwise agreed by the parties.
5.4A	[Deleted]
Note
In the transitional rules, rule 5.4A and its associated definitions will be preserved in relation to the declared transmission system of an adoptive jurisdiction.
5.4AA	[Deleted]
5.5	Commercial arbitration for prescribed and negotiated transmission services and large DCA services
5.5.1	Application
(a)	This rule 5.5 does not apply to the declared transmission system of an adoptive jurisdiction.
(b)	This rule 5.5 applies to any dispute which may arise between a Transmission Network Service Provider (including a Dedicated Connection Asset Service Provider for a large dedicated connection asset) (a provider) and a Connection Applicant or a person seeking large DCA services (an applicant) as to terms and conditions of access, for the provision of prescribed transmission services, the provision of negotiated transmission services (each a transmission services access dispute); or the provision of large DCA services (a large DCA services access dispute) (as applicable).
(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.
5.5.2	Notification of dispute
(a)	A provider or an applicant may notify the AER in writing that a transmission services access dispute or large DCA services access dispute exists.
(b)	On receiving a notification under paragraph (a), the AER must give notice in writing of the dispute to the other party to the dispute.
(c)	A provider or an applicant who has given notice of a dispute under paragraph (a) may withdraw notification of the dispute at any time by written notice to the AER and the other party to the dispute.
(d)	If the notification of a dispute is withdrawn under paragraph (c), it is taken for the purposes of this clause 5.5.2 to never have been given.
5.5.3	Appointment of commercial arbitrator
(a)	On receiving a notification under clause 5.5.2(a), the AER must request the provider and the applicant, by a time specified by the AER, to nominate to the AER two persons each for appointment as the commercial arbitrator to determine the transmission services access dispute or large DCA services access dispute. The provider and applicant may make the nominations.
(b)	As soon as practicable after the expiry of the time specified by the AER under paragraph (a), the AER must appoint:
(1)	one of the persons (if any) nominated to the AER by the provider or the applicant under paragraph (a); or
(2)	if neither the provider or the applicant nominate any such person within the time specified by the AER under paragraph (a) or all of the persons so nominated do not qualify for appointment under paragraph (d) or (e), a person determined by the AER,
as the commercial arbitrator to determine the dispute, and must refer the dispute to that commercial arbitrator.
(c)	A decision of the AER as to the appointment of the commercial arbitrator is final and binding on the provider and the applicant.
(d)	The AER may only appoint a person as the commercial arbitrator if that person is experienced or trained in dispute resolution techniques.
(e)	A person is not eligible for appointment as the commercial arbitrator if that person has any interest that may conflict with, or which may be seen to conflict with, the impartial resolution of the dispute. Where the person who is appointed as the commercial arbitrator becomes aware of such conflict after that person commences the hearing of the dispute, the person must advise the parties to that effect.
(f)	Where:
(1)	the provider or the applicant believes that the person appointed as the commercial arbitrator has an interest which may conflict with the impartial resolution of the dispute; or
(2)	the person appointed as the commercial arbitrator discloses the existence of such an interest,
the person must not continue to hear and determine the dispute, except with the written consent of the provider and the applicant.
5.5.4	Procedures of commercial arbitrator
(a)	The commercial arbitrator may give to the parties such directions as it considers necessary:
(1)	for the proper conduct of the proceedings, including in relation to the provision of documents and information to the other party and the making of oral and written submissions;
(2)	relating to the use and disclosure of information obtained from the other party to the dispute (including a direction to keep information confidential); and
(3)	in relation to the participation (if any) of legal representatives of the parties in the proceedings.
(b)	The commercial arbitrator must observe the rules of procedural fairness, but is not bound by the rules of evidence and may inform itself in any manner it thinks fit.
5.5.5	Powers of commercial arbitrator in determining disputes
(a)	In determining a transmission services access dispute in relation to the terms and conditions of access for the provision of prescribed transmission services the commercial arbitrator must apply:
(1)	in relation to price, the pricing methodology of the relevant Transmission Network Service Provider approved by the AER under Part E and Part J of Chapter 6A of the Rules;
(2)	in relation to other terms and conditions, Chapters 4, 5 and 6A of the Rules; and
(3)	in relation to all terms and conditions of access (including price) the decision of AEMO or the AER where those decisions relate to those terms and conditions and are made under Chapters 4, 5 and 6A of the Rules.
(b)	In determining a transmission services access dispute in relation to the terms and conditions of access for the provision of a negotiated transmission service the commercial arbitrator must apply:
(1)	in relation to price for the provision of that service by the provider, the negotiating principles that are applicable to that dispute;
(2)	in relation to other terms and conditions, the negotiating principles that are applicable to that dispute and Chapters 4 and 5 of the Rules;
(3)	in relation to all terms and conditions of access (including price) the decision of AEMO or the AER where those decisions relate to those terms and conditions and are made under Chapters 4 and 5 of the Rules.
(c)	In determining a large DCA services access dispute in relation to the terms and conditions of access for the provision of large DCA services, the commercial arbitrator must:
(1)	apply the access policy of the Dedicated Connection Asset Service Provider;
(2)	apply the relevant negotiating principles in schedule 5.12;
(3)	have regard to the legitimate business interests of the Dedicated Connection Asset Service Provider;
(4)	have regard to the interests of all persons who have rights to use the large DCA services; and
(5)	have regard to the operational and technical requirements necessary for the safe and reliable operation of the large dedicated connection asset and any facility connected to it.
(d)	In determining a transmission services access dispute in relation to the terms and conditions of access for the provision of negotiated transmission services a commercial arbitrator may:
(1)	have regard to other matters which the commercial arbitrator considers relevant.
(2)	hear evidence or receive submissions from AEMO and Transmission Network Users who may be adversely affected.
(e)	In determining a transmission services access dispute in relation to the terms and conditions of access for the provision of prescribed transmission services a commercial arbitrator may:
(1)	have regard to other matters which the commercial arbitrator considers relevant.
(2)	hear evidence or receive submissions from AEMO in relation to power system security matters and from Transmission Network Users who may be adversely affected.
5.5.6	Determination of disputes
(a)	Subject to paragraph (c), the commercial arbitrator must determine the dispute as quickly as possible, and in any case it must do so within 30 business days after the dispute is referred to the commercial arbitrator.
(b)	The determination of the commercial arbitrator:
(1)	may direct the provision of prescribed transmissions services and negotiated transmission services in accordance with Chapters 4, 5 and 6A of the Rules;
(2)	may specify, for a negotiated transmission service or a large DCA service, a price or charge in such a way that it is or is to be adjusted over time;
(3)	may direct the provision of large DCA services in accordance with the access policy of the Dedicated Connection Asset Service Provider; and
(4)	only where the dispute is a large DCA services access dispute, may require the enlargement or increase in capacity of, or alterations to, a large dedicated connection asset.
Note
An adjustment as referred to in subparagraph (2) may, for example, be appropriate where the cost of providing the negotiated transmission service to a Connection Applicant or person seeking large DCA services changes because the assets used to provide that service are subsequently used to provide a service to another person and the payment for the service by that other person enables the Transmission Network Service Provider or Dedicated Connection Asset Service Provider to recoup some of those costs from that other person.
(c)	The commercial arbitrator may extend the period referred to in paragraph (a) if the provider and the applicant so agree in writing.
(d)	The commercial arbitrator may at any time terminate the proceedings without making a decision if it considers that:
(1)	the dispute is misconceived or lacking in substance;
(2)	the notification of the dispute to the AER under clause 5.5.2(a) was vexatious; or
(3)	the party who notified the dispute to the AER under clause 5.5.2(a) has not negotiated in good faith or has notified the dispute prematurely or unreasonably.
(e)	The commercial arbitrator must terminate the proceedings without making a decision if at any time, whether on application by the provider or the applicant or otherwise, the arbitrator determines that the transmission service or large DCA service is capable of being provided on a genuinely competitive basis by a person other than the provider or an entity which is associated with the provider.
5.5.7	Costs of dispute
(a)	The fees and costs of the commercial arbitrator must be borne equally by the provider and the applicant unless:
(1)	paragraph (b) applies; or
(2)	otherwise agreed between the provider and the applicant.
(b)	The costs of determining the dispute (including the legal costs of either of the parties) may be allocated by the commercial arbitrator for payment as between the parties as part of any determination.
(c)	In deciding to allocate costs against one of the parties to the dispute, the commercial arbitrator may have regard to any relevant matters including (but not limited to) whether the conduct of that party unreasonably prolonged or escalated the dispute or otherwise increased the costs of resolving the dispute.
5.5.8	Enforcement of agreement or determination and requirement for reasons
(a)	Where the provider and the applicant reach agreement (whether or not the matter is before a commercial arbitrator), the parties may execute a written agreement recording their resolution of that dispute.
(b)	The commercial arbitrator must give its decision determining the dispute, together with its reasons for that decision, in writing and must provide a copy of its determination:
(1)	to the provider and to the applicant; and
(2)	(except to the extent that it contains confidential information) to the AER for publication.
(c)	An agreement that is executed under paragraph (a) and a determination of the commercial arbitrator under paragraph (b) are binding on the provider and the applicant, and any failure to comply with such an agreement or determination is a breach of the Rules in respect of which the AER may take action in accordance with the National Electricity Law.
5.5.9	Miscellaneous
(a)	To the extent permitted by law, a person who is appointed as a commercial arbitrator is not liable for any loss, damage or liability suffered or incurred by any person as a consequence of any act or omission of that person which was done in good faith in connection with the dispute
(b)	A person who is appointed as a commercial arbitrator may, before acting in relation to the dispute, require the parties to the dispute (and any one of them) to execute a release and indemnity in relation to any loss, damage or liability that that person would, but for the release or indemnity, suffer or incur as a consequence of any act or omission done in good faith in connection with the dispute.
5.5A 	 [Deleted]
Part C	Post-Connection Agreement matters
5.6	Design of Connected Equipment
5.6.1	Application
This rule 5.6 applies to new installations and modifications to existing installations that include alterations to existing generating plant, after:
(a)	13 December 1998, in the case of installations located in participating jurisdictions other than Tasmania and the Northern Territory;
(b)	29 May 2005, in the case of installations located in Tasmania; and
(c)	1 July 2019 in the case of installations located in the Northern Territory.
5.6.2	Advice of inconsistencies
(a)	At any stage prior to commissioning the facility in respect of a connection if there is an inconsistency between the proposed equipment and the connection agreement including the performance standards, the Registered Participant or the person intending to be registered as a Generator must:
(1)	advise the relevant Network Service Provider and, if the inconsistency relates to performance standards, NTESMO, in writing of the inconsistency; and
(2)	if necessary, negotiate in good faith with the Network Service Provider any necessary changes to the connection agreement.
Note
This clause is classified as a civil penalty provision under the National Electricity (South Australia) Regulations. (See clause 6(1) and Schedule 1 of the National Electricity (South Australia) Regulations.)
(b)	If an inconsistency in a connection agreement including a performance standard is identified under paragraph (a), the Registered Participant or the person intending to be registered as a Generator and the Network Service Provider must not commission the facility in respect of a connection unless the facility or the connection agreement or performance standard has been varied to remove the inconsistency.
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.)
(c) 	 [Deleted]
5.6.3	Additional information
A Registered Participant must provide any additional information in relation to its plant or associated equipment as the relevant Network Service Provider reasonably requests.
5.6.4	Advice on possible non-compliance
(a)	If the relevant Network Service Provider reasonably believes that the design of a proposed facility has potential to adversely and materially affect the performance of the power system, the Network Service Provider may require the Registered Participant to submit to it specified design information and drawings to enable the Network Service Provider to assess the performance of the facility in respect of its interaction with the power system:
(1)	after the Registered Participant has entered into an agreement for the supply of plant or associated equipment to be connected; and
(2)	when the relevant contractor's designs have progressed to a point where preliminary designs are available but prior to manufacture of equipment.
(b)	The Network Service Provider must, within 40 business days of receipt of such information, use its reasonable endeavours to advise the Registered Participant in writing of any design deficiencies which the Network Service Provider believes would cause the design to be inconsistent with the connection agreement or the Rules.
(c)	Notwithstanding paragraph (b), it is the Registered Participant's sole responsibility to ensure that all plant and equipment associated with the connection complies with the connection agreement and the Rules.
5.6A 	 [Deleted]
5.7	Inspection and Testing
5.7.1	Right of entry and inspection
(a)	If a Registered Participant who is party to a connection agreement reasonably believes that the other party to the connection agreement (being a party who is also a Registered Participant) is not complying with a technical provision of the Rules and that, as a consequence, the first Registered Participant is suffering, or is likely to suffer, a material adverse effect, then the first Registered Participant may enter the relevant facility at the connection point of the other Registered Participant in order to assess compliance by the other Registered Participant with its technical obligations under the Rules.
(b)	A Registered Participant who wishes to inspect the facilities of another Registered Participant under clause 5.7.1(a) must give that other Registered Participant at least 2 business days notice of its intention to carry out an inspection.
(c)	A notice given under clause 5.7.1(b) must include the following information:
(1)	the name of the representative who will be conducting the inspection on behalf of the Registered Participant;
(2)	the time when the inspection will commence and the expected time when the inspection will conclude; and
(3)	the nature of the suspected non-compliance with the Rules.
(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.
(e)	At any time when the representative of a Registered Participant is in another Registered Participant's facility, that representative must:
(1)	cause no damage to the facility;
(2)	only interfere with the operation of the facility to the extent reasonably necessary and approved by the relevant Registered Participant (such approval not to be unreasonably withheld or delayed); and
(3)	observe "permit to test" access to sites and clearance protocols of the operator of the facility, provided that these are not used by the operator of the facility solely to delay the granting of access to site and inspection.
(f)	Any representative of a Registered Participant conducting an inspection under this clause 5.7.1 must be appropriately qualified to perform the relevant inspection.
(g)	The costs of inspections under this clause 5.7.1 must be borne by the Registered Participant requesting the inspection.
(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.
(i)	Any inspection under clause 5.7.1(a) or (h) must only be for so long as is reasonably necessary.
(j)	Any equipment or goods installed or left on land or in premises of a Registered Participant after an inspection conducted under clause 5.7.1 do not become the property of the relevant Registered Participant (notwithstanding that they may be annexed or affixed to the relevant land or premises).
(k)	In respect of any equipment or goods left on land or premises of a Registered Participant during or after an inspection, a Registered Participant:
(1)	must not use any such equipment or goods for a purpose other than as contemplated in the Rules without the prior written approval of the owner of the equipment or goods;
(2)	must allow the owner of any such equipment or goods to remove any such equipment or goods in whole or in part at a time agreed with the relevant Registered Participant, such agreement not to be unreasonably withheld or delayed; and
(3)	must not create or cause to be created any mortgage, charge or lien over any such equipment or goods.
(l)	A Registered Participant (in the case of an inspection carried out under clause 5.7.1(a)) or NTESMO (in the case of an inspection carried out under clause 5.7.1(h)) must provide the results of that inspection to the Registered Participant whose facilities have been inspected, any other Registered Participant which is likely to be materially affected by the results of the test or inspection and NTESMO (in the case of an inspection carried out under clause 5.7.1(a)).
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.)
5.7.2	Right of testing
(a)	A Registered Participant, who has reasonable grounds to believe that equipment owned or operated by a Registered Participant with whom it has a connection agreement (which equipment is associated with the connection agreement) may not comply with the Rules or the connection agreement, may request testing of the relevant equipment by giving notice in writing to the other Registered Participant.
(b)	If a notice is given under clause 5.7.2(a) the relevant test is to be conducted at a time agreed by NTESMO.
(c)	The Registered Participant who receives a notice under clause 5.7.2(a) must co-operate in relation to conducting tests requested under clause 5.7.2(a).
(d)	The cost of tests requested under clause 5.7.2(a) must be borne by the Registered Participant requesting the test, unless the equipment is determined by the tests not to comply with the relevant connection agreement and the Rules, in which case all reasonable costs of such tests must be borne by the owner of that equipment.
(e)	Tests conducted in respect of a connection point under clause 5.7.2 must be conducted using test procedures agreed between the relevant Registered Participants, which agreement is not to be unreasonably withheld or delayed.
(f)	Tests under clause 5.7.2 must be conducted only by persons with the relevant skills and experience.
(g)	A Network Service Provider must give NTESMO adequate prior notice of intention to conduct a test in respect of a connection point to that Network Service Provider's network.
(h)	The Registered Participant who requests a test under this clause 5.7.2 may appoint a representative to witness a test and the relevant Registered Participant must permit a representative appointed under this clause 5.7.2(h) to be present while the test is being conducted.
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.)
(i)	A Registered Participant who conducts a test must submit a report to the Registered Participant who requested the relevant test, NTESMO and to any other Registered Participant which is likely to be materially affected by the results of the test, within a reasonable period after the completion of the test and the report is to outline relevant details of the tests conducted, including but not limited to the results of those tests.
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.)
(j)	A Network Service Provider may attach test equipment or monitoring equipment to plant owned by a Registered Participant or require a Registered Participant to attach such test equipment or monitoring equipment, subject to the provisions of clause 5.7.1 regarding entry and inspection.
(k)	In carrying out monitoring under clause 5.7.2(j) the Network Service Provider must not cause the performance of the monitored plant to be constrained in any way.
5.7.3	Tests to demonstrate compliance with connection requirements for generators
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.
(a)	Each Generator must, in accordance with the time frames specified by NTESMO, provide evidence to any relevant Network Service Provider with which that Generator has a connection agreement and to NTESMO, that its generating system complies with:
(1)	the applicable technical requirements under jurisdictional electricity legislation; and
(2)	the relevant connection agreement including the performance standards.
Note
This clause is classified as a civil penalty provision under the National Electricity (South Australia) Regulations. (See clause 6(1) and Schedule 1 of the National Electricity (South Australia) Regulations.)
Note
The requirements that will apply under jurisdictional electricity legislation for the purposes of paragraph (a)(1) will be requirements that correspond to the matters set out in clause S5.2.5 as applying in other participating jurisdictions.
(b) 	[Deleted]
(c)	If a test required by clause 5.7.3(a) demonstrates that a generating system is not complying with one or more technical requirements under jurisdictional electricity legislation or the relevant connection agreement or one or more of the performance standards then the Generator must:
(1)	promptly notify the relevant Network Service Provider and NTESMO of that fact; and
(2)	promptly notify the Network Service Provider and NTESMO of the remedial steps it proposes to take and the timetable for such remedial work; and
(3)	diligently undertake such remedial work and report at monthly intervals to the Network Service Provider on progress in implementing the remedial action; and
(4)	conduct further tests or monitoring on completion of the remedial work to confirm compliance with the relevant technical requirements or performance standards (as the case may be).
Note
This clause is classified as a civil penalty provision under the National Electricity (South Australia) Regulations. (See clause 6(1) and Schedule 1 of the National Electricity (South Australia) Regulations.)
Note
The requirements that will apply under jurisdictional electricity legislation for the purposes of paragraph (c) will be requirements that correspond to the matters set out in clause S5.2.5 as applying in other participating jurisdictions.
(d)	If NTESMO reasonably believes that a generating system is not complying with one or more applicable performance standards or one or more applicable technical requirements under jurisdictional electricity legislation or the relevant connection agreement, NTESMO may instruct the Generator to conduct tests within 25 business days to demonstrate that the relevant generating system complies with those performance standards or technical requirements.
Note
This clause is classified as a civil penalty provision under the National Electricity (South Australia) Regulations. (See clause 6(1) and Schedule 1 of the National Electricity (South Australia) Regulations.)
Note
The requirements that will apply under jurisdictional electricity legislation for the purposes of paragraph (d) will be requirements that correspond to the matters set out in clause S5.2.5 as applying in other participating jurisdictions.
(e)	If the tests undertaken in accordance with paragraph (d) provide evidence that the generating system continues to comply with those requirements NTESMO must reimburse the Generator for the reasonable expenses incurred as a direct result of conducting the tests.
(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.
(g)	Each Generator must maintain records for 7 years for each of its generating systems and power stations setting out details of the results of all technical performance and monitoring conducted under this clause 5.7.3 and make these records available to NTESMO on request.
5.7.3A	Tests to demonstrate compliance with system strength remediation schemes
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.
(a)	Each Registered Participant required under a connection agreement to implement a system strength remediation scheme by means of facilities owned, operated or controlled by the Registered Participant must at the request of AEMO or the relevant Network Service Provider made not more than once in a calendar year provide evidence that those facilities satisfy the requirements of the system strength remediation scheme set out in the connection agreement.
Note
This clause is classified as a civil penalty provision under the National Electricity (South Australia) Regulations. (See clause 6(1) and Schedule 1 of the National Electricity (South Australia) Regulations.)
(b)	If at any time the facilities do not satisfy the requirements of the system strength remediation scheme set out in the connection agreement, the Registered Participant must:
(1)	promptly notify the relevant Network Service Provider and AEMO of that fact;
(2)	promptly notify the Network Service Provider and AEMO of the remedial steps it proposes to take and the timetable for such remedial work;
(3)	diligently undertake such remedial work and report at monthly intervals to the Network Service Provider on progress in implementing the remedial action; and
(4)	conduct further tests or monitoring on completion of the remedial work to confirm compliance with the requirements of the system strength remediation scheme.
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.)
(c)	If AEMO reasonably believes the requirements of a system strength remediation scheme are not being complied with, AEMO may instruct the Registered Participant to conduct tests within 25 business days to demonstrate that the requirements are being met.
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.)
(d)	If the tests undertaken in accordance with paragraph (c) provide evidence that the requirements of a system strength remediation scheme are being complied with, AEMO must reimburse the Registered Participant for the reasonable expenses incurred as a direct result of conducting the tests.
(e)	If AEMO:
(1)	is satisfied that the requirements of a system strength remediation scheme are not being complied with; and
(2)	holds the reasonable opinion that the failure is impeding or will impede AEMO's ability to carry out its role in relation to power system security,
AEMO may direct the relevant Registered Participant to operate its facility at a particular output or power transfer capability or in a particular mode until the relevant Registered Participant submits evidence reasonably satisfactory to AEMO that the requirements of the system strength remediation scheme are being complied with.
(f)	Each Registered Participant referred to in paragraph (a) must maintain records for 7 years for each of its relevant facilities setting out details of the results of monitoring and testing conducted under this clause 5.7.3A and make these records available to AEMO on request.
5.7.4	Routine testing of protection equipment
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.
(a)	A Registered Participant must co-operate with any relevant Network Service Provider to test the operation of equipment forming part of a protection system relating to a connection point at which that Registered Participant is connected to a network and the Registered Participant must conduct these tests:
(1)	prior to the plant at the relevant connection point being placed in service; and
(2)	at intervals specified in the connection agreement or in accordance with an asset management plan agreed between the Network Service Provider and the Registered Participant.
(a1)	A Network Service Provider must institute and maintain a compliance program to ensure that its facilities of the following types, to the extent that the proper operation of a facility listed in this clause may affect power system security, operate reliably and in accordance with any performance requirements under jurisdictional electricity legislation:
(1)	protection systems;
(2)	control systems for maintaining or enhancing power system stability;
(3)	control systems for controlling voltage or reactive power; and
(4)	control systems for load shedding.
Note
This clause is classified as a civil penalty provision under the National Electricity (South Australia) Regulations. (See clause 6(1) and Schedule 1 of the National Electricity (South Australia) Regulations.)
Note
The requirements that will apply under jurisdictional electricity legislation for the purposes of paragraph (a1) will be requirements that correspond to the matters set out in Schedule 5.1 as applying in other participating jurisdictions.
(a2)	A compliance program under clause 5.7.4(a1) must:
(1)	include monitoring of the performance of the facilities;
(2)	to the extent reasonably necessary, include provision for periodic testing of the performance of those facilities upon which power system security depends;
(3)	provide reasonable assurance of ongoing compliance of the facilities with the relevant performance requirements under jurisdictional electricity legislation; and
(4)	be in accordance with good electricity industry practice.
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.
(a3)	A Network Service Provider must immediately notify NTESMO if it reasonably believes that a facility of a type listed in clause 5.7.4(a1) does not comply with, or is likely not to comply with, its performance requirements.
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.)
(a4)	A notice issued under clause 5.7.4(a3) must:
(1)	identify the facility and the requirement with which the facility does not comply;
(2)	give an explanation of the reason why the facility failed to comply with its performance requirement;
(3)	give the date and time when the facility failed to comply with its performance requirement;
(4)	give the date and time when the facility is expected to again comply with its performance requirement; and
(5)	describe the expected impact of the failure on the performance of the Network Service Provider's transmission system or distribution system.
(b)	Each Registered Participant must bear its own costs of conducting tests under this clause 5.7.4.
5.7.5	Testing by Registered Participants of their own plant requiring changes to normal operation
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.
(a)	A Registered Participant proposing to conduct a test on equipment related to a connection point, which requires a change to the normal operation of that equipment, must give notice in writing to the relevant Network Service Provider of at least 15 business days except:
(1)	in an emergency; or
(2)	where AEMO has notified the relevant Network Service Provider of the proposed date and time of a test of the Registered Participant's equipment to be conducted in accordance with the requirements of the SRAS Guideline, under an ancillary services agreement between AEMO and the Registered Participant.
Note
This clause is classified as a civil penalty provision under the National Electricity (South Australia) Regulations. (See clause 6(1) and Schedule 1 of the National Electricity (South Australia) Regulations.)
(b)	The notice to be provided under clause 5.7.5(a) must include:
(1)	the nature of the proposed test;
(2)	the estimated start and finish time for the proposed test;
(3)	the identity of the equipment to be tested;
(4)	the power system conditions required for the conduct of the proposed test;
(5)	details of any potential adverse consequences of the proposed test on the equipment to be tested;
(6)	details of any potential adverse consequences of the proposed test on the power system; and
(7)	the name of the person responsible for the co-ordination of the proposed test on behalf of the Registered Participant.
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.)
(c)	The Network Service Provider must review the proposed test described in a notice provided under clause 5.7.5(a) to determine whether the test:
(1)	could adversely affect the normal operation of the power system;
(2)	could cause a threat to power system security;
(3)	requires the power system to be operated in a particular way which differs from the way in which the power system is normally operated; or
(4)	could affect the normal metering of energy at a connection point.
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.)
(d)	If the Network Service Provider determines that the proposed test does fulfil one of the conditions specified in clause 5.7.5(c), then the Registered Participant and Network Service Provider must seek NTESMO's approval prior to undertaking the test, which approval must not be unreasonably withheld or delayed.
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.)
(e)	If, in NTESMO's reasonable opinion, a test could threaten public safety, damage or threaten to damage equipment or adversely affect the operation of the power system, NTESMO may direct that the proposed test procedure be modified or that the test not be conducted at the time proposed.
(f)	NTESMO must advise Network Service Providers of any test which may have a possible effect on normal metering of energy at a connection point.
(g)	NTESMO must advise any other Registered Participants who might be adversely affected by a proposed test and consider any reasonable requirements of those Registered Participants when approving the proposed test.
(h)	The Registered Participant who conducts a test under this clause 5.7.5 must ensure that the person responsible for the co-ordination of a test promptly advises NTESMO when the test is complete.
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.)
(i)	If NTESMO approves a proposed test, NTESMO must use its reasonable endeavours to ensure that power system conditions reasonably required for that test are provided as close as is reasonably practicable to the proposed start time of the test and continue for the proposed duration of the test.
(j)	Within a reasonable period after any such test has been conducted, the Registered Participant who has conducted a test under this clause 5.7.5 must provide the Network Service Provider with a report in relation to that test including test results where appropriate.
5.7.6	Tests of generating units requiring changes to normal operation
Note
The application of this clause will be revisited as part of the phased implementation of the Rules in this jurisdiction.
(a)	A Network Service Provider may, at intervals of not less than 12 months per generating system, require the testing by a Generator of any generating unit connected to the network of that provider in order to assess the performance of the relevant generating unit or generating system for the purposes of a connection agreement, and that provider is entitled to witness such tests.
(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.
(c)	Adequate notice of not less than 15 business days must be given by the Network Service Provider to the Generator before the proposed date of a test under paragraph (a).
(d)	The Network Service Provider must use its best endeavours to ensure that tests permitted under this clause 5.7.6 are conducted at a time which will minimise the departure from the commitment and dispatch that are due to take place as instructed or approved by NTESMO, at that time.
(e)	If not possible beforehand, a Generator must conduct a test under this clause 5.7.6 at the next scheduled outage of the relevant generating unit and in any event within 9 months of the request.
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.)
(f)	A Generator must provide any reasonable assistance requested by the Network Service Provider in relation to the conduct of tests.
(f1)	If requested by a Network Service Provider who required the test under clause 5.7.6(a), a Generator must provide to the Network Service Provider any relevant information relating to the plant which is the subject of a test carried out under this clause 5.7.6.
(g)	Tests conducted under this clause 5.7.6 must be conducted in accordance with test procedures agreed between the Network Service Provider and the relevant Generator and a Generator must not unreasonably withhold its agreement to test procedures proposed for this purpose by the Network Service Provider.
(h)	A Generator must provide the test records obtained from a test under paragraph (a) to the Network Service Provider.
(i)	The Generator, the Network Service Provider and NTESMO must each bear its own costs associated with tests conducted under this clause 5.7.6 and no compensation is to be payable for financial losses incurred as a result of these tests or associated activities.
5.7.7	Inter-network power system tests
(a)	For each kind of development or activity described in the first column of chart 1 below, the Proponent is as set out in the second column and the Relevant Transmission Network Service Provider (Relevant TNSP) is as set out in the third column, respectively, opposite the description of the development or activity.

Chart 1
No.	Kind of development or activity	Proponent 	Relevant TNSP 	
	column 1	column 2	column 3	
1.	A new transmission line between two networks, or within a transmission network, that is anticipated to have a material inter-network impact is commissioned.	Network Service Provider in respect of the new transmission line.	Proponent and the Transmission Network Service Provider in respect of any network to which the transmission line is connected.	
2.	An existing transmission line between two networks, or within a transmission network, that is anticipated to have a material inter-network impact is augmented or substantially modified.	Network Service Provider in respect of the augmentation or modification of the transmission line.	Proponent and the Transmission Network Service Provider in respect of any network to which the transmission line is connected.	
3.	A new generating unit or facility of a Customer or a network development is commissioned that is anticipated to have a material inter-network impact.	Generator in respect of the generating unit and associated connection assets.
Customer in respect of the facility and associated connection assets.
Network Service Provider in respect of the relevant network.	Transmission Network Service Provider in respect of any network to which the generating unit, facility or network development is connected and, if a network development, then also the Proponent.	
4.	Setting changes are made to any power system stabilisers as a result of a generating unit, facility of a Customer or network development being commissioned, modified or replaced.	Generator in respect of the generating unit.
Customer in respect of the facility.
Network Service Provider in respect of the relevant network.	Transmission Network Service Provider in respect of any transmission network to which the generating unit, facility or network development is connected.	
5.	Setting changes are made to any power system stabilisers as a result of a decision by AEMO, which are not covered by item 4 in this chart.	AEMO.	None.	
6.	AEMO determines that a test is required to verify the performance of the power system in light of the results of planning studies or simulations or one or more system incidents.	AEMO.	None.	

(b)	A Registered Participant, not being a Transmission Network Service Provider, determined in accordance with clause 5.7.7(a) to be a Proponent for a development or activity detailed in chart 1, may require the Relevant TNSP corresponding to that development or activity to undertake on their behalf their obligations as the Proponent and, where the Relevant TNSP receives a written request to undertake those obligations, the Relevant TNSP must do so.
(c)	Where, in this clause 5.7.7, there is a reference to a Proponent that reference includes a Relevant TNSP required in accordance with clause 5.7.7(b) to undertake the obligations of another Registered Participant.
(d)	If a Relevant TNSP is required by a Registered Participant in respect of a scheduled generating unit, a semi-scheduled generating unit, a scheduled load or a market network service, any of which have a nameplate rating in excess of 30 MW, to act as a Proponent in accordance with clause 5.7.7(b), that Relevant TNSP is entitled to recover all reasonable costs incurred from the Registered Participant that required the Relevant TNSP to act as the Proponent.
(e)	A Registered Participant wishing to undertake a development or conduct an activity listed in item 1, 2, 3 or 4 of chart 1 must notify AEMO not less than 80 business days before the transmission line, generating unit, facility or network development is planned to be commissioned, modified or replaced, giving details of the development or activity.
(f)	If AEMO receives a notice under clause 5.7.7(e), then it must provide a copy of the notice to each jurisdictional planning representative and consult with each jurisdictional planning representative about the potential impact of the development or activity.
(g)	AEMO or the Relevant TNSP for a development or activity may notify the Proponent of the development or activity that AEMO or the Relevant TNSP believes an inter-network test is required for that development or activity.
(h)	AEMO or the Relevant TNSP may only give a notice under clause 5.7.7(g) if:
(1)	AEMO or the Relevant TNSP considers that the development or activity may have a material impact on the magnitude of the power transfer capability of more than one transmission network and, in the circumstances, an inter-network test is required; or
(2)	an inter-network test is required having regard to guidelines published under clause 5.7.7(k) and the surrounding circumstances.
(i)	If the Relevant TNSP gives a notice under clause 5.7.7(g), then it must also promptly give a copy of the notice to AEMO.
(j)	A Registered Participant undertaking a development or activity listed in chart 1 must provide information reasonably requested by AEMO or the Relevant TNSP for making an assessment under this clause.
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.)
(k)	AEMO may develop, publish and amend from time to time, in accordance with the Rules consultation procedures, a set of guidelines to assist Registered Participants to determine when an inter-network test may be required.
(l)	AEMO and the Relevant TNSP must consider any relevant guidelines in determining whether an inter-network test is required.
(m)	If AEMO or the Relevant TNSP gives notice under clause 5.7.7(g), then the Proponent must, in consultation with AEMO, prepare a draft test program for the inter-network test and provide it to AEMO, each jurisdictional planning representative and the Relevant TNSP (if the Relevant TNSP gave the notice).
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.)
(n)	However, if AEMO determines that an inter-network test is required for a reason contemplated in item 5 or 6 of chart 1, then it must prepare a draft test program for the inter-network test in consultation with the jurisdictional planning representatives and provide that draft test program to each jurisdictional planning representative.
(o)	If a jurisdictional planning representative considers that any changes should be made to a draft test program, the jurisdictional planning representative must, within 10 business days after being provided with the draft test program, make a recommendation to AEMO that identifies the changes it proposes should be made to the draft test program.
(p)	AEMO must:
(1)	publish a copy of the draft test program and any relevant changes recommended by any jurisdictional planning representative and invite interested Registered Participants to make written submissions; and
(2)	only accept as valid submissions received not later than the closing date for submissions specified in the notice publishing the copy of the draft test program (not to be less than 14 days after the date of publication); and
(3)	provide the jurisdictional planning representatives with copies of all valid submissions and seek any further recommendations they may have.
(q)	AEMO must determine and publish in accordance with clause 3.13.13 the test program for an inter-network test after taking into account the recommendations of the jurisdictional planning representatives and any valid submissions received from Registered Participants.
(r)	In determining the test program, AEMO must so far as practicable have regard to the following principles:
(1)	power system security must be maintained in accordance with Chapter 4; and
(2)	the variation from the central dispatch outcomes that would otherwise occur if there were no inter-network test should be minimised; and
(3)	the duration of the tests should be as short as possible consistently with test requirements and power system security; and
(4)	the test facilitation costs to be borne by the Proponent under paragraph (aa) should be kept to the minimum consistent with this paragraph.
(s) 	 [Deleted]
(t)	An inter-regional test must not be conducted within 20 business days after AEMO publishes the test program for the inter-network test determined by AEMO under clause 5.7.7(r).
(u)	The Proponent in respect of an inter-network test must seek to enter into agreements with other Registered Participants to provide the test facilitation services identified in the test program in order to ensure that the power system conditions required by the test program are achieved.
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.)
(v)	If the Proponent approaches another Registered Participant seeking to enter into an agreement under clause 5.7.7(u) then the Proponent and the Registered Participant must negotiate in good faith concerning the provision of the relevant test facilitation service.
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.)
(w)	If:
(1)	a Proponent approaches another Registered Participant as described in clause 5.7.7(v); and
(2)	the Proponent and the other Registered Participant have not agreed the terms and conditions to be included in the agreement under which the Registered Participant will provide the test facilitation service requested within 15 business days of the approach,
then those terms and conditions must be determined in accordance with rule 8.2 and a dispute of this type is deemed to fall within clause 8.2.5(c)(2).
(x)	If the dispute concerns the price which the Proponent is to pay for a test facilitation service, then it must be resolved applying the following principles:
(1)	the other Registered Participant is entitled to recover the costs it incurs, and a reasonable rate of return on the capital it employs, in providing the test facilitation service, determined taking into account the additional costs associated with:
(i)	maintaining the equipment necessary to provide the test facilitation service;
(ii)	any labour required to operate and maintain the equipment used to provide the test facilitation service; and
(iii)	any materials consumed when the test facilitation service is utilised; and
(2)	the other Registered Participant is entitled to be compensated for any commercial opportunities foregone by providing the test facilitation service.
(y)	When the terms and conditions are determined in accordance with rule 8.2 under this clause 5.7.7, then the Proponent and the other Registered Participant must enter into an agreement setting out those terms and conditions.
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.)
(z)	If AEMO is not the Proponent in respect of an inter-network test, the Proponent must:
(1)	prior to the scheduled date of the inter-network test, confirm to AEMO that the test facilitation services identified in the test program will be available to be utilised, who will be providing them and the operational arrangements for utilising them;
(2)	provide sufficient information to enable AEMO to utilise the test facilitation services in conducting the inter-network test; and
(3)	respond promptly to any queries AEMO raises with the Proponent concerning the availability of the test facilitation services and AEMO's ability to utilise those services in conducting the inter-network tests.
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.)
(aa)	The Proponent in respect of an inter-network test must bear all of the following costs associated with that inter-network test:
(1)	any amounts payable under an agreement under which test facilitation services are provided;
(2)	the Proponent's own costs associated with the inter-network test and in negotiating and administering the agreements referred to in clause 5.7.7(u); and
(3)	if the Proponent is not AEMO and the amount of settlements residue on any directional interconnector for a trading interval during which there is an impact on central dispatch outcomes as a result of the inter-network test is negative, then the Proponent must enter into an agreement with AEMO to pay that amount to AEMO.
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.)
(ab)	If the Proponent is AEMO and the amount of settlements residue on any directional interconnector for a trading interval during which there is an impact on central dispatch outcomes as a result of the inter-network test is negative, then AEMO must adjust that residue to be zero and must recover the amount as provided for in clause 2.11.3(b)(2A).
(ac)	AEMO must establish operational conditions to achieve the particular power transfer levels for each stage of the inter-network test as contemplated by the test program:
(1)	utilizing where practicable and economic to do so the test facilitation services identified in the test program; and
(2)	otherwise, by applying to the minimum extent necessary to fulfil the test requirements, inter-network testing constraints.
(ad)	An inter-network test must be coordinated by an officer nominated by AEMO who has authority to stop the test or any part of it or vary the procedure within pre-approved guidelines determined by AEMO if that officer considers any of these actions to be reasonably necessary.
(ae)	Each Registered Participant must:
(1)	cooperate with AEMO in planning, preparing for and conducting inter-regional tests;
(2)	act in good faith in respect of, and not unreasonably delay, an inter-network test; and
(3)	comply with any instructions given to it by AEMO under clause 5.7.7(af).
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.)
(af)	AEMO may utilise test facilitation services under agreements entered into by the Proponent under this clause 5.7.7 during an inter-network test in order to achieve operational conditions on the power system which are reasonably required to achieve valid test results.
5.7.8	Contestable IUSA components
(a)	Before commissioning, the Primary Transmission Network Service Provider must ensure that contestable IUSA components are built to the standards specified in the functional specification provided under clause 5.3.3(b)(9) and the Connection Applicant for the identified user shared asset must provide access to the Primary Transmission Network Service Provider to make inspections, and agree to such tests, as is reasonably required for that purpose.
(b)	The Connection Applicant for the identified user shared asset must pay the reasonable costs of inspections and tests which are reasonably required by the Transmission Network Service Provider under paragraph (a).
5.8	Commissioning
5.8.1	Requirement to inspect and test equipment
(a)	A Registered Participant must ensure that any of its new or replacement equipment is inspected and tested to demonstrate that it complies with relevant Australian Standards, the Rules and any relevant connection agreement prior to or within an agreed time after being connected to a transmission network or distribution network, and the relevant Network Service Provider is entitled to witness such inspections and tests.
Note
This clause is classified as a civil penalty provision under the National Electricity (South Australia) Regulations. (See clause 6(1) and Schedule 1 of the National Electricity (South Australia) Regulations.)
(b)	The Registered Participant must produce test certificates on demand by the relevant Network Service Provider showing that the equipment has passed the tests and complies with the standards set out in clause 5.8.1(a) before connection to a network, or within an agreed time thereafter.
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.)
5.8.2	Co-ordination during commissioning
A Registered Participant seeking to connect to a network must co-operate with the relevant Network Service Provider(s) and NTESMO to develop procedures to ensure that the commissioning of the connection and connected facility is carried out in a manner that:
(a)	does not adversely affect other Registered Participants or affect power system security or quality of supply of the power system; and
(b)	minimises the threat of damage to any other Registered Participant's equipment.
5.8.3	Control and protection settings for equipment
Note
The application of this clause will be revisited as part of the phased implementation of the Rules in this jurisdiction.
(a)	Not less than 3 months prior to the proposed commencement of commissioning by a Registered Participant of any new or replacement equipment that could reasonably be expected to alter performance of the power system (other than replacement by identical equipment), the Registered Participant must submit to the relevant Network Service Provider sufficient design information including proposed parameter settings to allow critical assessment including analytical modelling of the effect of the new or replacement equipment on the performance of the power system.
Note
This clause is classified as a civil penalty provision under the National Electricity (South Australia) Regulations. (See clause 6(1) and Schedule 1 of the National Electricity (South Australia) Regulations.)
(b)	The Network Service Provider must:
(1)	consult with other Registered Participants and NTESMO as appropriate; and
(2)	within 20 business days of receipt of the design information under clause 5.8.3(a), notify the Registered Participant and NTESMO of any comments on the proposed parameter settings for the new or replacement equipment.
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.)
(c)	If the Network Service Provider's comments include alternative parameter settings for the new or replacement equipment, then the Registered Participant must notify the Network Service Provider that it either accepts or disagrees with the alternative parameter settings suggested by the Network Service Provider.
(d)	The Network Service Provider and the Registered Participant must negotiate parameter settings that are acceptable to them both and if there is any unresolved disagreement between them, the matter must be referred to NTESMO whose decision must be given within 20 business days of referral of the dispute and, once a decision is given, it is to be final.
(e)	The Registered Participant and the Network Service Provider must co-operate with each other to ensure that adequate grading of protection is achieved so that faults within the Registered Participant's facility are cleared without adverse effects on the power system.
5.8.4	Commissioning program
(a)	Prior to the proposed commencement of commissioning by a Registered Participant of any new or replacement equipment that could reasonably be expected to alter performance of the power system, the Registered Participant must advise the relevant Network Service Provider and NTESMO in writing of the commissioning program including test procedures and proposed test equipment to be used in the commissioning.
(b)	Notice under clause 5.8.4(a) must be given not less than 3 months prior to commencement of commissioning for a connection to a transmission network and not less than 1 month prior to commencement of commissioning for a connection to a distribution network.
(c)	The relevant Network Service Provider and NTESMO must, within 15 business days of receipt of such advice under clause 5.8.4(a), notify the Registered Participant either that they:
(1)	agree with the proposed commissioning program; or
(2)	require changes to it in the interest of maintaining power system security, safety or quality of supply.
(d)	If the relevant Network Service Provider or NTESMO require changes to the proposed commissioning program, then the parties must co-operate to reach agreement and finalise the commissioning program within a reasonable period.
(e)	A Registered Participant must not commence the commissioning until the commissioning program has been finalised and the relevant Network Service Provider and NTESMO must not unreasonably delay finalising a commissioning program.
5.8.5	Commissioning tests
(a)	The relevant Network Service Provider and/or NTESMO has the right to witness commissioning tests relating to new or replacement equipment that could reasonably be expected to alter performance of the power system or the accurate metering of energy.
(b)	The relevant Network Service Provider must, within a reasonable period of receiving advice of commissioning tests, notify the Registered Participant whose new or replacement equipment is to be tested under this clause 5.8.5 whether or not it:
(1)	wishes to witness the commissioning tests; and
(2)	agrees with the proposed commissioning times.
(c)	A Registered Participant whose new or replacement equipment is tested under this clause 5.8.5 must submit to the relevant Network Service Provider the commissioning test results demonstrating that a new or replacement item of equipment complies with the Rules or the relevant connection agreement or both to the satisfaction of the relevant Network Service Provider.
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.)
(d)	If the commissioning tests conducted in relation to a new or replacement item of equipment demonstrates non-compliance with one or more requirements of the Rules or the relevant connection agreement then the Registered Participant whose new or replacement equipment was tested under this clause 5.8.5 must promptly meet with the Network Service Provider to agree on a process aimed at achievement of compliance of the relevant item with the Rules.
(e)	On request by a Network Service Provider, NTESMO may direct that the commissioning and subsequent connection of the Registered Participant's equipment must not proceed if the relevant equipment does not comply with the requirements described in clause 5.8.1(a).
5.9	Disconnection and Reconnection
5.9.1	Voluntary disconnection
(a)	Unless agreed otherwise and specified in a connection agreement, a Registered Participant must give to the relevant Network Service Provider notice in writing of its intention to permanently disconnect a facility from a connection point.
Note
This clause is classified as a civil penalty provision under the National Electricity (South Australia) Regulations. (See clause 6(1) and Schedule 1 of the National Electricity (South Australia) Regulations.)
(b)	A Registered Participant is entitled, subject to the terms of the relevant connection agreement, to require voluntary permanent disconnection of its equipment from a network in which case appropriate operating procedures necessary to ensure that the disconnection will not threaten power system security must be implemented in accordance with clause 5.9.2.
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.)
(c)	The Registered Participant must pay all costs directly attributable to the voluntary disconnection and decommissioning.
5.9.2	Decommissioning procedures
(a)	In the event that a Registered Participant's facility is to be permanently disconnected from a network, whether in accordance with clause 5.9.1 or otherwise, the Network Service Provider and the Registered Participant must, prior to such disconnection occurring, follow agreed procedures for disconnection.
Note
This clause is classified as a civil penalty provision under the National Electricity (South Australia) Regulations. (See clause 6(1) and Schedule 1 of the National Electricity (South Australia) Regulations.)
(b)	The Network Service Provider must notify NTESMO and any Registered Participants with whom it has a connection agreement if it believes, in its reasonable opinion, the terms and conditions of such a connection agreement will be affected by procedures for disconnection or proposed procedures agreed with any other Registered Participant. The parties must negotiate any amendments to the procedures for disconnection or the connection agreement that may be required.
(c)	Any disconnection procedures agreed to or determined under clause 5.9.2(a) must be followed by all relevant Network Service Providers and Registered Participants.
5.9.3	Involuntary disconnection
(a)	NTESMO may direct a Network Service Provider to, or a Network Service Provider may (either on its own initiative or in accordance with a direction from NTESMO), disconnect a Registered Participant's facilities from a network, or a Registered Participant's market loads, in the following circumstances:
(1)	pursuant to a direction for a disconnection made by a court under:
(a)	section 62 or 63 of the National Electricity Law;
(b)	section 44AAG of the Competition and Consumer Act 2010 (Cth); or
(c)	section 44AAGA of the Competition and Consumer Act 2010 (Cth).
(2)	during an emergency in accordance with clause 5.9.5;
(3)	in accordance with the National Electricity Law; or
(4)	in accordance with the provisions of the Registered Participant's connection agreement.
(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.
(c)	A Network Service Provider that has received a direction from NTESMO under this clause 5.9.3 must comply with that direction promptly.
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.)
(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.
5.9.4	Direction to disconnect
(a)	Where a disconnection is made pursuant to clause 5.9.3(a)(1), neither NTESMO nor the relevant Network Service Provider is liable in any way for any loss or damage suffered or incurred by the Registered Participant by reason of the disconnection and neither NTESMO nor the relevant Network Service Provider is obliged for the duration of the disconnection to fulfil any agreement to convey electricity to or from the Registered Participant's facility.
(b)	A Registered Participant must not bring proceedings against NTESMO or a Network Service Provider to seek to recover any amount for any loss or damage described in clause 5.9.4(a).
(c)	Transmission service charges and distribution service charges must be paid by a Registered Participant whose facilities have been disconnected under clause 5.9.3 as if any disconnection had not occurred.
(d)	A Network Service Provider that has received a direction from NTESMO to disconnect a Registered Participant's facilities in the circumstances described in clause 5.9.3(a)(1) must comply with that direction promptly.
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.)
5.9.4A	Notification of disconnection
If the AER applies to a court for a direction, under section 62 or 63 of the National Electricity Law or pursuant to regulations made under section 44AAG of the Competition and Consumer Act 2010 (Cth), that a Registered Participant's market loads be disconnected, the AER must promptly notify NTESMO and the participating jurisdictions which the AER considers may be affected.
5.9.5	Disconnection during an emergency
(a)	Where NTESMO may direct a Network Service Provider to disconnect a Registered Participant's facilities during an emergency under the Rules or otherwise, then NTESMO may:
(1)	require the relevant Registered Participant to reduce the power transfer at the proposed point of disconnection to zero in an orderly manner and then direct a Network Service Provider to disconnect the Registered Participant's facility by automatic or manual means; or
(2)	direct a Network Service Provider to immediately disconnect the Registered Participant's facilities by automatic or manual means where, in NTESMO's reasonable opinion, it is not appropriate to follow the procedure set out in clause 5.9.5(a)(1) because action is urgently required as a result of a threat to safety of persons, hazard to equipment or a threat to power system security.
(b)	A Network Service Provider that has received a direction from NTESMO under this clause 5.9.5 must comply with that direction promptly.
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.)
5.9.6	Obligation to reconnect
(a)	Either NTESMO (by directing the Network Service Provider) or the relevant Network Service Provider (either on its own initiative or in accordance with a direction from NTESMO) must reconnect a Registered Participant's facilities to a transmission network or distribution network at a reasonable cost to the Registered Participant as soon as practicable if:
(1)	NTESMO is reasonably satisfied that there no longer exists an emergency due to which the Registered Participant's facilities were disconnected under clause 5.9.5;
(2)	NTESMO is reasonably satisfied that there no longer exists a reason for the disconnection under the National Electricity Law or the Registered Participant's connection agreement;
(3)	one of the following occurs:
(i)	a breach of the Rules giving rise to the disconnection has been remedied;
(ii)	where the breach is not capable of remedy, compensation has been agreed and paid by the Registered Participant to the affected parties or, failing agreement, the amount of compensation payable has been determined in accordance with the dispute resolution procedure in rule 8.2 and that amount has been paid;
(iii)	where the breach is not capable of remedy and the amount of compensation has not been agreed or determined, assurances for the payment of reasonable compensation have been given to the satisfaction of NTESMO, the Network Service Provider and the parties affected; or
(iv)	the Registered Participant has taken all necessary steps to prevent the re-occurrence of the breach and has delivered binding undertakings to NTESMO or the Network Service Provider that the breach will not re-occur.
(4)	NTESMO determines that the requirements under jurisdictional electricity legislation for reconnection following disconnection under an emergency frequency control arrangement are satisfied.
(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.
(c)	A Network Service Provider that has received a direction from NTESMO under this clause 5.9.6 must comply with that direction promptly.
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.)
Part D	Network Planning and Expansion
5.10	Network development generally
5.10.1	Content of Part D
(a)	Clause 5.10.2 sets out local definitions used in Part D.
(b)	Clause 5.11.1 sets out obligations regarding forecasts for connection points to the transmission network.
(c)	Clause 5.11.2 sets out the obligations of Network Service Providers relating to the identification of network limitations.
(d)	Rule 5.12 sets out planning and reporting obligations for Transmission Network Service Providers.
(e)	Rule 5.13 sets out planning and reporting obligations for Distribution Network Service Providers.
(e1)	Rule 5.13A sets out the obligations to provide distribution zone substation information.
(f)	Rule 5.14 sets out joint planning obligations of Network Service Providers.
(f1)	Rule 5.14B relates to guidelines for Transmission Annual Planning Reports.
(g)	Rule 5.15 relates to regulatory investment tests generally.
(g1)	Rule 5.15A relates to the regulatory investment test for transmission.
(h)	Rule 5.16 relates to the application of the regulatory investment test for transmission to RIT-T projects that are not actionable ISP projects.
(h1)	Rule 5.16A relates to the application of the regulatory investment test for transmission to actionable ISP projects.
(h2)	Rule 5.16B relates to disputes about the application of the regulatory investment test for transmission.
(i)	Rule 5.17 relates the regulatory investment test for distribution.
(j)	Rule 5.18 relates to the construction of funded augmentations.
(j1)	Rule 5.18A sets out the obligations of Transmission Network Service Providers in relation to a register of large generator connections.
(j2)	Rule 5.18B sets out obligations of Distribution Network Service Providers in relation to completed embedded generation projects.
(k)	Rule 5.19 relates to Scale Efficient Network Extensions.
(l)	Rule 5.20 relates to the NSCAS Report, Inertia Report and System Strength Report and associated methodologies.
(m)	Rule 5.20A relates to power system frequency management planning.
(m1)	Rule 5.20B sets out the process for identifying and providing the inertia requirements for inertia sub-networks.
(m2)	Rule 5.20C sets out the process for identifying and providing the system strength requirements for each region.
(n)	Rule 5.21 sets out AEMO's obligations to publish information and guidelines and provide advice regarding network development.
(o)	Rule 5.22 relates to the Integrated System Plan.
(p)	Rule 5.23 sets out dispute resolution procedures relating to the Integrated System Plan.
5.10.2	Definitions
In this Part D and schedules 5.8, 5.9 and 5.4A:
asset management means the development and implementation of plans and processes, encompassing management, financial, consumer, engineering, information technology and other business inputs to ensure assets achieve the expected level of performance and minimise costs to consumers over the expected life cycle of the assets.
consumer panel report has the meaning given in clause 5.22.7(a).
Cost Benefit Analysis Guidelines means the guidelines made by the AER under clause 5.22.5.
cost threshold  means a cost threshold specified in clause 5.15.3(b) or 5.15.3(d) (as relevant).
cost threshold determination means a final determination under clause 5.15.3(i).
cost threshold review means a review conducted under clause 5.15.3(e).
credible option has the meaning given to it in clause 5.15.2(a).
demand side engagement document means the document published by the Distribution Network Service Provider under clause 5.13.1(g).
demand side engagement register means a facility by which a person can register with a Distribution Network Service Provider their interest in being notified of developments relating to distribution network planning and expansion.
demand side engagement strategy means the strategy developed by a Distribution Network Service Provider under clause 5.13.1(e) and described in its demand side engagement document.
de-rate means, in respect of a Network Service Provider, a reduction in the network capability of a network element in the network of that Network Service Provider.
design fault level  means the maximum level of fault current that a facility can sustain while maintaining operation at an acceptable performance standard.
development path means a set of projects in an Integrated System Plan that together address power system needs.
dispute notice has the meaning given in clause 5.16B.5(c)(1) and 5.17.5(c)(1).
disputing party has the meaning given in clause 5.16B.5(c) and 5.17.5(c).
distribution asset  means the apparatus, equipment and plant, including distribution lines, substations and sub-transmission lines, of a distribution system.
draft project assessment report means the report prepared under clause 5.17.4(i).
final project assessment report  means the report prepared under clauses 5.17.4(o) or (p).
firm delivery capacity  means the maximum allowable output or load of a network or facility under single contingency conditions, including any short term overload capacity having regard to external factors, such as ambient temperature, that may affect the capacity of the network or facility.
Forecasting Best Practice Guidelines means the guidelines made by the AER under clause 4A.B.5.
forward planning period  means the period determined by the Distribution Network Service Provider under clause 5.13.1(a)(1).
future ISP project means a project:
(a)	that relates to a transmission asset or non-network option the purpose of which is to address an identified need specified in an Integrated System Plan and which forms part of an optimal development path; and
(b)	that is forecast in the Integrated System Plan that identifies the project, to be an actionable ISP project in the future.
IASR review report has the meaning given in clause 5.22.9(a).
Inputs, Assumptions and Scenario Report means the report published by AEMO under clause 5.22.8(a).
ISP candidate option means a credible option specified in an Integrated System Plan that the RIT-T proponent must consider as part of a regulatory investment test for transmission for an actionable ISP project.
ISP consumer panel has the meaning given in clause 5.22.7(a).
ISP development opportunity means a development identified in an Integrated System Plan that does not relate to a transmission asset or non-network option and may include distribution assets, generation, storage projects or demand side developments that are consistent with the efficient development of the power system.
ISP methodology means the methodology published by AEMO under clause 5.22.8(d).
ISP parameters means, for an ISP project:
(a)	the inputs, assumptions and scenarios set out in the most recent Inputs, Assumptions and Scenarios Report;
(b)	the other ISP projects associated with the optimal development path; and
(c)	any weightings specified as relevant to that project.
ISP project means an actionable ISP project, a future ISP project or an ISP development opportunity.
ISP review report has the meaning given in clause 5.22.13(a).
ISP timetable means the timetable published by AEMO under clause 5.22.4(a).
joint planning project means a project the purpose of which is to address a need identified under clause 5.14.1(d)(3) or clause 5.14.2(a) or clause 5.14.3(a).
load transfer capacity  means meeting the load requirements for a connection point by the reduction of load or group of loads at the connection point and increasing the load or group of loads at a different connection point.
non-network options report means the report prepared under clause 5.17.4(b).
non-network provider  means a person who provides non-network options.
normal cyclic rating  means the normal level of allowable load on a primary distribution feeder having regard to external factors, such as ambient temperature and wind speed, that may affect the capacity of the primary distribution feeder.
potential credible option means an option which a RIT-D proponent or RIT-T proponent (as the case may be) reasonably considers has the potential to be a credible option based on its initial assessment of the identified need.
potential transmission project means investment in a transmission asset of a Transmission Network Service Provider which:
(a)	is an augmentation; and
(b)	has an estimated capital cost in excess of $5 million (as varied in accordance with a cost threshold determination); and
(c)	the person who identifies the project considers is likely, if constructed, to relieve forecast constraints between regional reference nodes.
power system needs has the meaning given in clause 5.22.3(a).
preferred option  has the meaning given in clause 5.15A.1(c) and 5.17.1(b).
preparatory activities means activities required to design and to investigate the costs and benefits of actionable ISP projects and if applicable, future ISP projects including:
(a)	detailed engineering design;
(b)	route selection and easement assessment work;
(c)	cost estimation based on engineering design and route selection;
(d)	preliminary assessment of environmental and planning approvals; and
(e)	council and stakeholder engagement.
primary distribution feeder  means a distribution line connecting a sub-transmission asset to either other distribution lines that are not sub-transmission lines, or to distribution assets that are not sub-transmission assets.
project assessment conclusions report means the report prepared under clause 5.16.4(t), 5.16.4(u) or 5.16A.4(i) (as applicable).
project assessment draft report means the report prepared under clause 5.16.4(j) or 5.16A.4(c) (as applicable).
project specification consultation report means the report prepared under clause 5.16.4(b).
protected event EFCS investment means investment by a Transmission Network Service Provider or a Distribution Network Service Provider for the purposes of installing or modifying an emergency frequency control scheme applicable in respect of the Network Service Provider's transmission or distribution system in accordance with a protected event EFCS standard.
reconfiguration investment has the meaning given to it in clause 5.16.3(a)(5).
regulatory investment test for distribution application guidelines  means the guidelines developed and published by the AER in accordance with clause 5.17.2 as in force from time to time, and include amendments made in accordance with clause 5.17.2(e).
regulatory investment test for transmission application guidelines  means the guidelines developed and published by the AER in accordance with clause 5.16.2 as in force from time to time, and include amendments made in accordance with clause 5.16.2(e).
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.
RIT-D project means:
(a)	a project the purpose of which is to address an identified need identified by a Distribution Network Service Provider; or
(b)	a joint planning project that is not a RIT-T project.
RIT-D proponent means the Network Service Provider applying the regulatory investment test for distribution to a RIT-D project to address an identified need. The RIT-D proponent may be:
(a)	if the identified need is identified during joint planning under clause 5.14.1(d)(3), a Distribution Network Service Provider or a Transmission Network Service Provider; or
(b)	in any other case, a Distribution Network Service Provider.
RIT-T project means:
(a)	a project the purpose of which is to address an identified need identified by a Transmission Network Service Provider; or
(b)	a joint planning project if:
(1)	at least one potential credible option to address the identified need includes investment in a network or non-network option on a transmission network (other than dual function assets) with an estimated capital cost greater than the cost threshold that applies under clause 5.16.3(a)(2); or
(2)	the Network Service Providers affected by the joint planning project have agreed that the regulatory investment test for transmission should be applied to the project; or
(c)	an actionable ISP project.
RIT-T proponent means the Network Service Provider applying the regulatory investment test for transmission to a RIT-T project to address an identified need. The RIT-T proponent may be:
(a)	if the identified need is identified during joint planning under clause 5.14.1(d)(3), a Distribution Network Service Provider or a Transmission Network Service Provider; or
(b)	in any other case (including under clause 5.14.3(a)), a Transmission Network Service Provider.
sub-transmission means any part of thepower system which operates to deliver electricity from the transmission system to the distribution network and which may form part of the distribution network, including zone substations.
sub-transmission line  means a power line connecting a sub-transmission asset to either the transmission system or another sub-transmission asset.
system limitation means a limitation identified by a Distribution Network Service Provider under clause 5.13.1(d)(2).
system limitation template means a template developed and published by the AER under clause 5.13.3(a).
TAPR Guidelines means the guidelines published by the AER under clause 5.14B.1.
total capacity means the theoretical maximum allowable output or load of a network or facility with all network components and equipment intact.
transmission asset means the apparatus, equipment and plant, including transmission lines and substations of a transmission system.
transmission-distribution connection point means:
(a)	subject to paragraph (b), the agreed point of supply established between a transmission network and a distribution network;
(b)	in relation to the declared transmission system of an adoptive jurisdiction, the agreed point of supply between the transmission assets of the declared transmission system operator and a distribution network.
zone substation means a substation for the purpose of connecting a distribution network to a sub-transmission network.
5.10.3	Interpretation
The terms Network Service Provider, Transmission Network Service Provider and Distribution Network Service Provider when used in rules 5.11 to 5.17 and schedules 5.8 and 5.9 are not intended to refer to, and are not to be read or construed as referring to, any Network Service Provider in its capacity as a Market Network Service Provider.
5.11	Forecasts of connection to transmission network and identification of system limitations
5.11.1	Forecasts for connection to transmission network
(a)	The relevant Network Service Provider must give at least 40 business days written notice to each relevant Registered Participant of the annual date by which the Registered Participant must provide the relevant Network Service Provider with the short and long term electricity generation, market network service and load forecast information listed in schedule 5.7 in relation to each connection point which connects the Registered Participant to a transmission network of that Network Service Provider and any other relevant information as reasonably required by the Network Service Provider.
(b)	Details of planned future generating units, market network services and loads, being details regarding the proposed commencing date, active power capability and reactive power capability, power transfer capability, operating times/seasons and special operating requirements, must be given by each relevant Registered Participant to the relevant Network Service Provider on reasonable request.
(c)	Each relevant Registered Participant must use reasonable endeavours to provide accurate information under paragraph (a) which must include details of any factors which may impact on load forecasts or proposed facilities for generation or market network services.
(d)	If the Network Service Provider reasonably believes any forecast information to be inaccurate, the Network Service Provider may modify that forecast information and must advise the relevant Registered Participant and NTESMO in writing of this action and the reason for the modification. The Network Service Provider is not responsible for any adverse consequences of this action or for failing to modify forecast information under this paragraph (d).
5.11.2	Identification of network limitations
Note
The application of paragraph (b) of this clause will be revisited as part of the phased implementation of the Rules in this jurisdiction.
Each Network Service Provider must:
(a)	extrapolate the forecasts provided to it by Registered Participants for the purpose of planning;
(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.
(c)	notify any affected Registered Participants and NTESMO of the expected time for undertaking proposed corrective action which may consist of:
(1)	dual function assets or an investment in a transmission network designed to address limitations in respect of a distribution network notified under paragraph (b); and
(2)	network options or non-network options or modifications to connection facilities, designed to address the limitations notified under paragraph (b).
5.12	Transmission annual planning process
5.12.1	Transmission annual planning review
(a)	Each Transmission Network Service Provider must analyse the expected future operation of its transmission networks over an appropriate planning period, taking into account the relevant forecast loads, any future generation, market network service, demand side and transmission developments and any other relevant data.
(b)	Each Transmission Network Service Provider must conduct an annual planning review which must:
(1)	incorporate the forecast loads as submitted or modified in accordance with clause 5.11.1; and
(2)	include a review of the adequacy of existing connection points and relevant parts of the transmission system and planning proposals for future connection points; and
(3)	
(4)	consider the potential for augmentations, or non-network alternatives to augmentations, that are likely to provide a net economic benefit to all those who produce, consume and transport electricity in the market;
(5)	consider the condition of network assets; and
(6)	consider the potential for replacements of network assets, or non-network options to replacements of network assets, that are likely to provide a net economic benefit to all those who produce, consume and transport electricity in the market.
(c)	The minimum planning period for the purposes of the annual planning review is 10 years for transmission networks.
5.12.2	Transmission Annual Planning Report
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.
(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.
(c)	The Transmission Annual Planning Report must be consistent with the TAPR Guidelines and set out:
(1)	the forecast loads submitted by a Distribution Network Service Provider in accordance with clause 5.11.1 or as modified in accordance with clause 5.11.1(d), including at least:
(i)	a description of the forecasting methodology, sources of input information, and the assumptions applied in respect of the forecast loads;
(ii)	a description of high, most likely and low growth scenarios in respect of the forecast loads;
(iii)	an analysis and explanation of any aspects of forecast loads provided in the Transmission Annual Planning Report that have changed significantly from forecasts provided in the Transmission Annual Planning Report from the previous year; and
(iv)	an analysis and explanation of any aspects of forecast loads provided in the Transmission Annual Planning Report from the previous year which are significantly different from the actual outcome;
(1A)	for all network asset retirements, and for all network asset de-ratings that would result in a network constraint, that are planned over the minimum planning period specified in clause 5.12.1(c), the following information in sufficient detail relative to the size or significance of the asset:
(i)	a description of the network asset, including location;
(ii)	the reasons, including methodologies and assumptions used by the Transmission Network Service Provider for deciding that it is necessary or prudent for the network asset to be retired or de-rated, taking into account factors such as the condition of the network asset;
(iii)	the date from which the Transmission Network Service Provider proposes that the network asset will be retired or de-rated; and
(iv)	if the date to retire or de-rate the network asset has changed since the previous Transmission Annual Planning Report, an explanation of why this has occurred;
(1B)	for the purposes of subparagraph (1A), where two or more network assets are:
(i)	of the same type;
(ii)	to be retired or de-rated across more than one location;
(iii)	to be retired or de-rated in the same calendar year; and
(iv)	each expected to have a replacement cost less than $200,000 (as varied by a cost threshold determination),
those assets can be reported together by setting out in the Transmission Annual Planning Report:
(v)	a description of the network assets, including a summarised description of their locations;
(vi)	the reasons, including methodologies and assumptions used by the Transmission Network Service Provider, for deciding that it is necessary or prudent for the network assets to be retired or de-rated, taking into account factors such as the condition of the network assets;
(vii)	the date from which the Transmission Network Service Provider proposes that the network assets will be retired or de-rated; and
(viii)	if the calendar year to retire or de-rate the network assets has changed since the previous Transmission Annual Planning Report, an explanation of why this has occurred;
(2)	planning proposals for future connection points;
(3)	a forecast of constraints and inability to meet the network performance requirements set out in schedule 5.1 or relevant legislation or regulations of a participating jurisdiction over 1, 3 and 5 years, including at least:
(i)	a description of the constraints and their causes;
(ii)	the timing and likelihood of the constraints;
(iii)	a brief discussion of the types of planned future projects that may address the constraints over the next 5 years, if such projects are required; and
(iv)	sufficient information to enable an understanding of the constraints and how such forecasts were developed;
(4)	in respect of information required by subparagraph (3), where an estimated reduction in forecast load would defer a forecast constraint for a period of 12 months, include:
(i)	the year and months in which a constraint is forecast to occur;
(ii)	the relevant connection points at which the estimated reduction in forecast load may occur;
(iii)	the estimated reduction in forecast load in MW needed; and
(iv)	a statement of whether the Transmission Network Service Provider plans to issue a request for proposals for augmentation, replacement of network assets, or a non-network option identified by the annual planning review conducted under clause 5.12.1(b) and if so, the expected date the request will be issued;
(5)	for all proposed augmentations to the network and proposed replacements of network assets the following information, in sufficient detail relative to the size or significance of the project and the proposed operational date of the project:
(i)	project/asset name and the month and year in which it is proposed that the asset will become operational;
(ii)	the reason for the actual or potential constraint, if any, or inability, if any, to meet the network performance requirements set out in schedule 5.1 or relevant legislation or regulations of a participating jurisdiction, including load forecasts and all assumptions used;
(iii)	the proposed solution to the constraint or inability to meet the network performance requirements identified in subparagraph (ii), if any;
(iv)	total cost of the proposed solution;
(v)	whether the proposed solution will have a material inter-network impact. In assessing whether an augmentation to the network will have a material inter-network impact a Transmission Network Service Provider must have regard to the objective set of criteria published by AEMO in accordance with clause 5.21 (if any such criteria have been published by AEMO); and
(vi)	other reasonable network options and non-network options considered to address the actual or potential constraint or inability to meet the network performance requirements identified in subparagraph (ii), if any. Other reasonable network and non-network options include, but are not limited to, interconnectors, generation options, demand side options, market network service options and options involving other transmission and distribution networks;
(6)	the manner in which the proposed augmentations and proposed replacements of network assets relate to the most recent Integrated System Plan;
(6A)	for proposed new or modified emergency frequency control schemes, the manner in which the project relates to the most recent power system frequency risk review;
(7)	information on the Transmission Network Service Provider's asset management approach, including:
(i)	a summary of any asset management strategy employed by the Transmission Network Service Provider;
(ii)	a summary of any issues that may impact on the system constraints identified in the Transmission Annual Planning Report that has been identified through carrying out asset management; and
(iii)	information about where further information on the asset management strategy and methodology adopted by the Transmission Network Service Provider may be obtained.
(8)	any information required to be included in a Transmission Annual Planning Report under:
(i)	clauses 5.16.3(c) and 5.16A.3 in relation to a network investment which is determined to be required to address an urgent and unforeseen network issue; or
(ii)	clauses 5.20B.4(h) and (i) and clauses 5.20C.3(f) and (g) in relation to network investment and other activities to provide inertia network services, inertia support activities or system strength services.
(9)	emergency controls in place underjurisdictional electricity legislation, including the Network Service Provider's assessment of the need for new or altered emergency controls under that clause;
(10)	facilities in place under jurisdictional electricity legislation;
(11)	an analysis and explanation of any other aspects of the Transmission Annual Planning Report that have changed significantly from the preceding year's Transmission Annual Planning Report, including the reasons why the changes have occurred; and
(12)	the results of joint planning (if any) undertaken with a Transmission Network Service Provider under clause 5.14.3 in the preceding year, including a summary of the process and methodology used by the Transmission Network Service Providers to undertake joint planning and the outcomes of that joint planning.
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.
(d)	A declared transmission system operator for all or part of the declared shared network must provide to AEMO within a reasonable period of receiving a request, such information as reasonably requested by AEMO to enable it to comply with:
(1)	clause 5.12.1(b)(5);
(2)	clause 5.12.1(b)(6);
(3)	clause 5.12.2(c)(1A);
(4)	clauses 5.12.2(c)(4), (5) and (6) as they relate to the proposed replacement of network assets; and
(5)	clause 5.12.2(c)(7).
5.13	Distribution annual planning process
5.13.1	Distribution annual planning review
Scope
(a)	A Distribution Network Service Provider must:
(1)	subject to paragraph (b), determine an appropriate forward planning period for its distribution assets; and
(2)	analyse the expected future operation of its network over the forward planning period in accordance with this clause 5.13.1.
(b)	The minimum forward planning period for the purposes of the distribution annual planning review is 5 years.
(c)	The distribution annual planning review must include all assets that would be expected to have a material impact on the Distribution Network Service Provider's network over the forward planning period.
Requirements
(d)	Each Distribution Network Service Provider must, in respect of its network:
(1)	prepare forecasts covering the forward planning period of maximum demands for:
(i)	sub-transmission lines;
(ii)	zone substations; and
(iii)	to the extent practicable, primary distribution feeders,
having regard to:
(iv)	the number of customer connections;
(v)	energy consumption; and
(vi)	estimated total output of known embedded generating units;
(2)	identify, based on the outcomes of the forecasts in subparagraph (1), limitations on its network, including limitations caused by one or more of the following factors:
(i)	forecast load exceeding total capacity;
(ii)	the requirement for asset refurbishment or replacement;
(iii)	the requirement for power system security or reliability improvement;
(iv)	design fault levels being exceeded;
(v)	the requirement for voltage regulation and other aspects of quality of supply to other Network Users; and
(vi)	the requirement to meet any regulatory obligation or requirement;
(3)	identify whether corrective action is required to address any system limitations identified in subparagraph (2) and, if so, identify whether the Distribution Network Service Provider is required to:
(i)	carry out the requirements of the regulatory investment test for distribution; and
(ii)	carry out demand side engagement obligations as required under paragraph (f); and
(4)	take into account any jurisdictional electricity legislation.
Demand side engagement obligations
(e)	Each Distribution Network Service Provider must develop a strategy for:
(1)	engaging with non-network providers; and
(2)	considering non-network options.
(f)	A Distribution Network Service Provider must engage with non-network providers and consider non-network options for addressing system limitations in accordance with its demand side engagement strategy.
(g)	A  Distribution Network Service Provider must document its demand side engagement strategy in a demand side engagement document which must be published by no later than 31 August 2020.
(h)	A Distribution Network Service Provider must include the information specified in schedule 5.9 in its demand side engagement document.
(i)	A Distribution Network Service Provider must review and publish a revised demand side engagement document at least once every three years.
(j)	A Distribution Network Service Provider  must establish and maintain a facility by which parties can register their interest in being notified of developments relating to distribution network planning and expansion. A Distribution Network Service Provider must have in place a facility under this paragraph (j) no later than the date of publication of the Distribution Network Service Provider's  demand side engagement document under paragraph (g).
5.13.2	Distribution Annual Planning Report
(a)	For the purposes of this clause 5.13.2:
DAPR date means for a Distribution Network Service Provider:
(1)	the date by which it is required to publish a Distribution Annual Planning Report under jurisdictional electricity legislation; or
(2)	if no such date is specified in jurisdictional electricity legislation, 31 December.
(b)	By the DAPR date each year, a Distribution Network Service Provider must publish the Distribution Annual Planning Report setting out the results of the distribution annual planning review for the forward planning period.
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.
(c)	A Distribution Network Service Provider must include the information specified in schedule 5.8 in its Distribution Annual Planning Report.
(d)	Despite paragraph (c), a Distribution Network Service Provider is not required to include in its Distribution Annual Planning Report information required in relation to transmission-distribution connection points if it is required to do so under jurisdictional electricity legislation.
(e)	As soon as practicable after it publishes a Distribution Annual Planning Report  under paragraph (b), a Distribution Network Service Provider must publish on its website the contact details for a suitably qualified staff member of the Distribution Network Service Provider to whom queries on the report may be directed.
5.13.3	Distribution system limitation template
(a)	The AER must develop and publish a system limitation template in accordance with paragraph (c) and having regard to paragraph (b). The system limitation template must be developed by the AER in consultation with Distribution Network Service Providers and any persons who have identified themselves to the AER as having an interest in the form or contents of the system limitation template.
(b)	The purpose of the system limitation template is to facilitate the publication by Distribution Network Service Providers of information on system limitations referred to in their Distribution Annual Planning Reports in a useable, consistent, accessible format to assist third parties to propose alternative options to address system limitations.
(c)	The system limitation template must:
(1)	provide a template for the reporting of the following information:
(i)	the name (or identifier) and location of substations, sub-transmission lines, zone substations and, where appropriate, primary feeders, where there is a system limitation or a projected system limitation during the forward planning period that has been identified in a Distribution Network Service Provider's Distribution Annual Planning Report;
(ii)	the estimated timing (months(s) and year) of the system limitation or projected system limitation identified in subparagraph (i);
(iii)	the Distribution Network Service Provider's proposed option to address the system limitation;
(iv)	the estimated capital or operating cost of the proposed option; and
(v)	the amount by which peak demand at the location of the system limitation or projected system limitation would need to be reduced in order to defer the proposed solution, and the dollar value to the Distribution Network Service Provider of each year of deferral; and
(2)	include a statement that any information provided using the system limitation template must be read in conjunction with the reporting Distribution Network Service Provider's Distribution Annual Planning Report.
(d)	At the same time as it publishes its Distribution Annual Planning Report each year, a Distribution Network Service Provider must publish a report which contains the information specified in paragraph (c) in the form required by the system limitation template.
(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.
5.13A	Distribution zone substation information
Definitions
(a)	In this rule:
annual zone substation report means a report containing historical zone substation information for a reporting year (other than a reporting year covered by the ten year zone substation report).
reporting year for a Distribution Network Service Provider means a period of one year that ends on the same date in each reporting year (e.g. a period of one year ending on 30 June).
ten year zone substation report means a report containing historical zone substation information that is available for the ten reporting years prior to 1 July 2019.
zone substation information means the information specified in paragraph (b).
Zone substation information
(b)	Zone substation information means the following information for each zone substation on the Distribution Network Service Provider's distribution network:
(1)	the name or other identifier for the zone substation that corresponds to that used by the Distribution Network Service Provider in the regional development plan referred to in clause S5.8(n);
(2)	if the Distribution Network Service Provider has determined under paragraph (g) that the load for the zone substation should not be disclosed, a statement to the effect that the information has not been provided for that zone substation for reasons of confidentiality;
(3)	each date and time interval for which load data is available for the zone substation;
(4)	for each date and time interval specified under subparagraph (b)(3), load (in kW or MW); and
(5)	any additional information relating to load at the zone substation that the Distribution Network Service Provider wishes to provide.
Note
The following are examples of additional information that may be provided by a Distribution Network Service Provider under clause 5.13A(b)(5):
(a)	apparent power measured in kVA or MVA;
(b)	reactive power measured in kVAr or MVAr; or
(c)	power factor.
(c)	The Distribution Network Service Provider's obligation to provide zone substation information under subparagraphs (b)(4) and (5) is to provide raw data. A Distribution Network Service Provider is not required to analyse, assess or validate the quality or accuracy of that data before it is provided to a person who requests it under this rule 5.13A.
Requests for zone substation information
(d)	A Distribution Network Service Provider must publish on its website:
(1)	information on how a person may request a ten year zone substation report and/or annual zone substation reports;
(2)	the electronic format (and any other format) in which the Distribution Network Service Provider can make zone substation information available;
(3)	the end date of the Distribution Network Service Provider's reporting year;
(4)	the start and end dates of the period to which the ten year zone substation report relates;
(5)	details of the annual zone substation reports that are available on request;
(6)	information on when the next annual zone substation report will be available on request; and
(7)	the amount of the fee payable to the Distribution Network Service Provider for provision of the ten year zone substation report and each annual zone substation report. Any fee specified must be no more than that required to meet the reasonable costs anticipated to be incurred by the Distribution Network Service Provider in providing the relevant zone substation reports.
(e)	Any person may request a Distribution Network Service Provider to provide zone substation information. A request for zone substation information must:
(1)	specify whether the person requires:
(i)	a ten year zone substation report; and/or
(ii)	one or more annual zone substation reports;
(2)	specify the format in which the person wishes to receive the reports under subparagraph (e)(1), which must be a format specified by the Distribution Network Service Provider under paragraph (d)(2);
(3)	include an acknowledgment that:
(i)	any zone substation information provided by the Distribution Network Service Provider under subparagraphs (b)(4) and (5) is raw data and the Distribution Network Service Provider has not analysed, assessed or validated the quality or accuracy of that data; and
(ii)	the Distribution Network Service Provider makes no warranty or guarantee as to the quality, accuracy or suitability for any particular purpose of the zone substation information;
(4)	be accompanied by any applicable fees specified on the Distribution Network Service Provider's website; and
(5)	otherwise be in the format reasonably required by the Distribution Network Service Provider and as specified on its website.
Obligations of Distribution Network Service Providers to provide zone substation information
(f)	If a Distribution Network Service Provider receives a request in accordance with paragraph (e) it:
(1)	must provide the report(s) requested as soon as practicable but, in any event, within 30 business days of the date of the request; and
(2)	must not require the person who requested the report(s) to meet any further conditions or make any further acknowledgments or undertakings to the Distribution Network Service Provider before providing the report(s).
(g)	A Distribution Network Service Provider is not required to provide information under subparagraphs (b)(3) and (4) for a zone substation if, in the reasonable opinion of the Distribution Network Service Provider, that information is confidential or commercially-sensitive to a third party.
5.14	Joint planning
5.14.1	Joint planning obligations of Transmission Network Service Providers and Distribution Network Service Providers
(a)	Subject to paragraphs (b) and (c):
(1)	each Distribution Network Service Provider must conduct joint planning with each Transmission Network Service Provider of the transmission networks to which the Distribution Network Service Provider's networks are connected; and
(2)	each Transmission Network Service Provider must conduct joint planning with each Distribution Network Service Provider of the distribution networks to which the Transmission Network Service Provider's networks are connected.
(b)	In the case of the declared shared network of an adoptive jurisdiction, the relevant declared transmission system operator, the relevant Distribution Network Service Provider, AEMO and any interested party that has informed AEMO of its interest in the relevant plans, shall conduct joint planning.
(c)	For the purposes of this clause 5.14.1, a Transmission Network Service Provider does not include a Network Service Provider that is a Transmission Network Service Provider only because it owns, controls or operates dual function assets or transmission assets that are regulated under Chapter 6.
(d)	The relevant Distribution Network Service Provider and Transmission Network Service Provider must:
(1)	assess the adequacy of existing transmission and distribution networks and the assets associated with transmission-distribution connection points over the next five years and to undertake joint planning of projects which relate to both networks (including, where relevant, dual function assets);
(2)	use best endeavours to work together to ensure efficient planning outcomes and to identify the most efficient options to address the needs identified in accordance with subparagraph (4);
(3)	identify any limitations or constraints:
(i)	that will affect both the Transmission Network Service Provider's and Distribution Network Service Provider's network; or
(ii)	which can only be addressed by corrective action that will require coordination by the Transmission Network Service Provider and the Distribution Network Service Provider; and
(4)	where the need for a joint planning project is identified under subparagraph (3):
(i)	jointly determine plans that can be considered by relevant Registered Participants, AEMO, interested parties, and parties registered on the demand side engagement register of each Distribution Network Service Provider involved in joint planning;
(ii)	determine whether the joint planning project is a RIT-T project or a RIT-D project; and
(iii)	may agree on a lead party to be responsible for carrying out the regulatory investment test for transmission or the regulatory investment test for distribution (as the case may be) in respect of the joint planning project.
(e)	If a Network Service Provider, as the lead party for one or more Network Service Providers, undertakes the regulatory investment test for transmission or the regulatory investment test for distribution (as the case may be) in respect of a joint planning project, the other Network Service Providers will be taken to have discharged their obligation to undertake the relevant test in respect of that project.
5.14.2	Joint planning obligations of Distribution Network Service Providers and Distribution Network Service Providers
(a)	Distribution Network Service Providers must undertake joint planning with other Distribution Network Service Providers where there is a requirement to consider the need for any augmentation or non-network options that affect more than one Distribution Network Service Provider's network.
(b)	Distribution Network Service Providers involved in joint planning may agree on a lead party to be responsible for carrying out the regulatory investment test for distribution in respect of the joint planning project.
(c)	If a Distribution Network Service Provider, as the lead party for one or more Distribution Network Service Providers, undertakes the regulatory investment test for distribution in respect of a joint planning project, the other Distribution Network Service Providers will be taken to have discharged their obligation to undertake the regulatory investment test for distribution in respect of that project.
5.14.3	Joint planning obligations of Transmission Network Service Providers
Transmission Network Service Providers must undertake joint planning if:
(a)	a possible credible option to address a constraint in a transmission network is an augmentation to the transmission network of another Transmission Network Service Provider; and
(b)	that constraint is not already being considered under other processes under the Rules.
5.14.4	Joint planning by Transmission Network Service Providers and AEMO
(a)	Transmission Network Service Providers and AEMO (the joint planning parties) must take reasonable steps to cooperate and consult with each other to enable preparation of a draft or final Integrated System Plan or an ISP update, including each joint planning party (as applicable):
(1)	providing, and consulting on, a Transmission Annual Planning Report prior to its publication;
(2)	providing, in accordance with the ISP timetable, the latest available information in relation to the development of a Transmission Annual Planning Report required for the purpose of preparing a draft or final Integrated System Plan or ISP update;
(3)	providing information in relation to non-network options for the purpose of preparing a draft or final Integrated System Plan or ISP update;
(4)	conducting a preliminary review of non-network options submitted to AEMO following a draft Integrated System Plan;
(5)	sharing a draft optimal development path to be included in the draft and final Integrated System Plan or an ISP update before its publication;
(6)	considering whether a credible option in a draft optimal development path is reliability corrective action; and
(7)	sharing information reasonably necessary to prepare a draft or final Integrated System Plan or an ISP update.
(b)	As soon as practicable after a Transmission Network Service Provider becomes aware of a material change to information provided under paragraph (a), that information must be updated.
(c)	AEMO must provide Transmission Network Service Providers with draft regional demand forecasts for the next summer period informed by the previous summer period as soon as practicable, and by no later than 30 June each year.
5.14A	Joint planning in relation to retirement or de-ratings of network assets forming part of the Declared Shared Network
(a)	In the case of a proposed retirement or de-rating of a network asset that forms part of the declared shared network of an adoptive jurisdiction, AEMO and the relevant declared transmission system operator must conduct joint planning in respect of that proposed retirement or de-rating if an identified need arises from that proposed retirement or de-rating.
(b)	In conducting joint planning under paragraph (a), AEMO and the declared transmission system operator must use best endeavours to work together to identify the most efficient options to address the relevant identified need.
5.14B	TAPR Guidelines
5.14B.1	Development of TAPR Guidelines
(a)	The AER must, in accordance with the transmission consultation procedures, make and publish TAPR Guidelines that set out the required format of Transmission Annual Planning Reports.
(b)	The AER must develop and publish the first TAPR Guidelines under the Rules by the date specified in the Rules and there must be TAPR Guidelines in force at all times after that date.
(c)	Subject to paragraph (d), the AER may, from time to time and in accordance with the transmission consultation procedures, amend or replace the TAPR Guidelines.
(d)	The AER may make administrative or minor amendments to the TAPR Guidelines without complying with the transmission consultation procedures.
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.
5.15	Regulatory investment tests generally
5.15.1	Interested parties
In clauses 5.16.4, 5.16A.4, rule 5.16B and clauses 5.17.4 and 5.17.5, interested party means a person including an end user or its representative who, in the AER's opinion, has the potential to suffer a material and adverse impact from the investment identified as the preferred option in the project assessment conclusions report or the final project assessment report (as the case may be).
5.15.2	Identification of a credible option
(a)	A credible option is an option (or group of options) that:
(1)	addresses the identified need;
(2)	is (or are) commercially and technically feasible; and
(3)	can be implemented in sufficient time to meet the identified need,
and is (or are) identified as a credible option in accordance with paragraphs (b) or (d) (as relevant).
(b)	Subject to paragraph (b1), in applying the regulatory investment test for transmission, the RIT-T proponent must consider, in relation to a RIT-T project other than those described in clauses 5.16.3(a)(1)-(8) or 5.16A.3(a), all options that could reasonably be classified as credible options taking into account:
(1)	energy source;
(2)	technology;
(3)	ownership;
(4)	the extent to which the credible option enables trading of electricity within a local electricity system;
(5)	whether it is a network option or a non-network option;
(6)	whether the credible option is intended to be regulated;
(7)	whether the credible option has a proponent; and
(8)	any other factor which the RIT-T proponent reasonably considers should be taken into account.
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.)
(b1)	Paragraph (b) only applies to the application of the regulatory investment test for transmission to a RIT-T project that is an actionable ISP project where a RIT-T proponent is considering new credible options under clause 5.15A.3(b)(7)(iii)(C).
(c)	In applying the regulatory investment test for distribution, the RIT-D proponent must consider, in relation to a RIT-D project other than those described in clauses 5.17.3(a)(1)-(7), all options that could reasonably be classified as credible options, without bias as to:
(1)	energy source;
(2)	technology;
(3)	ownership; and
(4)	whether it is a network option or a non-network option.
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.)
(d)	The absence of a proponent does not exclude an option from being considered a credible option.
5.15.3	Review of costs thresholds
Regulatory investment test for transmission thresholds
(a)	Every 3 years the AER must undertake a review of the changes in the input costs used to calculate the estimated capital costs in relation to transmission investment as referred to in paragraph (b), for the purposes of determining whether the cost thresholds specified in paragraph (b) need to be changed to maintain the appropriateness of the cost thresholds over time by adjusting those cost thresholds to reflect any increase or decrease in the input costs since:
(1)	July 2009 in respect of the first cost threshold review; and
(2)	the date of the previous review in respect of every subsequent cost threshold review.
Note
The cost thresholds are regularly reviewed by the AER under paragraph (b). The current thresholds are specified in the latest cost threshold determination available on the AER's website www.aer.gov.au.
(b)	For the purposes of paragraph (a), the cost thresholds for review are the following amounts:
(1) 	 [Deleted]
(1A)	of less than $200,000 referred to in clause 5.12.2(c)(1B)(iv);
(2)	of less than $5 million referred to in clause 5.16.3(a)(2);
(3) 	 [Deleted]
(4)	of less than $5 million referred to in clause 5.16.3(a)(5);
(5)	of less than $35 million referred to in clause 5.16.4(z1)(1) and clause 5.16A.4(m)(1); and
(6)	in excess of $5 million in relation to investment in transmission assets of the type referred to in the definition of potential transmission project in clause 5.10.2.
Regulatory investment test for distribution costs thresholds
(c)	Subject to paragraph (f)(2), every 3 years, and at the same time as it undertakes its review of the cost thresholds for regulatory investment test for transmission under paragraph (a), the AER must undertake a review of the changes in the input costs used to calculate the estimated capital costs in relation to:
(1)	projects subject to the regulatory investment test for distribution; and
(2)	the cost threshold for committed investments that are to address an urgent and unforeseen network need subject to the Distribution Annual Planning Report,
for the purposes of determining whether the costs thresholds specified in paragraph (d) need to be changed to maintain the appropriateness of the cost thresholds over time by adjusting those cost thresholds to reflect any increase or decrease in the input costs since:
(3)	1 January 2013 in respect of the first cost threshold review; and
(4)	the date of the previous review in respect of every subsequent cost threshold review.
(d)	For the purposes of paragraph (c), the cost thresholds for review are the following amounts:
(1)	$5 million referred to in clause 5.17.3(a)(2);
(2)	[Deleted];;
(3)	$10 million referred to in clause 5.17.4(n)(2);
(4)	$20 million referred to in clause 5.17.4(s);
(4A)	of less than $200,000 referred to in S5.8(b2)(4);
(5)	$2 million referred to in S5.8(g).
Note
The cost thresholds are regularly reviewed by the AER under paragraph (b). The current thresholds are specified in the latest cost threshold determination available on the AER's website www.aer.gov.au.
Cost threshold reviews
(e)	Each cost threshold review is to be commenced by the AER by 31 July of the relevant year.
(f)	The first review of the cost thresholds for: :
(1)	the regulatory investment test for transmission under paragraph (a) must be initiated in 2012; and
(2)	the regulatory investment test for distribution under paragraph (c) must be initiated in 2015.
(g)	Within six weeks following the commencement of a cost threshold review, the AER must publish a draft determination outlining:
(1)	whether the AER has formed the view that any of the cost thresholds need to be amended to reflect increases or decreases in the input costs to ensure that the appropriateness of the cost thresholds is maintained over time;
(2)	its reasons for determining whether the cost thresholds need to be varied to reflect increases or decreases in the input costs;
(3)	if there is to be a variation in a cost threshold, the amount of the new cost threshold and the date the new cost threshold will take effect; and
(4)	its reasons for determining the amount of the new cost threshold.
(h)	At the same time as it publishes the draft determination under paragraph (f), the AER must publish a notice seeking submissions on the draft determination. The notice must specify the period within which written submissions can be made (the cost threshold consultation period) which must be no less than 5 weeks from the date of the notice.
(i)	The AER must consider any written submissions received during the cost threshold consultation period in making its final determination in respect of the matters outlined in paragraph (g).
(j)	The final determination on cost thresholds must be made and published by the AER within 5 weeks following the end of the cost threshold consultation period.
(k)	The AER may publish a draft determination under paragraph (g), a notice under paragraph (h), or a final determination under paragraph (j) for any cost threshold reviews under paragraphs (a) and (c) as a single document.
5.15.4	Costs determinations
(a)	Where the AER engages a consultant to assist in making a determination under rule 5.16B or clause 5.17.5, the AER may make a costs determination.
(b)	Where a costs determination is made, the AER may:
(1)	render the RIT-T proponent or the RIT-D proponent (as the case may be) an invoice for the costs; or
(2)	determine that the costs should:
(i)	be shared by all the parties to the dispute, whether in the same proportion or differing proportions; or
(ii)	be borne by a party or parties to the dispute other than the RIT-T proponent or the RIT-D proponent (as the case may be) whether in the same proportion or differing proportions; and
(iii)	the AER may render invoices accordingly.
(c)	If an invoice is rendered under subparagraph (b)(2)(iii), the AER must specify a time period for the payment of the invoice that is no later than 30 business days from the date the AER makes a determination under paragraph (a).
5.15A	Regulatory investment test for transmission
5.15A.1	General principles and application
(a)	The AER must develop and publish the regulatory investment test for transmission in accordance with the transmission consultation procedures and this rule 5.15A.
(b)	The regulatory investment test for transmission will apply to RIT-T projects which are not actionable ISP projects (in accordance with rule 5.16) and to RIT-T projects which are actionable ISP projects (in accordance with rule 5.16A) but will differ in its application to each of those types of projects.
(c)	The purpose of the regulatory investment test for transmission in respect of its application to both types of projects is to identify the credible option that maximises the present value of net economic benefit to all those who produce, consume and transport electricity in the market (the preferred option). For the avoidance of doubt, a preferred option may, in the relevant circumstances, have a negative net economic benefit (that is, a net economic cost) to the extent the identified need is for reliability corrective action.
(d)	The regulatory investment test for transmission application guidelines under clause 5.16.2 apply to RIT-T projects which are not actionable ISP projects.
(e)	The Cost Benefit Analysis Guidelines under clause 5.22.5 apply to RIT-T projects which are actionable ISP projects.
5.15A.2	Principles for RIT-T projects which are not actionable ISP projects
(a)	This clause 5.15A.2 only applies in respect of the application of the regulatory investment test for transmission to RIT-T projects that are not actionable ISP projects.
(b)	The regulatory investment test for transmission in respect of its application to both types of projects must:
(1)	be based on a cost-benefit analysis that is to include an assessment of reasonable scenarios of future supply and demand if each credible option were implemented compared to the situation where no option is implemented;
(2)	not require a level of analysis that is disproportionate to the scale and likely impact of each of the credible options being considered;
(3)	be capable of being applied in a predictable, transparent and consistent manner;
(4)	require the RIT-T proponent to consider the following classes of market benefits that could be delivered by the credible option:
(i)	changes in fuel consumption arising through different patterns of generation dispatch;
(ii)	changes in voluntary load curtailment;
(iii)	changes in involuntary load shedding, with the market benefit to be considered using a reasonable forecast of the value of electricity to consumers;
(iv)	changes in costs for parties, other than the RIT-T proponent, due to:
(A)	differences in the timing of new plant;
(B)	differences in capital costs; and
(C)	differences in the operating and maintenance costs;
(v)	differences in the timing of expenditure;
(vi)	changes in network losses;
(vii)	changes in ancillary services  costs;
(viii)	competition benefits;
(ix)	any additional option value (where this value has not already been included in the other classes of market benefits) gained or foregone from implementing that credible option with respect to the likely future investment needs of the market; and
(x)	other classes of market benefits that are:
(A)	determined to be relevant by the RIT-T proponent and agreed to by the AER in writing before the date the relevant project specification consultation report is made available to other parties under clause 5.16.4; or
(B)	specified as a class of market benefit in the regulatory investment test for transmission;
(5)	require a RIT-T proponent to include a quantification of all classes of market benefits which are determined to be material in the RIT-T proponent's reasonable opinion;
(6)	require a RIT-T proponent to consider all classes of market benefits as material unless it can, in the project assessment draft report, or in respect of a proposed preferred option which is subject to the exemption contained in clause 5.16.4(z1), in the project specification consultation report, provide reasons why:
(i)	a particular class of market benefit is likely not to affect materially the outcome of the assessment of the credible options under the regulatory investment test for transmission; or
(ii)	the estimated cost of undertaking the analysis to quantify the market benefit is likely to be disproportionate to the scale, size and potential benefits of each credible option being considered in the report;
(7)	with respect to the classes of market benefits set out in subparagraphs (4)(ii) and (iii), ensure that, if the credible option is for reliability corrective action, the quantification assessment required by paragraph (5) will only apply insofar as the market benefit delivered by the credible option exceeds the minimum standard required for reliability corrective action;
(8)	require the RIT-T proponent to quantify the following classes of costs:
(i)	costs incurred in constructing or providing the credible option;
(ii)	operating and maintenance costs in respect of the credible option;
(iii)	the cost of complying with laws, regulations and applicable administrative requirements in relation to the construction and operation of the credible option; and
(iv)	any other class of costs that are:
(A)	determined to be relevant by the RIT-T proponent and agreed to by the AER in writing before the date the relevant project specification consultation report is made available to other parties under clause 5.16.4; or
(B)	specified as a class of cost in the regulatory investment test for transmission;
(9)	provide that any cost or market benefit which cannot be measured as a cost or market benefit to Generators, Distribution Network Service Providers, Transmission Network Service Providers or consumers of electricity may not be included in any analysis under the regulatory investment test for transmission;
(10)	specify:
(i)	the method or methods permitted for estimating the magnitude of the different classes of market benefits;
(ii)	the method or methods permitted for estimating the magnitude of the different classes of costs;
(iii)	the method or methods permitted for estimating market benefits which may occur outside the region in which the networks affected by the RIT-T project are located; and
(iv)	the appropriate method and value for specific inputs, where relevant, for determining the discount rate or rates to be applied;
(11)	specify that a sensitivity analysis is required of any modelling relating to the cost-benefit analysis; and
(12)	reflect that the credible option that maximises the present value of net economic benefit to all those who produce, consume or transport electricity in the market may, in some circumstances, have a negative net economic benefit (that is, a net economic cost) where the identified need is for reliability corrective action.
5.15A.3	Principles for actionable ISP projects
(a)	This clause 5.15A.3 only applies in respect of the application of the regulatory investment test for transmission to RIT-T projects that are actionable ISP projects.
(b)	The regulatory investment test for transmission must:
(1)	assess the costs and benefits of future supply and demand if each credible option were implemented compared to the case where that option is not implemented;
(2)	not require a level of analysis that is disproportionate to the scale and likely impact of each of the credible options being considered;
(3)	be capable of being applied in a predictable, transparent and consistent manner;
(4)	require a RIT-T proponent to include a quantification of all classes of market benefits identified in the relevant Integrated System Plan, and may include consideration of other classes of market benefits, in accordance with the Cost Benefit Analysis Guidelines;
(5)	with respect to the classes of market benefits set out in subparagraph (4), ensure that, if the credible option is for reliability corrective action, the quantification assessment required by subparagraph (4) will only apply insofar as the market benefit delivered by the credible option exceeds the minimum standard required for reliability corrective action;
(6)	require the RIT-T proponent to quantify the following classes of costs:
(i)	costs incurred in constructing or providing each credible option;
(ii)	operating and maintenance costs in respect of each credible option;
(iii)	the cost of complying with laws, regulations and applicable administrative requirements in relation to the construction and operation of each credible option; and
(iv)	any other class of costs that are:
(A)	determined to be relevant by the RIT-T proponent and agreed to by the AER in writing before the date the relevant project assessment draft report is made available to other parties under clause 5.16A.4; or
(B)	specified as a class of cost in the regulatory investment test for transmission;
(7)	specify that the RIT-T proponent must:
(i)	comply with the Cost Benefit Assessment Guidelines;
(ii)	adopt the identified need set out in the Integrated System Plan relevant to the actionable ISP project;
(iii)	consider the following credible options:
(A)	the ISP candidate option or ISP candidate options, which may include refinements of an ISP candidate option;
(B)	non-network options identified in the Integrated System Plan as being reasonably likely to meet the relevant identified need, in accordance with clause 5.22.12(e)(1); and
(C)	any new credible options that were not previously considered in the Integrated System Plan that meet the identified need (including any non-network options submitted to AEMO in accordance with clause 5.22.14(c)(1));
(iv)	adopt the most recent ISP parameters, or if the RIT-T proponent decides to vary or omit an ISP parameter, or add a new parameter, then the RIT-T proponent must specify the ISP parameter which is new, omitted or has been varied and provide demonstrable reasons why the addition or variation is necessary;
(v)	assess the market benefits with and without each credible option; and
(vi)	in so far as practicable, adopt the market modelling from the Integrated System Plan;
(8)	specify that the RIT-T proponent is not required to:
(i)	consider any credible option that was previously considered in the Integrated System Plan, but does not form part of the optimal development path;
(ii)	consider any non-network options identified in the Integrated System Plan as not meeting the relevant identified need, in accordance with clause 5.22.12(e)(2); or
(iii)	request submissions for non-network options, or otherwise seek to identify non-network options in addition to those assessed in the Integrated System Plan under clause 5.22.12(d) or submitted to AEMO in accordance with clause 5.22.14(c)(1); and
(9)	specify the RIT-T proponent may, but is not required to, consider credible options already considered and not included in the optimal development path in the Integrated System Plan.
5.16	Application of RIT-T to RIT-T projects which are not actionable ISP projects
5.16.1	Application
This rule 5.16 applies to the application of the regulatory investment test for transmission to RIT-T-projects that are not actionable ISP projects.
5.16.2	Regulatory investment test for transmission application guidelines
(a)	At the same time as the AER develops and publishes a proposed regulatory investment test for transmission under the transmission consultation procedure, the AER must also develop and publish guidelines for the operation and application of the regulatory investment test for transmission (the regulatory investment test for transmission application guidelines) in accordance with the transmission consultation procedures and this rule 5.16.
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.
(b)	The regulatory investment test for transmission application guidelines must:
(1)	give effect to and be consistent with this clause 5.16.2 and clauses 5.15.2, 5.16.3, 5.16.4 and rule 5.16B; and
(2)	provide guidance on:
(i)	the operation and application of the regulatory investment test for transmission;
(ii)	the process to be followed in applying the regulatory investment test for transmission; and
(iii)	how disputes raised in relation to the regulatory investment test for transmission and its application will be addressed and resolved.
(c)	The regulatory investment test for transmission application guidelines must provide guidance and worked examples as to:
(1)	what constitutes a credible option;
(2)	acceptable methodologies for valuing the costs of a credible option;
(3)	what may constitute an externality under the regulatory investment test for transmission;
(4)	the classes of market benefits to be considered for the purposes of clause 5.15A.2(b)(4);
(5)	the suitable modelling periods and approaches to scenario development;
(6)	the acceptable methodologies for valuing the market benefits of a credible option referred to clause 5.15A.2(b)(4), including the option value, competition benefits and market benefits that accrue across regions;
(7)	the appropriate approach to undertaking a sensitivity analysis for the purposes of clause 5.15A.2(b)(11);
(8)	the appropriate approaches to assessing uncertainty and risks; and
(9)	when a person is sufficiently committed to a credible option for reliability corrective action to be characterised as a proponent for the purposes of clause 5.15.2(b)(7).
(d)	The AER must ensure that there is a regulatory investment test for transmission and regulatory investment test for transmission application guidelines in force at all times.
(e)	The AER may, from time to time, amend or replace the regulatory investment test for transmission and regulatory investment test for transmission application guidelines in accordance with the transmission consultation procedures, provided the AER  publishes any amendments to, or replacements of, the regulatory investment test for transmission or regulatory investment test for transmission application guidelines at the same time.
(f)	An amendment referred to in paragraph (e) does not apply to a current application of the regulatory investment test for transmission and the regulatory investment test for transmission application guidelines under the Rules by RIT-T proponent.
(g)	For the purposes of paragraph (f), a "current application" means any action or process initiated under the Rules which relies on or is referenced to the regulatory investment test for transmission and/or the regulatory investment test for transmission application guidelines and is not completed at the date of the relevant amendment to the regulatory investment test for transmission and/or the regulatory investment test for transmission application guidelines.
5.16.3	Investments subject to the regulatory investment test for transmission
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.
(a)	A RIT-T proponent must apply the regulatory investment test for transmission to a RIT-T project except in circumstances where:
(1)	the RIT-T project is required to address an urgent and unforeseen network issue that would otherwise put at risk the reliability of the transmission network as described in paragraph (b);
(2)	the estimated capital cost of the most expensive option to address the identified need which is technically and economically feasible is less than $5 million (as varied in accordance with a cost threshold determination);
(3)	the proposed expenditure relates to maintenance and is not intended to augment the transmission network or replace network assets;
(4)	[Deleted];
(5)	the proposed relevant network investment is an investment undertaken by a  Transmission Network Service Provider which:
(i)	re-routes one or more paths of a network for the long term; and
(ii)	has a substantial primary purpose other than the need to augment a network,
(a reconfiguration investment) and which the RIT-T proponent reasonably estimates to have an estimated capital cost of less than $5 million (as varied in accordance with a cost threshold determination) or which has, or is likely to have, no material impact on network users;
(6)	the identified need can only be addressed by expenditure on a connection asset which provides services other than prescribed transmission services or standard control services;
(7)	the cost of addressing the identified need is to be fully recovered through charges other than charges in respect of prescribed transmission services or standard control services;
(8)	the proposed expenditure relates to protected event EFCS investment and is not intended to augment the transmission network; or
(9)	the proposed expenditure is an inertia service payment or a system strength services payment;
(10)	the proposed expenditure is for network investment undertaken by the Transmission Network Service Provider to satisfy its obligation as an Inertia Service Provider under clause 5.20B.4 to make available inertia network services in relation to an inertia shortfall for an inertia sub-network and:
(i)	immediately prior to the notice of the inertia shortfall being given by AEMO under clause 5.20B.3(c), the Inertia Service Provider is not under an obligation to provide inertia network services for that inertia sub-network (including under rule 11.100); and
(ii)	the time by which the Inertia Service Provider must make the inertia network services available is less than 18 months after the notice is given by AEMO under clause 5.20B.3(c); or
(11)	the proposed expenditure is for network investment undertaken by the Transmission Network Service Provider to satisfy its obligation as a System Strength Service Provider under clause 5.20C.3 to make available system strength services in relation to a fault level shortfall for a fault level node and:
(i)	immediately prior to the notice of the fault level shortfall being given by AEMO under clause 5.20C.2(c), the System Strength Service Provider is not under an obligation to provide system strength services for that fault level node (including under rule 11.101); and
(ii)	the time by which the System Strength Service Provider must make the system strength services available is less than 18 months after the notice is given by AEMO under clause 5.20C.2(c).
Note
This clause is classified as a civil penalty provision under the National Electricity (South Australia) Regulations. (See clause 6(1) and Schedule 1 of the National Electricity (South Australia) Regulations.)
(b)	For the purposes of paragraph (a)(1), a RIT-T project will be required to address an urgent and unforeseen network issue that would otherwise put at risk the reliability of the transmission network if:
(1)	it is necessary that the assets or services to address the issue be operational within 6 months of the issue being identified;
(2)	the event or circumstances causing the identified need was not reasonably foreseeable by, and was beyond the reasonable control of, the Network Service Provider(s) that identified the identified need;
(3)	a failure to address the identified need is likely to materially adversely affect the reliability and secure operating state of the transmission network; and
(4)	it is not a contingent project.
(c)	If a proposed relevant network investment is determined to be required to address an urgent and unforeseen network issue as described in paragraph (b), and the Network Service Provider making the investment is a Transmission Network Service Provider, then the Transmission Network Service Provider must provide the following information in its next Transmission Annual Planning Report following the identification of the need for the relevant network investment:
(1)	the date when the proposed relevant network investment became or will become operational;
(2)	the purpose of the proposed relevant network investment; and
(3)	the total cost of the proposed relevant network investment.
(d)	With the exception of funded augmentations, for each RIT-T project to which the regulatory investment test for transmission does not apply in accordance with paragraphs (a), the Network Service Providers affected by the RIT-T project must ensure, acting reasonably, that the investment required to address the identified need is planned and developed at least cost over the life of the investment.
(e)	A RIT-T proponent must not treat different parts of an integrated solution to an identified need as distinct and separate options for the purposes of determining whether the regulatory investment test for transmission applies to each of those parts.
5.16.4	Regulatory investment test for transmission procedures
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.
(a)	If a RIT-T project is subject to the regulatory investment test for transmission under clause 5.16.3, then the RIT-T proponent must consult all Registered Participants, NTESMO and interested parties on the RIT-T project in accordance with this clause 5.16.4.
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.)
Project specification consultation report
(b)	A RIT-T proponent must prepare a report (the project specification consultation report), which must include:
(1)	a description of the identified need;
(2)	the assumptions used in identifying the identified need (including, in the case of proposed reliability corrective action, why the RIT-T proponent considers reliability corrective action is necessary);
(3)	the technical characteristics of the identified need that a non-network option would be required to deliver, such as:
(i)	the size of load reduction or additional supply;
(ii)	location; and
(iii)	operating profile;
(4)	if applicable, reference to any discussion on the description of the identified need or the credible options in respect of that identified need in the most recent Integrated System Plan;
(5)	a description of all credible options of which the RIT-T proponent is aware that address the identified need, which may include, without limitation, alternative transmission options, interconnectors, generation, demand side management, market network services or other network options;
(6)	for each credible option identified in accordance with subparagraph (5), information about:
(i)	the technical characteristics of the credible option;
(ii)	whether the credible option is reasonably likely to have a material inter-network impact;
(iii)	the classes of market benefits that the RIT-T proponent considers are likely not to be material in accordance with clause 5.15A.2(b)(6), together with reasons of why the RIT-T proponent considers that these classes of market benefits are not likely to be material;
(iv)	the estimated construction timetable and commissioning date; and
(v)	to the extent practicable, the total indicative capital and operating and maintenance costs.
(c)	The RIT-T proponent must make the project specification consultation report available to all Registered Participants, NTESMO and other interested parties.
(d)	The RIT-T proponent must:
(1)	provide a summary of the project specification consultation report to NTESMO within 5 business days of making the project specification consultation report; and
(2)	upon request by an interested party, provide a copy of the project specification consultation report to that person within 3 business days of the request.
(e)	Within 3 business days of receipt of the summary, NTESMO must publish the summary of the project specification consultation report on its website.
(f)	The RIT-T proponent must seek submissions from Registered Participants, NTESMO and interested parties on the credible options presented, and the issues addressed, in the project specification consultation report.
(g)	The period for consultation referred to in paragraph (f) must be not less than 12 weeks from the date that NTESMO publishes the summary of the project specification consultation report on its website.
(h)	A RIT-T proponent that is a Transmission Network Service Provider may discharge its obligation under paragraph (c) to make the project specification consultation report available by including the project specification consultation report as part of its Transmission Annual Planning Report.
(i)	A RIT-T proponent that is a Distribution Network Service Provider may discharge its obligation under paragraph (c) to make the project specification consultation report available by including the project specification consultation report as part of its Distribution Annual Planning Report.
Project assessment draft report
(j)	If one or more Network Service Providers wishes to proceed with a RIT-T project, within 12 months of the end date of the consultation period referred to in paragraph (g), or such longer time period as is agreed in writing by the AER, the RIT-T proponent for the relevant RIT-T project must prepare a report (the project assessment draft report), having regard to the submissions received, if any, under paragraph (f) and make that report available to all Registered Participants, NTESMO and interested parties.
(k)	The project assessment draft report must include:
(1)	a description of each credible option assessed;
(2)	a summary of, and commentary on, the submissions to the project specification consultation report;
(3)	a quantification of the costs, including a breakdown of operating and capital expenditure, and classes of material market benefit for each credible option;
(4)	a detailed description of the methodologies used in quantifying each class of material market benefit and cost;
(5)	reasons why the RIT-T proponent has determined that a class or classes of market benefit are not material;
(6)	the identification of any class of market benefit estimated to arise outside the region of the Transmission Network Service Provider affected by the RIT-T project, and quantification of the value of such market benefits (in aggregate across all regions);
(7)	the results of a net present value analysis of each credible option and accompanying explanatory statements regarding the results;
(8)	the identification of the proposed preferred option;
(9)	for the proposed preferred option identified under subparagraph (8), the RIT-T proponent must provide:
(i)	details of the technical characteristics;
(ii)	the estimated construction timetable and commissioning date;
(iii)	if the proposed preferred option is likely to have a material inter-network impact and if the Transmission Network Service Provider affected by the RIT-T project has received an augmentation technical report, that report; and
(iv)	a statement and the accompanying detailed analysis that the preferred option satisfies the regulatory investment test for transmission.
(l)	If a Network Service Provider affected by a RIT-T project elects to proceed with a project which is for reliability corrective action, it can only do so where the proposed preferred option has a proponent. The RIT-T proponent must identity that proponent in the project assessment draft report.
(m)	A RIT-T proponent that is a Transmission Network Service Provider may discharge its obligation under paragraph (j) to make the project assessment draft report available by including the project assessment draft report as part of its Transmission Annual Planning Report provided that report is published within 12 months of the end date of the consultation period required under paragraph (g) or within 12 months of the end of such longer time period as is agreed by the AER in writing under paragraph (j).
(n)	A RIT-T proponent that is a Distribution Network Service Provider may discharge its obligation under paragraph (j) to make the project assessment draft report available by including the project assessment draft report as part of its Distribution Annual Planning Report provided that report is published within 12 months of the end date of the consultation period required under paragraph (g) or within 12 months of the end of such longer time period as is agreed by the AER in writing under paragraph (j).
(o)	The RIT-T proponent must:
(1)	provide a summary of the project assessment draft report to NTESMO within 5 business days of making the project assessment draft report; and
(2)	upon request by an interested party, provide a copy of the project assessment draft report to that person within 3 business days of the request.
(p)	Within 3 business days of receipt of the summary, NTESMO must publish the summary of the project assessment draft report on its website.
(q)	The RIT-T proponent must seek submissions from Registered Participants, NTESMO and interested parties on the preferred option presented, and the issues addressed, in the project assessment draft report.
(r)	The period for consultation referred to in paragraph (q) must be not less than 6 weeks from the date that NTESMO publishes the summary of the report on its website.
(s)	Within 4 weeks after the end of the consultation period required under paragraph (r), at the request of an interested party, a Registered Participant or NTESMO (each being a relevant party for the purposes of this paragraph), the relevant Network Service Provider must meet with the relevant party if a meeting is requested by two or more relevant parties and may meet with a relevant party if after having considered all submissions, the relevant Network Service Provider, acting reasonably, considers that the meeting is necessary.
Project assessment conclusions report
(t)	As soon as practicable after the end of the consultation period on the project assessment draft report referred to in paragraph (r), the RIT-T proponent must, having regard to the submissions received, if any, under paragraph (q) and the matters discussed at any meetings held, if any, under paragraph (s), prepare and make available to all Registered Participants, NTESMO and interested parties and publish a report (the project assessment conclusions report).
(u)	If:
(1)	the RIT-T proponent is exempt from making a project assessment draft report under paragraph (z1); and
(2)	a Network Service Provider affected by a RIT-T project, within 12 months of the end date of the period for consultation referred to in paragraph (g), or within 12 months of the end date of such longer time period as is agreed in writing by the AER elects to proceed with the proposed transmission investment,
the relevant Network Service Provider must, having regard to the submissions received, if any, under paragraph (g) as soon as practicable prepare and make available to all Registered Participants, NTESMO and interested parties and publish a report (the project assessment conclusions report).
(v)	The project assessment conclusions report must set out:
(1)	the matters detailed in the project assessment draft report as required under paragraph (k); and
(2)	a summary of, and the RIT-T proponent's response to, submissions received, if any, from interested parties sought under paragraph (q).
(w)	The RIT-T proponent must:
(1)	provide a summary of the project assessment conclusions report to NTESMO within 5 business days of making the project assessment conclusions report; and
(2)	upon request by an interested party, provide a copy of the project assessment conclusions report to that person within 3 business days of the request.
(x)	Within 3 business days of receipt of the summary, NTESMO must publish the summary of the project assessment conclusions report on its website.
(y)	A RIT-T proponent that is a Transmission Network Service Provider may discharge its obligation under paragraph (t) and (u) to make the project assessment conclusions report available by including the project assessment conclusions report as part of its Transmission Annual Planning Report provided that the report is published within 4 weeks from the date of making available the project assessment conclusions report under paragraph (t) or (u), as the case may be.
(z)	A RIT-T proponent that is a Distribution Network Service Provider may discharge its obligation under paragraph (t) and (u) to make the project assessment conclusions report available by including the project assessment conclusions report as part of its Distribution Annual Planning Report provided that the report is published within 4 weeks from the date of making available the project assessment conclusions report under paragraph (t) or (u), as the case may be.
Exemption from drafting a project assessment draft report for RIT-T projects without material market benefits
(z1)	A RIT-T proponent is exempt from paragraphs (j) to (s) if:
(1)	the estimated capital cost of the proposed preferred option is less than $35 million (as varied in accordance with a cost threshold determination);
(2)	the relevant  Network Service Provider has identified in its project specification consultation report:
(i)	its proposed preferred option;
(ii)	its reasons for the proposed preferred option; and
(iii)	that its RIT-T project has the benefit of this exemption;
(3)	the RIT-T proponent considers, in accordance with clause 5.15A.2(b)(6), that the proposed preferred option and any other credible option in respect of the identified need will not have a material market benefit for the classes of market benefit specified in clause 5.15A.2(b)(4) except those classes specified in clauses 5.15A.2(b)(4)(ii) and (iii), and has stated this in its project specification consultation report; and
(4)	the RIT-T proponent forms the view that no submissions were received on the project specification consultation report which identified additional credible options that could deliver a material market benefit.
(z2)	The RIT-T proponent must address in the project assessment conclusions report any issues that were raised in relation to a proposed preferred option to which paragraph (z1) applies during the consultation on the project specification consultation report.
Reapplication of regulatory investment test for transmission
(z3)	If:
(1)	a RIT-T proponent has published a project assessment conclusions report in respect of a RIT-T project;
(2)	a Network Service Provider still wishes to undertake the RIT-T project to address the identified need; and
(3)	there has been a material change in circumstances which, in the reasonable opinion of the RIT-T proponent means that the preferred option identified in the project assessment conclusions report is no longer the preferred option,
then the RIT-T proponent must reapply the regulatory investment test for transmission to the RIT-T project, unless otherwise determined by the AER.
(z4)	For the purposes of paragraph (z3), a material change in circumstances may include, but is not limited to, a change to the key assumptions used in identifying:
(1)	the identified need described in the project assessment conclusions report; or
(2)	the credible options assessed in the project assessment conclusions report.
(z5)	When making a determination under paragraph (z3) the AER must have regard to:
(1)	the credible options (other than the preferred option) identified in the project assessment conclusions report;
(2)	the change in circumstances identified by the RIT-T proponent; and
(3)	whether a failure to promptly undertake the RIT-T project is likely to materially affect the reliability and secure operating state of the transmission network or a significant part of that network.
Declared transmission system operator may request assistance from AEMO to conduct market benefits assessments for replacement RIT-T projects
(z6)	Where a RIT-T proponent is a declared transmission system operator within a declared shared network, it may in relation to RIT-T projects to address an identified need that arises from the retirement or de-rating of network assets, request assistance and information from AEMO as reasonably required for it to consider and conduct market benefits assessments as required by:
(1)	clause 5.16.4(b)(6)(iii);
(2)	clause 5.16.4(k)(3) to (k)(6); and
(3)	clause 5.16.4(v).
(z7)	AEMO must provide assistance and information requested under paragraph (z6) to the declared transmission system operator within a reasonable period of time.
5.16.5	[Deleted]
5.16.6	[Deleted]
5.16A	Application of the RIT-T to actionable ISP Projects
5.16A.1	Application
This rule 5.16A applies to the application of the regulatory investment test for transmission to RIT-T-projects that are actionable ISP projects.
5.16A.2	Cost Benefit Analysis Guidelines
(a)	The Cost Benefit Analysis Guidelines developed and published by the AER in accordance with clause 5.22.5 must include guidelines for the operation and application of the regulatory investment test for transmission to actionable ISP projects in accordance with rule 5.15A and this rule 5.16A.
(b)	The Cost Benefit Analysis Guidelines must in relation to the application of the regulatory investment test for transmission by a RIT-T proponent to an actionable ISP project:
(1)	give effect to and be consistent with rule 5.15A and clauses 5.16A.3, 5.16A.4 and 5.16A.5; and
(2)	specify requirements for actionable ISP projects on:
(i)	the operation and application of the regulatory investment test for transmission;
(ii)	the process to be followed in applying the regulatory investment test for transmission; and
(iii)	how disputes raised in relation to the regulatory investment test for transmission and its application will be addressed and resolved.
(c)	The Cost Benefit Analysis Guidelines must provide guidance as to:
(1)	what constitutes a credible option for the purposes of clause 5.15A.3(b)(7)(iii)(C);
(2)	acceptable methodologies for valuing the costs of a credible option; and
(3)	how the RIT-T proponent must apply the ISP parameters.
5.16A.3	Actionable ISP projects subject to the RIT-T
(a)	A RIT-T proponent must apply the regulatory investment test for transmission to an identified need related to an actionable ISP project except if the circumstances set out in clause 5.16.3(a) apply to that actionable ISP project.
(b)	In addition to the circumstances under clause 5.16.3(a)(1), an actionable ISP project will also be taken to be required to address an urgent and unforeseen network issue that would otherwise put at risk the reliability of the transmission network where it is identified as such a project in the Integrated System Plan.
(c)	If a proposed relevant network investment is determined to be required to address an urgent and unforeseen network issue as described in paragraph (b), then the relevant Transmission Network Service Provider must provide the following information in its next Transmission Annual Planning Report following the identification of the need for the relevant network investment:
(1)	the date when the proposed relevant network investment became or will become operational;
(2)	the purposes of the proposed relevant network investment; and
(3)	the total cost of the proposed relevant network investment.
(d)	With the exception of funded augmentations, for each actionable ISP project to which the regulatory investment test for transmission does not apply in accordance with paragraph (a), the Network Service Providers affected by the actionable ISP project must ensure, acting reasonably, that the investment required to address the identified need is planned and developed at least cost over the life of the investment.
5.16A.4	Regulatory investment test for transmission procedures
(a)	If a Transmission Network Service Provider is identified as a RIT-T proponent in an Integrated System Plan for an actionable ISP project, then that Transmission Network Service Provider is the RIT-T proponent for that RIT-T project and must apply the regulatory investment test for transmission to, and consult all Registered Participants, AEMO and interested parties on, that RIT-T project in accordance with this clause 5.16A.4.
(b)	A Transmission Network Service Provider's obligations under paragraphs (a) and (c) cease if AEMO publishes an Integrated System Plan or an ISP update that shows that the actionable ISP project no longer forms part of the optimal development path.
Project assessment draft report
(c)	The RIT-T proponent must prepare a report in accordance with paragraphs (d) to (h) (project assessment draft report) and publish it by the date specified in the Integrated System Plan for that RIT-T project or such longer time period as is agreed in writing by the AER and make that report available to all Registered Participants, AEMO and interested parties.
(d)	The project assessment draft report must:
(1)	include the matters required by the Cost Benefit Assessment Guidelines;
(2)	adopt the identified need set out in the Integrated System Plan (including, in the case of proposed reliability corrective action, why the RIT-T proponent considers reliability corrective action is necessary);
(3)	describe each credible option assessed;
(4)	include a quantification of the costs, including a breakdown of operating and capital expenditure for each credible option;
(5)	assess market benefits with and without each credible option and provide accompanying explanatory statements regarding the results;
(6)	if the RIT-T proponent has varied the ISP parameters, provide demonstrable reasons in accordance with 5.15A.3(b)(7)(iv);
(7)	identify the proposed preferred option that the RIT-T proponent proposes to adopt; and
(8)	for the proposed preferred option identified under subparagraph (7), the RIT-T proponent must provide:
(i)	details of the technical characteristics; and
(ii)	the estimated construction timetable and commissioning date.
(e)	The RIT-T proponent must publish on its website the project assessment draft report within 5 business days of the project assessment draft report being made. The RIT-T proponent must promptly provide the project assessment draft report to AEMO after it is made and AEMO must publish on its website the report within 5 business days of receipt.
(f)	The RIT-T proponent must seek submissions from Registered Participants, AEMO and interested parties on the proposed preferred option presented, and the issues addressed, in the project assessment draft report.
(g)	The period for consultation referred to in paragraph (f) must be not less than 6 weeks from the date that AEMO publishes the report on its website.
(h)	Within 4 weeks after the end of the consultation period required under paragraph (g), at the request of an interested party, a Registered Participant or AEMO (each being a relevant party for the purposes of this paragraph), the RIT-T proponent must meet with the relevant party if a meeting is requested by two or more relevant parties and may meet with a relevant party if after having considered all submissions, the RIT-T proponent, acting reasonably, considers that the meeting is necessary.
Project assessment conclusions report
(i)	As soon as practicable after the end of the consultation period on the project assessment draft report referred to in paragraph (g), the RIT-T proponent must, having regard to the submissions received, if any, under paragraph (f) and the matters discussed at any meetings held, if any, under paragraph (h), prepare and make available to all Registered Participants, AEMO and interested parties and publish a report (the project assessment conclusions report).
(j)	The project assessment conclusions report must set out:
(1)	the matters detailed in the project assessment draft report as required under paragraph (d); and
(2)	a summary of, and the RIT-T proponent's response to, submissions received, if any, from interested parties sought under paragraph (f).
(k)	The RIT-T proponent must publish on its website the project conclusions report within 5 business days of the project assessment conclusions report being made. The RIT-T proponent must promptly provide the project assessment conclusions report to AEMO after it is made and AEMO must publish on its website the report within 5 business days of receipt.
(l)	A RIT-T proponent may discharge its obligation under paragraph (i) to make the project assessment conclusions report available by including the project assessment conclusions report as part of its Transmission Annual Planning Report provided that the report is published within 4 weeks from the date of publishing the project assessment conclusions report under paragraph (i).
Exemption from drafting a project assessment draft report for RIT-T projects
(m)	A RIT-T proponent is exempt from paragraphs (c) to (h) if:
(1)	the estimated capital cost of all credible options is less than $35 million (as varied in accordance with a cost threshold determination);
(2)	AEMO has identified in the relevant draft Integrated System Plan that the identified need to be addressed relates to reliability corrective action and will have the benefit of this exemption; and
(3)	AEMO confirms that no submissions were received on the draft Integrated System Plan which identified additional credible options that could deliver a material market benefit.
Reapplication of regulatory investment test for transmission
(n)	If:
(1)	a RIT-T proponent has published on its website a project assessment conclusions report in respect of a RIT-T project; and
(2)	there has been either:
(i)	a material change in circumstances which, in the reasonable opinion of the RIT-T proponent means that the preferred option identified in the project assessment conclusions report is no longer the preferred option; or
(ii)	AEMO has published an Integrated System Plan or ISP update that shows a change to the identified need in relation to the actionable ISP project the subject of the project assessment conclusions report,
then the RIT-T proponent must re-apply the regulatory investment test for transmission, unless otherwise determined by the AER.
(o)	For the purposes of paragraph (n), a material change in circumstances may include, but is not limited to, a change to the key inputs and assumptions (including as a result of an ISP update) used in identifying:
(1)	the identified need described in the project assessment conclusions report; or
(2)	the credible options assessed in the project assessment conclusions report.
(p)	When making a determination under paragraph (n) the AER must have regard to:
(1)	the credible options (other than the preferred option) identified in the project assessment conclusions report;
(2)	the change in circumstances identified by the RIT-T proponent or AEMO; and
(3)	whether a failure to promptly undertake the RIT-T project is likely to materially affect the reliability and secure operating state of the transmission network or a significant part of that network.
5.16A.5	Actionable ISP project trigger event
In order to be eligible to submit a contingent project application in relation to an actionable ISP project (or a stage of an actionable ISP project if the actionable ISP project is a staged project) under clause 6A.8.2, all of the following criteria must be satisfied ("trigger event"):
(a)	the RIT-T proponent must issue a project assessment conclusions report that meets the requirements of clause 5.16A.4 and which identifies a project as the preferred option (which may be a stage of an actionable ISP project if the actionable ISP project is a staged project);
(b)	the RIT-T proponent must obtain written confirmation from AEMO that:
(1)	the preferred option addresses the relevant identified need specified in the most recent Integrated System Plan and aligns with the optimal development path referred to in the most recent Integrated System Plan; and
(2)	the cost of the preferred option does not change the status of the actionable ISP project as part of the optimal development path as updated in accordance with clause 5.22.15 where applicable;
(c)	no dispute notice has been given to the AER under rule 5.16B(c) or, if a dispute notice has been given, then in accordance with rule 5.16B(d), the dispute has been rejected or the project assessment conclusions report has been amended and identifies that project as the preferred option; and
(d)	the cost of the preferred option set out in the contingent project application must be no greater than the cost considered in AEMO's assessment in subparagraph (b).
5.16B	Disputes in relation to application of regulatory investment test for transmission
(a)	Registered Participants, the AEMC, Connection Applicants, Intending Participants, AEMO and interested parties may, by notice to the AER, dispute conclusions made by the RIT-T proponent in the project assessment conclusions report in relation to:
(1)	the application of the regulatory investment test for transmission;
(2)	the basis on which the RIT-T proponent has classified the preferred option as being for reliability corrective action; or
(3)	the RIT-T proponent's assessment regarding whether the preferred option will have a material inter-network impact, in accordance with any criteria for a material inter-network impact that are in force at the time of the preparation of the project assessment conclusions report.
(b)	A dispute under this rule 5.16B may not be raised in relation to any matters set out in the project assessment conclusions report which:
(1)	are treated as externalities by the regulatory investment test for transmission; or
(2)	relate to an individual's personal detriment or property rights; or
(3)	for an actionable ISP project, uses or relies on matters set out in the most recent Integrated System Plan or Inputs Assumptions and Scenarios Report, including the identified need, ISP parameters, credible options or classes of market benefits relevant to that actionable ISP project.
(c)	Within 30 days of the date of publication of the project assessment conclusions report under clauses 5.16.4(t), (u), (y) or (z) or 5.16A.4(i) or (l) (as the case may be), the party disputing a conclusion made in the project assessment conclusions report (a disputing party) must:
(1)	give notice of the dispute in writing setting out the grounds for the dispute (the dispute notice) to the AER; and
(2)	at the same time, give a copy of the dispute notice to the RIT-T proponent.
(d)	Subject to paragraph (f)(3), within 40 days of receipt of the dispute notice or within an additional period of up to 60 days where the AER notifies interested parties that the additional time is required to make a determination because of the complexity or difficulty of the issues involved, the AER must either:
(1)	reject any dispute by written notice to the person who initiated the dispute if the AER considers that the grounds for the dispute are misconceived or lacking in substance; and
(2)	notify the RIT-T proponent that the dispute has been rejected; or
(3)	subject to paragraph (f), make and publish a determination:
(i)	directing the RIT-T proponent to amend the matters set out in the project assessment conclusions report; or
(ii)	stating that, based on the grounds of the dispute, the RIT-T proponent will not be required to amend the project assessment conclusions report.
(e)	The RIT-T proponent must comply with an AER determination made under paragraph (d)(3)(i) within a timeframe specified by the AER in its determination.
(f)	In making a determination under paragraph (d)(3), the AER:
(1)	must only take into account information and analysis that the RIT-T proponent could reasonably be expected to have considered or undertaken at the time that it performed the regulatory investment test for transmission;
(2)	must publish its reasons for making a determination;
(3)	may request further information regarding the dispute from the disputing party or the RIT-T proponent in which case the period of time for rejecting a dispute or making a determination under paragraph (d) is extended by the time it takes the relevant party to provide the requested further information to the AER;
(4)	may disregard any matter raised by the disputing party or the RIT-T proponent that is misconceived or lacking in substance; and
(5)	where making a determination under subparagraph (d)(3)(i), must specify a reasonable timeframe for the RIT-T proponent to comply with the AER's direction to amend the matters set out in the project assessment conclusions report.
(g)	The AER may only make a determination under subparagraph (d)(3)(i) if it determines that:
(1)	the RIT-T proponent has not correctly applied the regulatory investment test for transmission in accordance with the Rules;
(2)	the RIT-T proponent has erroneously classified the preferred option as being for reliability corrective action;
(3)	the RIT-T proponent, for a RIT-T project that is not an actionable ISP project, has not correctly assessed whether the preferred option will have a material inter-network impact; or
(4)	there was a manifest error in the calculations performed by the RIT-T proponent in applying the regulatory investment test for transmission.
(h)	A disputing party or the RIT-T proponent (as the case may be) must as soon as reasonably practicable provide any information requested under paragraph (f)(3) to the AER.
(i)	The relevant period of time in which the AER must make a determination under paragraph (d)(3) is automatically extended by the period of time taken by the RIT-T proponent or a disputing party to provide any additional information requested by the AER under this rule 5.16B, provided:
(1)	the AER makes the request for the additional information at least 7 business days prior to the expiry of the relevant period; and
(2)	the RIT-T proponent or the disputing party provides the additional information within 14 business days of receipt of the request.
5.17	Regulatory investment test for distribution
5.17.1	Principles
(a)	The AER must develop and publish the regulatory investment test for distribution in accordance with the distribution consultation procedures and this clause 5.17.1.
(b)	The purpose of the regulatory investment test for distribution is to identify the credible option that maximises the present value of the net economic benefit to all those who produce, consume and transport electricity in the local electricity system (the preferred option). For the avoidance of doubt, a preferred option may, in the relevant circumstances, have a negative net economic benefit (that is, a net economic cost) where the identified need is for reliability corrective action.
(c)	The regulatory investment test for distribution must:
(1)	be based on a cost-benefit analysis that must include an assessment of reasonable scenarios of future supply and demand;
(2)	not require a level of analysis that is disproportionate to the scale and likely impact of each of the credible options being considered;
(3)	be capable of being applied in a predictable, transparent and consistent manner;
(4)	require the RIT-D proponent to consider whether each credible option could deliver the following classes of market benefits:
(i)	changes in voluntary load curtailment;
(ii)	changes in involuntary load shedding and customer interruptions caused by network outages, using a reasonable forecast of the value of electricity to customers;
(iii)	changes in costs for parties, other than the RIT-D proponent, due to differences in:
(A)	the timing of new plant;
(B)	capital costs; and
(C)	the operating and maintenance costs;
(iv)	differences in the timing of expenditure;
(v)	changes in load transfer capacity and the capacity of Embedded Generators to take up load;
(vi)	any additional option value (where this value has not already been included in the other classes of market benefits) gained or foregone from implementing the credible option with respect to the likely future investment needs of the local electricity system;
(vii)	changes in electrical energy losses; and
(viii)	any other class of market benefit determined to be relevant by the AER.
(5)	with respect to the classes of market benefits set out in subparagraphs (4)(i) and (ii), ensure that, if a credible option is for reliability corrective action, the consideration and any quantification assessment of these classes of market benefits will only apply insofar as the market benefit delivered by that credible option exceeds the minimum standard required for reliability corrective action;
(6)	require the RIT-D proponent to consider whether the following classes of costs would be associated with each credible option and, if so, quantify the:
(i)	financial costs incurred in constructing or providing the credible option;
(ii)	operating and maintenance costs over the operating life of the credible option;
(iii)	cost of complying with laws, regulations and applicable administrative requirements in relation to the construction and operation of the credible option; and
(iv)	any other financial costs determined to be relevant by the AER.
(7)	require a RIT-D proponent, in exercising judgement as to whether a particular class of market benefit or cost applies to each credible option, to have regard to any submissions received on the non-network options report and/or draft project assessment report where relevant;
(8)	provide that any market benefit or cost which cannot be measured as a market benefit or cost to persons in their capacity as Generators, Distribution Network Service Providers, Transmission Network Service Providers or consumers of electricity must not be included in any analysis under the regulatory investment test for distribution; and
(9)	specify:
(i)	the method or methods permitted for estimating the magnitude of the different classes of market benefits;
(ii)	the method or methods permitted for estimating the magnitude of the different classes of costs;
(iii)	the appropriate method and value for specific inputs, where relevant, for determining the discount rate or rates to be applied;
(iv)	that a sensitivity analysis is required for modelling the cost-benefit analysis; and
(v)	that the credible option that maximises the present value of net economic benefit to all those who produce, consume or transport electricity in the local electricity system may, in some circumstances, be a negative net economic benefit (that is, a net economic cost) where the identified need is for reliability corrective action.
(d)	A RIT-D proponent may, under the regulatory investment test for distribution, quantify each class of market benefits under paragraph (c)(4) where the RIT-D proponent considers that:
(1)	any applicable market benefits may be material; or
(2)	the quantification of market benefits may alter the selection of the preferred option.
(e)	The regulatory investment test for distribution permits a single assessment of an integrated set of related and similar investments.
5.17.2	Regulatory investment test for distribution application guidelines
(a)	At the same time as the AER develops and publishes a proposed regulatory investment test for distribution under the distribution consultation procedure, the AER must also develop and publish guidelines for the operation and application of the regulatory investment test for distribution in accordance with the distribution consultation procedures and this clause 5.17.2.
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.
(b)	The regulatory investment test for distribution application guidelines must:
(1)	give effect to and be consistent with this clause 5.17.2 and clauses 5.15.2, 5.17.3, 5.17.4 and 5.17.5; and
(2)	provide guidance on:
(i)	the operation and application of the regulatory investment test for distribution;
(ii)	the process to be followed in applying the regulatory investment test for distribution;
(iii)	what will be considered to be a material and adverse local electricity system impact for the purposes of the definition of interested parties in clause 5.15.1.
(iv)	how disputes raised in relation to the regulatory investment test for distribution and its application will be addressed and resolved.
(c)	The regulatory investment test for distribution application guidelines must provide guidance and worked examples as to:
(1)	how to make a determination under clause 5.17.4(c);
(2)	what constitutes a credible option;
(3)	the suitable modelling periods and approaches to scenario development;
(4)	the classes of market benefits to be considered for the purposes of clause 5.17.1(c)(4);
(5)	the acceptable methodologies for valuing the market benefits of a credible option referred to in clause 5.17.1(c)(4);
(6)	acceptable methodologies for valuing the costs of a credible option referred to in clause 5.17.1(c)(6);
(7)	the appropriate approach to undertaking a sensitivity analysis for the purposes of clause 5.17.1(c)(9)(iv);
(8)	the appropriate approaches to assessing uncertainty and risks; and
(9)	what may constitute an externality under the regulatory investment test for distribution.
(d)	The AER must develop and publish the first regulatory investment test for distribution and regulatory investment test for distribution application guidelines by 31 August 2013, and there must be a regulatory investment test for distribution and regulatory investment test for distribution application guidelines in force at all times after that date.
(e)	The AER may, from time to time, amend or replace the regulatory investment test for distribution and regulatory investment test for distribution application guidelines in accordance with the distribution consultation procedures, provided the AER  publishes any amendments to, or replacements of, the regulatory investment test for distribution or regulatory investment test for distribution application guidelines at the same time.
(f)	An amendment referred to in paragraph (e) does not apply to a current application of the regulatory investment test for distribution and the regulatory investment test for distribution application guidelines under the Rules by a RIT-D proponent.
(g)	For the purposes of paragraph (f), a "current application" means any action or process initiated under the Rules which relies on or is referenced to the regulatory investment test for distribution and/or the regulatory investment test for distribution application guidelines and is not completed at the date of the relevant amendment to the regulatory investment test for distribution and/or the regulatory investment test for distribution application guidelines.
(h)	The AER may publish the regulatory investment test for distribution, the regulatory investment test for distribution application guidelines, the regulatory investment test for transmission and the regulatory investment test for transmission application guidelines in a single document.
5.17.3	Projects subject to the regulatory investment test for distribution
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.
(a)	A RIT-D proponent must apply the regulatory investment test for distribution to a RIT-D project except in circumstances where:
(1)	the RIT-D project is required to address an urgent and unforeseen network issue that would otherwise put at risk the reliability of the distribution network or a significant part of that network as described in paragraph (c);
(2)	the estimated capital cost to the Network Service Providers affected by the RIT-D project of the most expensive potential credible option to address the identified need is less than $5 million (as varied in accordance with a cost threshold determination);
(3)	the cost of addressing the identified need is to be fully recovered through charges other than charges in respect of standard control services or prescribed transmission services;
(4)	the identified need can only be addressed by expenditure on a connection asset which provides services other than standard control services or prescribed transmission services;
(5)	the RIT-D project is related to the maintenance of existing assets and is not intended to augment a network or replace network assets
(6)	[Deleted]; or
(7)	the proposed expenditure relates to protected event EFCS investment and is not intended to augment a network.
Note
This clause is classified as a civil penalty provision under the National Electricity (South Australia) Regulations. (See clause 6(1) and Schedule 1 of the National Electricity (South Australia) Regulations.)
(b)	If a potential credible option to address an identified need includes expenditure on a dual function asset, the project must be assessed under the regulatory investment test for distribution unless the identified need was identified through joint planning under rule 5.14 and the project to address the identified need is a RIT-T project.
(c)	For the purposes of paragraph (a)(1), a RIT-D project will be required to address an urgent and unforeseen network issue that would otherwise put at risk the reliability of the distribution network or a significant part of that network if:
(1)	it is necessary that the assets or services to address the issue be operational within six months of the issue being identified;
(2)	the event or circumstances causing the identified need was not reasonably foreseeable by, and was beyond the reasonable control of, the Network Service Provider(s) that identified the identified need;
(3)	a failure to address the identified need is likely to materially adversely affect the reliability and secure operating state of the distribution network or a significant part of that network; and
(4)	it is not a contingent project.
(d)	With the exception of negotiated distribution services and negotiated transmission services, for each RIT-D project to which the regulatory investment test for distribution does not apply in accordance with paragraph (a)(1)-(6), the Network Service Providers affected by the RIT-D project must ensure, acting reasonably, that the investment required to address the identified need is planned and developed at least cost over the life of the investment.
(e)	A RIT-D proponent must not treat different parts of an integrated solution to an identified need as distinct and separate options for the purposes of determining whether the regulatory investment test for distribution applies to each of those parts.
5.17.4	Regulatory investment test for distribution procedures
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.
(a)	If a RIT-D project is subject to the regulatory investment test for distribution under clause 5.17.3, then the RIT-D proponent must consult with the following persons on the RIT-D project in accordance with this clause 5.17.4:
(1)	all Registered Participants, NTESMO, interested parties and non-network providers; and
(2)	if the RIT-D proponent is a Distribution Network Service Provider, persons registered on its demand side engagement register.
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.)
Screening for non-network options
(b)	Subject to paragraph (c), a RIT-D proponent must prepare and publish a non-network options report under paragraph (e) if a RIT-D project is subject to the regulatory investment test for distribution under clause 5.17.3.
(c)	A RIT-D proponent is not required to comply with paragraph (b) if it determines on reasonable grounds that there will not be a non-network option that is a potential credible option, or that forms a significant part of a potential credible option, for the RIT-D project to address the identified need.
(d)	If a RIT-D proponent makes a determination under paragraph (c), then as soon as possible after making the determination it must publish a notice setting out the reasons for its determination, including any methodologies and assumptions it used in making its determination.
Non-network options report
(e)	A non-network options report must include:
(1)	a description of the identified need;
(2)	the assumptions used in identifying the identified need (including, in the case of proposed reliability corrective action, why the RIT-D proponent considers reliability corrective action is necessary);
(3)	if available, the relevant annual deferred augmentation charge associated with the identified need;
(4)	the technical characteristics of the identified need that a non-network option would be required to deliver, such as:
(i)	the size of load reduction or additional supply;
(ii)	location;
(iii)	contribution to power system security or reliability;
(iv)	contribution to power system fault levels as determined under jurisdictional electricity legislation; and
(v)	the operating profile;
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.
(5)	a summary of potential credible options to address the identified need, as identified by the RIT-D proponent, including network options and non-network options.
(6)	for each potential credible option, the RIT-D proponent must provide information, to the extent practicable, on:
(i)	a technical definition or characteristics of the option;
(ii)	the estimated construction timetable and commissioning date (where relevant); and
(iii)	the total indicative cost (including capital and operating costs); and
(7)	information to assist non-network providers wishing to present alternative potential credible options including details of how to submit a non-network proposal for consideration by the RIT-D proponent.
(f)	The non-network options report must be published in a timely manner having regard to the ability of parties to identify the scope for, and develop, alternative potential credible options or variants to the potential credible options.
(g)	At the same time as publishing the non-network options report, the RIT-D proponent, if it is a Distribution Network Service Provider, must notify persons registered on its demand side engagement register of the report's publication.
(h)	Registered Participants, NTESMO, interested parties, non-network providers and (if relevant) persons registered on the Distribution Network Service Provider's  demand side engagement register must be provided with not less than three months in which to make submissions on the non-network options report from the date that the RIT-D proponent publishes the report.
Draft project assessment report
(i)	If one or more Network Service Providers wishes to proceed with a RIT-D project following a determination under paragraph (c) or the publication of a non-network options report then the RIT-D proponent, having regard, where relevant, to any submissions received on the non-network options report, must prepare and publish a draft project assessment report within:
(1)	12 months of:
(i)	the end of the consultation period on a non-network options report; or
(ii)	where a non-network options report is not required, the publication of a notice under paragraph (d); or
(2)	any longer time period as agreed to in writing by the AER.
(j)	The draft project assessment report must include the following:
(1)	a description of the identified need for the investment;
(2)	the assumptions used in identifying the identified need (including, in the case of proposed reliability corrective action, reasons that the RIT-D proponent considers reliability corrective action is necessary);
(3)	if applicable, a summary of, and commentary on, the submissions on the non-network options report;
(4)	a description of each credible option assessed;
(5)	where a Distribution Network Service Provider has quantified market benefits in accordance with clause 5.17.1(d), a quantification of each applicable market benefit for each credible option;
(6)	a quantification of each applicable cost for each credible option, including a breakdown of operating and capital expenditure;
(7)	a detailed description of the methodologies used in quantifying each class of cost and market benefit;
(8)	where relevant, the reasons why the RIT-D proponent has determined that a class or classes of market benefits or costs do not apply to a credible option;
(9)	the results of a net present value analysis of each credible option and accompanying explanatory statements regarding the results;
(10)	the identification of the proposed preferred option;
(11)	for the proposed preferred option, the RIT-D proponent must provide:
(i)	details of the technical characteristics;
(ii)	the estimated construction timetable and commissioning date (where relevant);
(iii)	the indicative capital and operating cost (where relevant);
(iv)	a statement and accompanying detailed analysis that the proposed preferred option satisfies the regulatory investment test for distribution; and
(v)	if the proposed preferred option is for reliability corrective action and that option has a proponent, the name of the proponent; and
(12)	contact details for a suitably qualified staff member of the RIT-D proponent to whom queries on the draft report may be directed.
(k)	The RIT-D proponent must publish a request for submissions on the matters set out in the draft project assessment report, including the proposed preferred option, from:
(1)	Registered Participants, NTESMO, non-network providers and interested parties; and
(2)	if the RIT-D proponent is a Distribution Network Service Provider, persons on its demand side engagement register.
(l)	If the proposed preferred option has the potential to, or is likely to, have an adverse impact on the quality of service experienced by consumers of electricity, including:
(1)	anticipated changes in voluntary load curtailment by consumers of electricity; or
(2)	anticipated changes in involuntary load shedding and customer interruptions caused by network outages,
then the RIT-D proponent must consult directly with those affected customers in accordance with a process reasonably determined by the RIT-D proponent.
(m)	The consultation period on the draft project assessment report must not be less than six weeks from the publication of the report.
Exemption from the draft project assessment report
(n)	A RIT-D proponent is not required to prepare and publish a draft project assessment report under paragraph (i) if:
(1)	the RIT-D proponent made a determination under paragraph (c) and has published a notice under paragraph (d); and
(2)	the estimated capital cost to the Network Service Providers affected by the RIT-D project of the proposed preferred option is less than $10 million (varied in accordance with a cost threshold determination).
Final project assessment report
(o)	As soon as practicable after the end of the consultation period on the draft project assessment report, the RIT-D proponent must, having regard to any submissions received on the draft project assessment report, publish a final project assessment report.
(p)	If the RIT-D project is exempt from the draft project assessment report stage under paragraph (n), the RIT-D proponent must publish the final project assessment report as soon as practicable after the publication of the notice under paragraph (d).
(q)	At the same time as publishing the final project assessment report, a RIT-D proponent that is a Distribution Network Service Provider must notify persons on its demand side engagement register of the report's publication.
(r)	The final project assessment report must set out:
(1)	if a draft project assessment report was prepared:
(i)	the matters detailed in that report as required under paragraph (j); and
(ii)	a summary of any submissions received on the draft project assessment report and the RIT-D proponent's response to each such submission; and
(2)	if no draft project assessment report was prepared, the matters specified in paragraph (j).
(s)	If the preferred option outlined in the final project assessment report has an estimated capital cost to the Network Service Providers affected by the RIT-D project of less than $20 million (varied in accordance with a cost threshold determination), the RIT-D proponent may discharge its obligations to publish its final project assessment report under paragraphs (o) and (p) by including the final project assessment report as part of its Distribution Annual Planning Report (where the RIT-D proponent is a Distribution Network Service Provider) or its Transmission Annual Planning Report (where the RIT-D proponent is a Transmission Network Service Provider).
Reapplication of regulatory investment test for distribution
(t)	If:
(1)	a RIT-D proponent has published a final project assessment report in respect of a RIT-D project;
(2)	a Network Service Provider still wishes to undertake the RIT-D project to address the identified need; and
(3)	there has been a material change in circumstances which, in the reasonable opinion of the RIT-D proponent means that the preferred option identified in the final project assessment report is no longer the preferred option,
then the RIT-D proponent must reapply the regulatory investment test for distribution to the RIT-D project, unless otherwise determined by the AER.
(u)	For the purposes of paragraph (t), a material change in circumstances may include, but is not limited to, a change to the key assumptions used in identifying:
(1)	the identified need described in the final project assessment report; or,
(2)	the credible options assessed in, the final project assessment report.
(v)	When making a determination under paragraph (t) the AER must have regard to:
(1)	the credible options (other than the preferred option) identified in the final project assessment report;
(2)	the change in circumstances identified by the RIT-D proponent; and
(3)	whether a failure to promptly undertake the RIT-D project is likely to materially affect the reliability and secure operating state of the distribution network or a significant part of that network.
5.17.5	Disputes in relation to application of regulatory investment test for distribution
(a)	Registered Participants, the AEMC, Connection Applicants, Intending Participants, NTESMO, interested parties, and non-network providers may, by notice to the AER, dispute conclusions made by the RIT-D proponent in the final project assessment report on the grounds that:
(1)	the RIT-D proponent has not applied the regulatory investment test for distribution in accordance with the Rules; or
(2)	there was a manifest error in the calculations performed by the RIT-D proponent in applying the regulatory investment test for distribution.
(b)	A dispute under this clause 5.17.5 may not be raised in relation to any matters set out in the final project assessment report which:
(1)	are treated as externalities by the regulatory investment test for distribution; or
(2)	relate to an individual's personal detriment or property rights.
(c)	Within 30 days of the date of publication of the final project assessment report under clause 5.17.4(o), (p) or (s) (as the case may be), the party disputing matters in the final project assessment report (a disputing party) must:
(1)	give notice of the dispute in writing setting out the grounds for the dispute (the dispute notice) to the AER; and
(2)	at the same time, give a copy of the dispute notice to the RIT-D proponent.
(d)	Subject to paragraph (h), within 40 days of receipt of the dispute notice or within an additional period of up to 60 days where the AER notifies a relevant party that the additional time is required to make a determination because of the complexity or difficulty of the issues involved, the AER must either:
(1)	reject any dispute by written notice to the person who initiated the dispute if the AER considers that the grounds for the dispute are invalid, misconceived or lacking in substance; and
(2)	notify the RIT-D proponent that the dispute has been rejected; or
(3)	subject to paragraph (f) and (g), make and publish a determination:
(i)	directing the RIT-D proponent to amend the matters set out in the final project assessment report; or
(ii)	stating that, based on the grounds of the dispute, the RIT-D proponent will not be required to amend the final project assessment report.
(e)	A RIT-D proponent must comply with an AER determination made under subparagraph (d)(3)(i) within a timeframe specified by the AER in its determination.
(f)	In making a determination under paragraph (d)(3), the AER:
(1)	must only take into account information and analysis that the RIT-D proponent could reasonably be expected to have considered or undertaken at the time that it performed the regulatory investment test for distribution;
(2)	must publish its reasons for making a determination;
(3)	may disregard any matter raised by the disputing party or the RIT-D proponent that is misconceived or lacking in substance; and
(4)	where making a determination under subparagraph (d)(3)(i), must specify a reasonable timeframe for the RIT-D proponent to comply with the AER's direction to amend the matters set out in the final project assessment report.
(g)	The AER may only make a determination under subparagraph (d)(3)(i) if it determines that:
(1)	the RIT-D proponent has not correctly applied the regulatory investment test for distribution in accordance with the Rules; or
(2)	there was a manifest error in the calculations performed by the RIT-D proponent in applying the regulatory investment test for distribution.
(h)	The AER may request additional information regarding the dispute from the disputing party or the RIT-D proponent in which case the period of time for rejecting a dispute under paragraph (d)(1) or making a determination under paragraph (d)(3) is automatically extended by the time it takes the relevant party to provide the additional information to the AER provided:
(1)	the AER makes the request for additional information at least seven days prior to the expiry of the relevant period; and
(2)	the RIT-D proponent or disputing party provides the additional information within 14 days of receipt of the request under subparagraph (1).
(i)	A disputing party or the RIT-D proponent (as the case may be) must as soon as reasonably practicable provide any information requested under paragraph (h) to the AER.
5.18	Construction of funded augmentations
Note
The application of paragraph (c) of this rule will be revisited as part of the phased implementation of the Rules in this jurisdiction.
(a)	The term Transmission Network Service Provider when used in this rule 5.18 is not intended to refer to, and is not to be read or construed as referring to, any Transmission Network Service Provider in its capacity as a Market Network Service Provider.
(b)	A Transmission Network Service Provider who proposes to construct a funded augmentation must make available to all Registered Participants and AEMO a notice which must set out:
(1)	a detailed description of the proposed funded augmentation;
(2)	all relevant technical details concerning the proposed funded augmentation, the impact of the funded augmentation on the relevant transmission network's Transmission Network Users and the construction timetable and commissioning date for the funded augmentation;
(3)	an augmentation technical report prepared by AEMO if, and only if, the funded augmentation is reasonably likely to have a material inter-network impact and the Transmission Network Service Provider has not received consent to proceed with construction from all Transmission Network Service Providers whose transmission networks are materially affected by the funded augmentation. In assessing whether a funded augmentation is reasonably likely to have a material inter-network impact, the Transmission Network Service Provider must have regard to the objective set of criteria published by AEMO (if any such criteria have been published by AEMO).
(c)	The Transmission Network Service Provider must provide a summary of the notice prepared in accordance with paragraph (b) to AEMO. Within 3 business days of receipt of the summary, AEMO must publish the summary on its website.
(d)	The Transmission Network Service Provider must consult with any interested parties, in accordance with the Rules consultation procedures, on any matter set out in the notice prepared in accordance with paragraph (b).
5.18A	Generator connections
5.18A.1	Definitions
(a)	In this rule 5.18A:
assessment date means, in respect of a new large generator connection, the first TAPR date that falls no earlier than 18 months after the commissioning date for that large generator connection.
commissioning date means, in respect of a new large generator connection, the date of commencement of commissioning of the connection and connected facilities of that large generator connection.
connections register has the meaning given in clause 5.18A.2.
impact assessment has the meaning given in clause 5.18A.3.
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.
TAPR date means the date under clause 5.12.2 by which a Transmission Network Service Provider must publish its Transmission Annual Planning Report.
5.18A.2	Register of generator connections
(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).
(b)	Subject to satisfying any relevant exemptions contained in clause 8.6.2, the Transmission Network Service Provider must not publish confidential information as part of, or in connection with, the connections register.
(c)	The Transmission Network Service Provider must:
(1)	include in the first connections register the details contained in subparagraphs (a)(1) to (5), for all Generator connections on its network with a commissioning date after 1 July 2019; and
(2)	by the TAPR date each year, update the connections register to include:
(i)	the details contained in subparagraphs (a)(1) to (6) for all new Generator connections on its network; and
(ii)	updated information for all Generator connections contained in the connections register where the information listed in subparagraphs (a)(1)-(5) has changed.
5.18A.3	Impact assessment of large generator connections
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.
(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.
(b)	An impact assessment prepared in accordance with this clause 5.18A.3 is not required to be updated by the Transmission Network Service Provider at any future point in time.
(c)	The purpose of the impact assessment is to identify any material effects of the large generator connection on the Transmission Network Service Provider's network, as compared with the absence of that large generator connection on its network.
(d)	Subject to paragraph (e), when preparing an impact assessment, a Transmission Network Service Provider must consider whether the new large generator connection has resulted in changes to:
(1)	ancillary service requirements to the extent such changes relate specifically to the Transmission Network Service Provider's network;
(2)	the level, and pattern, of network congestion on its network;
(3)	the timing of expenditure for the Transmission Network Service Provider on its network; and
(4)	the level of interconnector power transfer capability on its network,
and if such changes have occurred, include details of the changes in the impact assessment to the extent they have had a material impact on the Transmission Network Services Provider's network.
(e)	If the Transmission Network Service Provider considers any of the changes referred to in paragraph (d) to have an immaterial impact on its network, outline the reasons why it has determined such impacts to be immaterial.
(f)	The impact assessment must:
(1)	be based on historical data;
(2)	consider the impacts referred to in paragraph (d) for the 12 months immediately preceding the commissioning date as compared to the 12 months following the commissioning date; and
(3)	include a detailed description of the methodologies or data used in quantifying each impact referred to in paragraph (d).
5.18B	Completed embedded generation projects
5.18B.1	Definitions
(a)	For the purposes of this rule 5.18B:
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.
DAPR date has the same meaning as in clause 5.13.2.
5.18B.2	Register of completed embedded generation projects
(a)	In relation to completed embedded generation projects, a Distribution Network Service Provider must establish and publish, on its website, a register of the plant, including but not limited to:
(1)	technology of generating unit (e.g. synchronous generating unit, induction generator, photovoltaic array, etc) and its make and model;
(2)	maximum power generation capacity of all embedded generating units comprised in the relevant generating system;
(3)	contribution to fault levels;
(4)	the size and rating of the relevant transformer;
(5)	a single line diagram of the connection arrangement;
(6)	protection systems and communication systems;
(7)	voltage control and reactive power capability; and
(8)	details specific to the location of a facility connected to the network that are relevant to any of the details in subparagraphs (1)-(7).
(b)	Subject to satisfying any relevant exemptions contained in clause 8.6.2, the Distribution Network Service Provider must not publish confidential information as part of, or in connection with, the register.
(c)	The Distribution Network Service Provider must:
(1)	include in the register the details contained in paragraph (b) for all completed embedded generation projects within the 5 year period preceding the establishment of the register; and
(2)	update the register by the DAPR date each year thereafter with details of all completed embedded generation projects in the 5 year period preceding the DAPR date.
5.19	SENE Design and Costing Study
5.19.1	Definitions
In this rule 5.19:
forecast generation scenarios means different assumptions made by the Transmission Network Service Provider conducting a SENE Design and Costing Study about the likely timing and capacity of future connections of generating systems in the geographic area relevant to the study and the probability of that capacity materialising.
Scale Efficient Network Extension means an augmentation to a transmission network which is capable of facilitating the future connection to the transmission network of two or more generating systems in the same geographic area that have different owners, operators or controllers.
SENE Design and Costing Study means a study undertaken by a Transmission Network Service Provider in accordance with this rule 5.19 which compares the cost of forecast connections of generating systems to a transmission network augmented by a Scale Efficient Network Extension and the cost of those forecast connections connecting to the national grid in the same geographic area in the absence of the Scale Efficient Network Extension.
SENE Study Proponent means a person that makes a request under clause 5.19.2(a).
SENE study information means:
(a)	any data or information provided to a Transmission Network Service Provider by a Network Service Provider under clause 5.19.5 for the purposes of a SENE Design and Costing Study;
(b)	any data or information provided to a Transmission Network Service Provider by a person for the purposes of a SENE Design and Costing Study, provided that the person has registered its interest in response to an invitation under clause 5.19.3(e)(3); and
(c)	any data or information contained in a SENE Design and Costing Study published under clause 5.19.6.
5.19.2	Interpretation
In this rule 5.19:
(a)	a reference to a Transmission Network Service Provider does not include a Distribution Network Service Provider in its capacity as owner, controller or operator of a dual function asset; and
(b)	a reference to a transmission network does not include dual function assets.
5.19.3	Request for SENE Design and Costing Study
(a)	Any person may request a Transmission Network Service Provider to undertake a SENE Design and Costing Study in relation to the construction of a Scale Efficient Network Extension for connection to its transmission network.
(b)	If the Transmission Network Service Provider receives a request under paragraph (a), the Transmission Network Service Provider must undertake a SENE Design and Costing Study if the following conditions are satisfied:
(1)	at the time the study is requested, the Transmission Network Service Provider is not undertaking another SENE Design and Costing Study in relation to the same geographic area;
(2)	it has agreed the scope and timing of the SENE Design and Costing Study with the SENE Study Proponent in accordance with paragraph (c); and
(3)	the SENE Study Proponent or any other person or group of persons (which may include the SENE Study Proponent) has agreed to pay all the reasonable costs incurred by the Transmission Network Service Provider in undertaking the study, including any costs it incurs in meeting its obligation under clause 5.19.5(b).
(c)	The Transmission Network Service Provider:
(1)	must in accordance with clause 5.19.4, negotiate with the SENE Study Proponent in good faith to reach agreement on the cost, scope and timeframes for undertaking the SENE Design and Costing Study; and
(2)	without limiting subparagraph (1), must not unreasonably withhold its consent to undertake a SENE Design and Costing Study in accordance with the scope and timeframes for the study proposed by the SENE Study Proponent.
(d)	The Transmission Network Service Provider must undertake the SENE Design and Costing Study in accordance with the agreement reached with the SENE Study Proponent under paragraph (c).
(e)	As soon as practicable after the conditions referred to in paragraph (b) are satisfied in relation to a SENE Design and Costing Study, the relevant Transmission Network Service Provider must publish on its website a notice of the commencement of the study. A notice under this paragraph (e) must:
(1)	specify the geographic area that is being considered in the study;
(2)	specify the dates agreed between the Transmission Network Service Provider and the SENE Study Proponent for completion of the study and any other milestones for the study;
(3)	invite any person who may be interested in providing SENE study information to the Transmission Network Service Provider to register their interest by written notice to the Transmission Network Service Provider within a period specified in the notice, being a period not less than 10 business days from the date the notice is published; and
(4)	include a statement to the effect that by registering with the Transmission Network Service Provider in accordance with subparagraph (3), the person is giving consent to the use and disclosure of the SENE study information subsequently provided by that person in accordance with clause 5.19.7.
5.19.4	Content of SENE Design and Costing Study
In negotiating the scope of the SENE Design and Costing Study with the SENE Study Proponent under clause 5.19.3(c), the Transmission Network Service Provider must consider the following matters:
(a)	the construction of future generating systems and the capacity of those generating systems in the relevant geographic area that are considered likely to require connection to the national grid, based on forecast generation scenarios;
(b)	having regard to each forecast generation scenario:
(1)	the most appropriate location of the point of connection of the Scale Efficient Network Extension to the present transmission network;
(2)	the configuration of the Scale Efficient Network Extension including the point at which generating systems may connect to the Scale Efficient Network Extension;
(3)	the capacity and technical specifications of the Scale Efficient Network Extension;
(4)	indicative development, operating and other costs for the Scale Efficient Network Extension, based on an indicative timetable for development of the Scale Efficient Network Extension;
(5)	opportunities for developing the Scale Efficient Network Extension incrementally;
(6)	the likely impact of the Scale Efficient Network Extension on its transmission network, including the type and estimated cost of any other augmentation that would be required to ensure that the Scale Efficient Network Extension did not increase congestion on its transmission network;
(7)	a comparison between:
(i)	the estimated total project expenditure (excluding any revenue impact) of forecast connections of generating systems to the Transmission Network Service Provider's network as augmented by a Scale Efficient Network Extension; and
(ii)	the estimated total project expenditure (excluding any revenue impact) of forecast connections of generating systems to the Transmission Network Service Provider's network, or, if different, the Local Network Service Provider's network, in the same geographic area in the absence of the Scale Efficient Network Extension; and
(c)	the most recent Integrated System Plan and the Transmission Network Service Provider's most recent Transmission Annual Planning Report (to the extent relevant).
5.19.5	Co-operation of other Network Service Providers
(a)	A Network Service Provider must co-operate with any Transmission Network Service Provider that is undertaking a SENE Design and Costing Study to enable that Transmission Network Service Provider to undertake the study expeditiously and consider the matters referred to in clause 5.19.4.
(b)	A Transmission Network Service Provider may request data or information (including confidential information) or assistance from another Network Service Provider for the purposes of undertaking a SENE Design and Costing Study but must meet the reasonable costs of the Network Service Provider in complying with the request.
(c)	A Network Service Provider may, but is not required to, provide such data, information or assistance as requested under paragraph (b). If a Network Service Provider provides such information or data it must identify any information or data that is confidential information.
5.19.6	Publication of SENE Design and Costing Study report
As soon as practicable after the SENE Design and Costing Study is completed, the Transmission Network Service Provider that undertook the study must publish on its website a report of the study that includes:
(a)	a description of the scope of the SENE Design and Costing Study;
(b)	a description of the Scale Efficient Network Extension for each forecast generation scenario considered in the study, including its configuration;
(c)	any assumptions made as part of the study;
(d)	a summary of the key matters considered as part of the SENE Design and Costing Study; and
(e)	the study's conclusions as well as an explanation of the reasoning which underlies those conclusions.
5.19.7	Provision and use of information
(a)	The SENE study information must:
(1)	be prepared, given and used in good faith; and
(2)	not be disclosed or made available by the relevant Transmission Network Service Provider to a third party except as set out in this clause 5.19.7 or in accordance with rule 8.6 as if it were confidential information for the purposes of that rule.
(b)	A Transmission Network Service Provider conducting a SENE Design and Costing Study may disclose SENE study information to another Network Service Provider if the relevant Transmission Network Service Provider considers the data or information is materially relevant to that provider for the purposes of providing information or assistance under clause 5.19.5.
(c)	If a Transmission Network Service Provider intends to disclose information under paragraph (b), it must first advise the relevant information provider of the extent of the disclosure, unless the information may be disclosed in accordance with rule 8.6.
(d)	A Transmission Network Service Provider may:
(1)	use SENE study information to prepare the relevant SENE Design and Costing Study or any future SENE Design and Costing Study; and
(2)	subject to paragraph (e), include SENE study information in a report published under clause 5.19.6.
(e)	A Transmission Network Service Provider must not include in a report published under clause 5.19.6, SENE study information which the relevant Network Service Provider has identified as confidential information under clause 5.19.5(c).
5.20	System security reports
5.20.1	Definitions
In this rule 5.20:
NSCAS description means a detailed description of each type of network support and control ancillary service.
NSCAS quantity procedure means a procedure that determines the location and quantity of each type of network support and control ancillary service required.
NSCAS trigger date means for any NSCAS gap identified in clause 5.20.3(b), the date that the NSCAS gap first arises.
NSCAS tender date means for any NSCAS gap identified in clause 5.20.3(c), the date or indicative date that AEMO would need to act so as to call for offers to acquire NSCAS to meet that NSCAS gap by the relevant NSCAS trigger date in accordance with clause 3.11.3(c)(4).
5.20.2	Publication of NSCAS methodology
(a)	AEMO must develop and publish the NSCAS description and NSCAS quantity procedure in accordance with the Rules consultation procedures.
(b)	AEMO may amend the NSCAS description and the NSCAS quantity procedure.
(c)	AEMO must comply with the Rules consultation procedures when making or amending the NSCAS description or the NSCAS quantity procedure.
(d)	AEMO may make minor and administrative amendments to the NSCAS description or the NSCAS quantity procedure without complying with the Rules consultation procedures.
5.20.3	Publication of NSCAS Report
AEMO must publish annually the NSCAS Report on its website for the following year which must include:
(a)	an assessment that identifies any NSCAS gap;
(b)	for any NSCAS gap identified in subparagraph (a) required to maintain power system security and reliability of supply of the transmission network in accordance with the power system security standards and the reliability standard, the relevant NSCAS trigger date;
(c)	for any NSCAS gap identified in subparagraph (a) required to maintain power system security and reliability of supply of the transmission network in accordance with the power system security standards and the reliability standard, the relevant NSCAS tender date;
(d)	a report on NSCAS acquired by AEMO under ancillary services agreements in the previous calendar year; and
(e)	information on any other matter that AEMO considers relevant.
5.20.4	Inertia requirements methodology
(a)	AEMO must develop and publish the inertia requirements methodology in accordance with the Rules consultation procedures.
(b)	AEMO may amend the inertia requirements methodology.
(c)	AEMO must comply with the Rules consultation procedures when making or amending the inertia requirements methodology.
(d)	AEMO may make minor and administrative amendments to the inertia requirements methodology without complying with the Rules consultation procedures.
(e)	The inertia requirements methodology determined by AEMO must provide for AEMO to take the following matters into account in determining the secure operating level of inertia:
(1)	the capabilities and expected response times provided by generating units providing market ancillary services (other than the regulating raise service or regulating lower service) in the inertia sub-network;
(2)	the maximum load shedding or generation shedding expected to occur on the occurrence of any credible contingency event affecting the inertia sub-network when the inertia sub-network is islanded;
(3)	additional inertia needed to account for the possibility of a reduction in inertia if the contingency event that occurs is the loss or unavailability of a synchronous generating unit, synchronous condenser or any other facility or service that is material in determining inertia requirements;
(4)	any constraints that could reasonably be applied to the inertia sub-network when islanded to achieve a secure operating state and any unserved energy that might result from the constraints; and
(5)	any other matters as AEMO considers appropriate.
5.20.5	Publication of Inertia Report
(a)	AEMO must publish annually the Inertia Report on its website for the following year which must include:
(1)	the boundaries of the inertia sub-networks and related inertia requirements determined by AEMO under rule 5.20B since the last Inertia Report and details of AEMO's assessment of any inertia shortfall and AEMO's forecast of any inertia shortfall arising at any time within a planning horizon of at least 5 years;
(2)	a report on the inertia requirements determined for each inertia sub-network together with the results of AEMO's assessment under clause 5.20B.3; and
(3)	information on any other matter that AEMO considers relevant.
5.20.6	Publication of system strength requirements methodologies
(a)	AEMO must develop and publish the system strength requirements methodology in accordance with the Rules consultation procedures.
(b)	AEMO may amend the system strength requirements methodology.
(c)	AEMO must comply with the Rules consultation procedures when making or amending the system strength requirements methodology.
(d)	AEMO may make minor and administrative amendments to the system strength requirements methodology without complying with the Rules consultation procedures.
(e)	The system strength requirements methodology determined by AEMO must provide for AEMO to take the following matters into account in determining the fault level nodes and the minimum three phase fault level:
(1)	the combination of three phase fault levels at each fault level node in the region that could reasonably be considered to be sufficient for the power system to be in a secure operating state;
(2)	the maximum load shedding or generation shedding expected to occur on the occurrence of any credible contingency event or protected event affecting the region;
(3)	the stability of the region following any credible contingency event or protected event;
(4)	the risk of cascading outages as a result of any load shedding or generating system or market network service facility tripping as a result of a credible contingency event or protected event in the region;
(5)	additional contribution to the three phase fault level needed to account for the possibility of a reduction in the three phase fault level at a fault level node if the contingency event that occurs is the loss or unavailability of a synchronous generating unit or any other facility or service that is material in determining the three phase fault level at the fault level node;
(6)	the stability of any equipment that is materially contributing to the three phase fault level or inertia within the region; and
(7)	any other matters as AEMO considers appropriate.
5.20.7	Publication of System Strength Report
AEMO must publish annually the System Strength Report on its website for the following year which must include:
(a)	a description of the system strength requirements determined by AEMO under rule 5.20C since the last System Strength Report and details of AEMO's assessment of any fault level shortfall and AEMO's forecast of any fault level shortfall arising at any time within a planning of at least 5 years;
(b)	the system strength requirements determined for each region together with the results of its assessment under clause 5.20C.2; and
(c)	information on any other matter that AEMO considers relevant.
5.20A	Frequency management planning
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.
5.20A.1	Power system frequency risk review
(a)	AEMO must, through a power system frequency risk review under this rule, review:
(1)	non-credible contingency events the occurrence of which AEMO expects would be likely to involve uncontrolled increases or decreases in frequency (alone or in combination) leading to cascading outages, or major supply disruptions;
(2)	current arrangements for management of the non-credible contingency events described in sub-paragraph (1); and
(3)	options for future management of those events.
(b)	The options referred to in subparagraph (a)(3) may include:
(1)	new or modified emergency frequency control schemes;
(2)	declaration of the event as a protected event;
(3)	network augmentation; and
(4)	non-network alternatives to augmentation.
(c)	A power system frequency risk review must:
(1)	identify non-credible contingency events referred to in paragraph (a) that AEMO considers should be priorities for assessment having regard to:
(i)	the likely power system security outcomes if the event occurs;
(ii)	the likelihood of the event occurring;
(iii)	whether in AEMO's opinion there are reasonably likely to be options for management of the event that are technically feasible, and (on the basis of AEMO's preliminary assessment of the estimated costs and benefits of that option) are economically feasible; and
(iv)	other factors that AEMO considers relevant;
(2)	for events identified under subparagraph (1):
(i)	assess options for future management of the event that are technically and economically feasible;
(ii)	assess the expected costs and time for implementation of each option and any other factors that AEMO considers should be taken into account in selecting a recommended option; and
(iii)	identify the recommended option or range of options;
(3)	for current protected events:
(i)	assess the adequacy and costs of the arrangements for management of the event;
(ii)	consider whether to recommend a request to the Reliability Panel to revoke the declaration of the event as a protected event; and
(iii)	except where a recommendation is to be made under subparagraph (ii), identify any need for changes to the arrangements for management of the event and where applicable, identify the options for change and in relation to each option, the matters referred to in subparagraphs (2)(ii) and (iii); and
(4)	assess the performance of existing emergency frequency control schemes and identify any need to modify the scheme.
5.20A.2	Power system frequency risk review process
(a)	AEMO must undertake a power system frequency risk review at least every two years.
(b)	AEMO must put in place arrangements it considers appropriate to consult with and take into account the views of Transmission Network Service Providers in the conduct of a power system frequency risk review.
(c)	Where AEMO is considering a new or modified emergency frequency control scheme, AEMO must consult with Distribution Network Service Providers whose distribution system is likely to be directly affected by the scheme.
(d)	When undertaking a power system frequency risk review, AEMO may consult with any other parties it considers appropriate, including without limitation, Jurisdictional System Security Coordinators.
5.20A.3	Power system frequency risk review report
(a)	On completion of a power system frequency risk review, AEMO must publish a draft report setting out its findings and recommendations on the matters set out in clause 5.20A.1, and invite written submissions to be made within a period of at least 10 business days specified in the invitation. AEMO must publish its final report as soon as reasonably practicable following the receipt of submissions.
(b)	Where a power system frequency risk review identifies the need for a new or modified emergency frequency control scheme (alone or in combination with the declaration of a protected event) the report under this clause must:
(1)	specify the areas of the power system to which the emergency frequency control scheme will apply and whether it is an over frequency scheme, under frequency scheme, or both; and
(2)	include the anticipated time required to design, procure and commission the new or modified scheme.
(c)	Where, as the result of a power system frequency risk review, AEMO recommends seeking declaration or revocation of a non-credible contingency event as a protected event, the report under this clause must include the proposed timetable for submission of a request to the Reliability Panel under clause 5.20A.4 or clause 5.20A.5 (as applicable).
5.20A.4	Request for protected event declaration
(a)	AEMO must develop and submit to the Reliability Panel a request for declaration of a non-credible contingency event as a protected event in accordance with the recommendations of a power system frequency risk review and taking into account any guidelines issued by the Reliability Panel under clause 8.8.1(a)(2d) as to the timing and content of requests under this clause.
(b)	A request under this clause must include:
(1)	information explaining the nature and likelihood of the non-credible contingency event and the consequences for the power system if the event were to occur including AEMO's estimate of unserved energy;
(2)	options for managing the non-credible contingency event as a protected event, AEMO's recommended option or range of options and the rationale for the recommendation;
(3)	for each recommended option under subparagraph (2), AEMO's estimate of the additional costs to operate the power system in accordance with the power system security principles in clause 4.2.6 if the event is declared to be a protected event including a description of the mechanisms that may be used;
(4)	where a recommended option for managing the non-credible contingency event includes a new or modified emergency frequency control scheme:
(i)	the target capabilities proposed to be included in the protected event EFCS standard for the scheme, the rationale for the proposed target capabilities and the corresponding expected power system security outcomes including AEMO's estimate of unserved energy associated with operation of the scheme; and
(ii)	AEMO's estimate of the costs to procure and commission the scheme and maintain its availability and performance, including upfront costs and ongoing maintenance costs;
(5)	AEMO's proposals for other matters that may be determined by the Reliability Panel under clause 8.8.4 in connection with the request; and
(6)	other information AEMO considers reasonably necessary to assist the Reliability Panel to consider the request.
5.20A.5	Request to revoke a protected event declaration
(a)	If AEMO recommends in a power system frequency risk review that a non-credible contingency event should no longer be managed as a protected event, AEMO must submit to the Reliability Panel a request to revoke the declaration of a non-credible contingency event as a protected event in accordance with the recommendations of the power system frequency risk review.
(b)	A request under this clause must include:
(1)	information explaining the nature of the non-credible contingency event and the consequences for the power system if the event were to cease to be managed as a protected event; and
(2)	other information AEMO considers reasonably necessary to assist the Reliability Panel to consider the request.
5.20B	Inertia sub-networks and requirements
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.
5.20B.1	Boundaries of inertia sub-networks
(a)	For the purpose of determining the required levels of inertia in the national grid, the connected transmission systems forming part of the national grid are to be divided into inertia sub-networks.
(b)	AEMO must determine the boundaries of inertia sub-networks and may from time to time adjust the boundaries, including adjustments that result in new inertia sub-networks.
(c)	The boundaries of an inertia sub-network must be aligned with the boundaries of a region or wholly confined within a region.
(d)	Subject to paragraph (c), in determining and adjusting the boundaries of inertia sub-networks, AEMO must take into account the following matters:
(1)	synchronous connections between the proposed inertia sub-network and adjacent parts of the national grid;
(2)	the likelihood of the proposed inertia sub-network being islanded; and
(3)	the criticality and practicality of maintaining the proposed inertia sub-network in a satisfactory operating state if it is islanded and being able to return to a secure operating state while islanded.
(e)	In determining and adjusting the boundaries of inertia sub-networks, AEMO must comply with the Rules consultation procedures.
(f)	AEMO must publish the boundaries of the inertia sub-networks and any adjustments in the Inertia Report.
5.20B.2	Inertia requirements
(a)	AEMO must from time to time determine the inertia requirements for inertia sub-networks applying the inertia requirements methodology. AEMO must make a determination under this paragraph:
(1)	subject to subparagraph (2) and any other requirements under the Rules, for any inertia sub-network, no more than once in every 12 month period; and
(2)	for each affected inertia sub-network, as soon as reasonably practical after becoming aware of a material change to the power system likely to affect the inertia requirements for the inertia sub-network where the timing, occurrence or impact of the change was unforeseen.
(b)	The inertia requirements to be determined for each inertia sub-network are:
(1)	the minimum threshold level of inertia, being the minimum level of inertia required to operate the inertia sub-network in a satisfactory operating state when the inertia sub-network is islanded; and
(2)	the secure operating level of inertia, being the minimum level of inertia required to operate the inertia sub-network in a secure operating state when the inertia sub-network is islanded.
(c)	AEMO must publish the inertia requirements determined for each inertia sub-network together with the results of its assessment under clause 5.20B.3 in the Inertia Report.
5.20B.3	Inertia shortfalls
(a)	AEMO must as soon as practicable following its determination of the inertia requirements for an inertia sub-network under clause 5.20B.2 assess:
(1)	the level of inertia typically provided in the inertia sub-network having regard to typical patterns of dispatched generation in central dispatch;
(2)	whether in AEMO's reasonable opinion, there is or is likely to be an inertia shortfall in the inertia sub-network and AEMO's forecast of the period over which the inertia shortfall will exist; and
(3)	where AEMO has previously assessed that there was or was likely to be an inertia shortfall, whether in AEMO's reasonable opinion that inertia shortfall has been or will be remedied.
(b)	In making its assessment under paragraph (a) for an inertia sub-network, AEMO must take into account:
(1)	over what time period and to what extent the inertia that is typically provided in the inertia sub-network is or is likely to be below the secure operating level of inertia;
(2)	the levels of inertia that are typically provided in adjacent connected inertia sub-networks and the likelihood of the inertia sub-network becoming islanded; and
(3)	any other matters that AEMO reasonably considers to be relevant in making its assessment.
(c)	If AEMO assesses that there is or is likely to be an inertia shortfall in any inertia sub-network, AEMO must publish and give to the Inertia Service Provider for the inertia sub-network a notice of that assessment that includes AEMO's specification of the date by which the Inertia Service Provider must ensure the availability of inertia network services in accordance with clause 5.20B.4(b), which must not be earlier than 12 months after the notice is published unless an earlier date is agreed with the Inertia Service Provider.
(d)	If AEMO assesses that an inertia shortfall in an inertia sub-network has been or will be remedied, AEMO must publish and give to the Inertia Service Provider for the inertia sub-network a notice of that assessment that includes AEMO's specification of the date from which the obligation of the Inertia Service Provider under clause 5.20B.4(b) ceases, which must not be earlier than 12 months after the notice is published unless an earlier date is agreed with the Inertia Service Provider.
5.20B.4	Inertia Service Provider to make available inertia services
(a)	The Inertia Service Provider for an inertia sub-network is:
(1)	the Transmission Network Service Provider for the inertia sub-network; or
(2)	if there is more than one Transmission Network Service Provider for the inertia sub-network, the jurisdictional planning body for the participating jurisdiction in which the inertia sub-network is located.
(b)	If AEMO gives a notice under clause 5.20B.3(c) that AEMO has assessed that there is or is likely to be an inertia shortfall in an inertia sub-network, the Inertia Service Provider for the inertia sub-network must make inertia network services available in accordance with paragraph (c) that when enabled will provide inertia to:
(1)	the secure operating level of inertia; or
(2)	the secure operating level of inertia as adjusted for inertia support activities, but not less than the minimum threshold level of inertia as adjusted for inertia support activities.
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.)
(c)	For the purposes of paragraph (b), an Inertia Service Provider for an inertia sub-network must:
(1)	use reasonable endeavours to make the inertia network services available by the date specified by AEMO in the notice under clause 5.20B.3(c);
(2)	make a range and level of inertia network services available such that it is reasonably likely that inertia network services that provide the required level of inertia when enabled are continuously available, taking into account planned outages and the risk of unplanned outages;
(3)	ensure that the inertia network services that when enabled provide inertia up to the minimum threshold level of inertia (as adjusted for inertia support activities if applicable) are qualifying inertia network services as specified in paragraph (d);
(4)	ensure that the inertia network services that when enabled provide inertia beyond the minimum threshold level of inertia up to the secure operating level of inertia (as adjusted for inertia support activities if applicable), are qualifying inertia network services as specified in paragraph (e); and
(5)	maintain the availability of those inertia network services until the date the Inertia Service Provider's obligation ceases, as specified by AEMO under clause 5.20B.3(d).
(d)	The inertia network services that qualify to provide inertia up to the minimum threshold level of inertia are:
(1)	inertia network services made available by the Inertia Service Provider investing in its network through the installation, commissioning and operation of a synchronous condensor; and
(2)	inertia network services made available to the Inertia Service Provider by a Registered Participant and provided by means of a synchronous generating unit or a synchronous condensor under an inertia services agreement.
(e)	The inertia network services that qualify to provide inertia beyond the minimum threshold level of inertia up to the secure operating level of inertia are:
(1)	the inertia network services referred to in paragraph (d);
(2)	inertia network services made available by the Inertia Service Provider investing in its network other than those referred to in paragraph (d); and
(3)	inertia network services made available to the Inertia Service Provider by a Registered Participant under an inertia services agreement other than those referred to in paragraph (d).
(f)	An Inertia Service Provider required to make inertia network services available under paragraph (b) must make available the least cost option or combination of options that will satisfy its obligation within the time referred to in subparagraph (c)(1) and for so long as the obligation to make the inertia network services available continues.
(g)	An Inertia Service Provider required to make inertia network services available under paragraph (b) must prepare and publish information to enable potential providers of inertia network services to develop non-network options for consideration by the Inertia Service Provider including:
(1)	a description of the requirement for inertia network services including timing;
(2)	the technical characteristics that a non-network option would be required to deliver, such as the level of inertia, location, availability, response time and operating profile;
(3)	a summary of potential options to make the inertia network services available identified by the Inertia Service Provider, including network options and non-network options; and
(4)	information to assist providers of non-network options wishing to present proposals to the Inertia Service Provider including details of how to submit a proposal for consideration.
(h)	An Inertia Service Provider must provide information in its Transmission Annual Planning Report about:
(1)	the activities undertaken to satisfy its obligation to make  inertia network services available under paragraph (b); and
(2)	inertia support activities undertaken to reduce the minimum threshold level of inertia or the secure operating level of inertia.
(i)	If the Inertia Service Provider proposes network investment for either of the purposes specified in paragraph (h), the Inertia Service Provider must provide the following information in its next Transmission Annual Planning Report:
(1)	the date when the proposed relevant network investment became or will become operational;
(2)	the purpose of the proposed relevant network investment;
(3)	the total cost of the proposed relevant network investment; and
(4)	the indicative total cost of any non-network options considered.
(j)	An Inertia Service Provider may include the cost of inertia service payments in the calculation of network support payments in accordance with Chapter 6A.
5.20B.5	Inertia support activities
(a)	AEMO may at the request of an Inertia Service Provider approve activities (inertia support activities) under this clause and agree corresponding adjustments to the minimum threshold level of inertia or the secure operating level of inertia for the purposes of clause 5.20B.4(b) where the activities:
(1)	are to be undertaken by the Inertia Service Provider or provided as a service to the Inertia Service Provider;
(2)	are not inertia network services; and
(3)	AEMO is satisfied the activities will contribute to the operation of the inertia sub-network in a satisfactory operating state or secure operating state in the circumstances described in clause 4.4.4(a) or (b) as applicable.
Note
If approved by AEMO under paragraph (a), inertia support activities may include installing or contracting for the provision of frequency control services, installing emergency protection schemes or contracting with Generators in relation to the operation of their generating units in specified conditions.
(b)	An adjustment to the minimum threshold level of inertia or the secure operating level of inertia for inertia support activities will apply to the level determined by AEMO and only where and to the extent that the approved activity is enabled and performing in accordance with the conditions of any approval determined by AEMO.
(c)	An Inertia Service Provider making a request under paragraph (a) must give AEMO:
(1)	details of the proposed inertia support activity and the other information about the inertia support activity consistent with the requirements of clause 5.20B.6(c);
(2)	the proposed technical specification and performance standards and the information about arrangements to enable the inertia support activity consistent with the requirements of clause 5.20B.6(d);
(3)	information about how the inertia support activity will contribute to operation of the inertia sub-network in a satisfactory operating state or secure operating state in the circumstances described in clause 4.4.4(a) or (b) as applicable;
(4)	the Inertia Service Provider's proposal for calculating adjustments to be made and the times they will apply; and
(5)	any other information requested by AEMO in connection with the request.
(d)	AEMO may give or withhold its approval under this clause in its discretion and subject to any conditions determined by AEMO.
(e)	The technical specification, performance standards and information referred to in paragraph (c)(2) and any change to them must be approved by AEMO.
(f)	An Inertia Service Provider must obtain AEMO's approval under paragraph (e) before any change to the technical specification, performance standards or arrangements to give instructions that apply to an inertia support activity comes into effect.
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.)
5.20B.6	Inertia network services information and approvals
(a)	An Inertia Service Provider required to make inertia network services available under clause 5.20B.4(b) must prepare and give to AEMO and keep up to date, a schedule setting out:
(1)	the inertia network services made available by the Inertia Service Provider for the inertia sub-network; and
(2)	the Inertia Service Provider's proposed order of priority for the inertia network services to be enabled.
(b)	Where the Inertia Service Provider procures inertia network services from a Generator provided by means of a synchronous generating unit under an inertia services agreement, the Inertia Service Provider must register the generating unit with AEMO as an inertia generating unit and specify that the generating unit may be periodically used to provide inertia network services and will not be eligible to set spot prices when constrained on to provide inertia in accordance with clause 3.9.7(c).
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.)
(c)	An Inertia Service Provider required to make inertia network services available under clause 5.20B.4(b) must give to AEMO and keep up to date the following details for each inertia network service:
(1)	a description of the inertia network service, including:
(i)	the nature of the inertia network service;
(ii)	the generating unit or other facilities used to provide the inertia network service;
(iii)	the purpose for which the inertia network service is being provided;
(iv)	the location in the transmission network or distribution network of the facilities used to provide the inertia network service;
(v)	the quantity of inertia to be provided when the inertia network service is enabled and;
(vi)	any other information requested by AEMO in connection with the inertia network service;
(2)	information about the availability of the inertia network service, including:
(i)	the times when, and the period over which, the inertia network service will be available to provide inertia; and
(ii)	any possible restrictions on the availability of the inertia network service
(d)	An Inertia Service Provider required to make inertia network services available under clause 5.20B.4(b) must prepare and submit to AEMO for approval under paragraph (e) the following details for each inertia network service:
(1)	the technical specification and performance standards for the inertia network service; and
(2)	the arrangements necessary for AEMO to give instructions to enable or cease the provision of the inertia network service including:
(i)	the period of any notice that has to be given to the provider of the inertia network service for it to be enabled;
(ii)	the response time to any instruction for the inertia network service to be enabled or to cease being provided; and
(iii)	communication protocols between it, AEMO and the Registered Participants that provide inertia network services.
(e)	The technical specification. performance standards and arrangements necessary for AEMO to give the instructions referred to in paragraph (d) and any change to them must be consistent with the Rules and approved by AEMO.
(f)	An Inertia Service Provider must ensure that AEMO's approval is obtained under paragraph (e) before the inertia network service is first made available and in the case of a change, before the change comes into effect.
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.)
(g)	AEMO must use reasonable endeavours to respond to the Inertia Service Provider within 20 business days following the receipt of a request for approval under paragraph (e) stating whether it gives its approval.
(h)	If AEMO does not approve the matters in a request for approval under paragraph (e):
(1)	AEMO must tell the Inertia Service Provider its reasons for withholding approval and may advise the Inertia Service Provider of the changes AEMO requires to be made; and
(2)	the Inertia Service Provider must amend its request to address the matters identified by AEMO and submit to AEMO a new request for approval.
5.20C	System strength requirements
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.
5.20C.1	System strength requirements
(a)	AEMO must from time to time determine the system strength requirements for each region applying the system strength requirements methodology. AEMO must make a determination under this paragraph:
(1)	subject to subparagraph (2) and any other requirements under the Rules, for any region, no more than once in every 12 month period; and
(2)	for each affected region, as soon as reasonably practical after becoming aware of a material change to the power system likely to affect the system strength requirements for the region where the timing, occurrence or impact of the change was unforeseen.
(b)	The system strength requirements to be determined for each region are:
(1)	the fault level nodes in the region, being the location on the transmission network for which the three phase fault level must be maintained at or above a minimum three phase fault level determined by AEMO; and
(2)	for each fault level node, the minimum three phase fault level.
(c)	AEMO must publish the system strength requirements determined for each region together with the results of its assessment under clause 5.20C.2 in the System Strength Report.
5.20C.2	Fault level shortfalls
(a)	AEMO must as soon as practicable following its determination of the system strength requirements for a region under clause 5.20C.1 assess:
(1)	the three phase fault level typically provided at each fault level node in the region having regard to typical patterns of dispatched generation in central dispatch;
(2)	whether in AEMO's reasonable opinion, there is or is likely to be a fault level shortfall in the region and AEMO's forecast of the period over which the fault level shortfall will exist; and
(3)	where AEMO has previously assessed that there was or was likely to be a fault level shortfall, whether in AEMO's reasonable opinion that fault level shortfall has been or will be remedied.
(b)	In making its assessment under paragraph (a) for a region, AEMO must take into account:
(1)	over what time period and to what extent the three phase fault levels at fault level nodes that are typically observed in the region are likely to be insufficient to maintain the power system in a secure operating state; and
(2)	any other matters that AEMO reasonably considers to be relevant in making its assessment.
(c)	If AEMO assesses that there is or is likely to be a fault level shortfall in a region, AEMO must publish and give to the System Strength Service Provider for the region a notice of that assessment that includes AEMO's specification of:
(1)	the extent of the fault level shortfall; and
(2)	the date by which the System Strength Service Provider must ensure the availability of system strength services in accordance with clause 5.20C.3(b), which must not be earlier than 12 months after the notice is published unless an earlier date is agreed with the System Strength Service Provider.
(d)	If AEMO assesses that a fault level shortfall in a region has been or will be remedied, AEMO must publish and give to the System Strength Service Provider for the region a notice of that assessment that includes AEMO's specification of the date from which the obligation of the System Strength Service Provider under clause 5.20C.3(b) ceases, which must not be earlier than 12 months after the notice is published unless an earlier date is agreed with the System Strength Service Provider.
5.20C.3	System Strength Service Provider to make available system strength services
(a)	The System Strength Service Provider for a region is:
(1)	the Transmission Network Service Provider for the region; or
(2)	if there is more than one Transmission Network Service Provider for a region, the jurisdictional planning body for the participating jurisdiction in which the region is located
(b)	If AEMO gives a notice under clause 5.20C.2(c) that AEMO has assessed that there is or is likely to be a fault level shortfall at a fault level node in a region, the System Strength Service Provider for the region must make system strength services available in accordance with paragraph (c) that when enabled will address the fault level shortfall at the relevant fault level node.
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.)
(c)	For the purposes of paragraph (b), a System Strength Service Provider for a region must:
(1)	use reasonable endeavours to make the system strength services available by the date specified by AEMO in the notice under clause 5.20C.2(c);
(2)	make a range and level of system strength services available such that it is reasonably likely that system strength services that address the fault level shortfall when enabled are continuously available, taking into account planned outages, the risk of unplanned outages and the potential for the system strength services  to impact typical patterns of dispatched generation in central dispatch; and
(3)	maintain the availability of those system strength services until the date the System Strength Service Provider's obligation ceases, as specified by AEMO under clause 5.20C.2(d).
(d)	A System Strength Service Provider required to make system strength services available under paragraph (b) must make available the least cost option or combination of options that will satisfy its obligation within the time referred to in subparagraph (c)(1) and for so long as the obligation to make the system strength services available continues.
(e)	A System Strength Service Provider required to make system strength services available under paragraph (b) must prepare and publish information to enable potential providers of system strength services to develop non-network options for consideration by the System Strength Service Provider including:
(1)	a description of the requirement for system strength services including timing;
(2)	the technical characteristics that a non-network option would be required to deliver, such as the contribution to the three phase fault level, location, availability, response time and operating profile;
(3)	a summary of potential options to make the system strength services available identified by the System Strength Service Provider, including network options and non-network options; and
(4)	information to assist providers of non-network options wishing to present proposals to the System Strength Service Provider including details of how to submit a proposal for consideration.
(f)	A System Strength Service Provider must provide information in its Transmission Annual Planning Report about the activities undertaken to satisfy its obligation to make system strength services available under paragraph (b).
(g)	If the System Strength Service Provider proposes network investment for the purpose specified in paragraph (f), the System Strength Service Provider must provide the following information in its next Transmission Annual Planning Report:
(1)	the date when the proposed relevant network investment became or will become operational;
(2)	the purpose of the proposed relevant network investment;
(3)	the total cost of the proposed relevant network investment;
(4)	the indicative total costs of any non-network options considered.
(h)	A System Strength Service Provider may include the cost of system strength service payments in the calculation of network support payments in accordance with Chapter 6A.
5.20C.4	System strength services information and approvals
(a)	A System Strength Service Provider required to make system strength services available under clause 5.20C.3(b) must prepare and give to AEMO and keep up to date, a schedule setting out:
(1)	the system strength services available to contribute to the three phase fault level at each fault level node in the region for which there is a fault level shortfall; and
(2)	the System Strength Service Provider's proposed order of priority for the system strength services to be enabled.
(b)	Where the System Strength Service Provider procures system strength services from a Generator provided by means of a generating unit under a system strength services agreement, the System Strength Service Provider must register the generating unit with AEMO as a system strength generating unit and specify that the generating unit may be periodically used to provide system strength services and will not be eligible to set spot prices when constrained on to provide system strength services in accordance with clause 3.9.7(c).
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.)
(c)	A System Strength Service Provider required to make system strength services available under clause 5.20C.3(b) must give to AEMO and keep up to date the following details for each system strength service:
(1)	a description of the system strength service, including:
(i)	the nature of the system strength service;
(ii)	the generating unit or other facilities used to provide the system strength service;
(iii)	the purpose for which the system strength service is being provided;
(iv)	the location in the transmission network or distribution network of the facilities used to provide the system strength service;
(v)	the contribution to the three phase fault level at each relevant fault level node and the facility's connection point when the system strength service is enabled; and
(vi)	any other information (including models) requested by AEMO to assess the contribution of the system strength service referred to in subparagraph (v).
(2)	information about the availability of the system strength service, including:
(i)	the times when, and the period over which, the system strength service will be available to contribute to the three phase fault level at each relevant fault level node; and
(ii)	any possible restrictions on the availability of the system strength service.
(d)	A System Strength Service Provider required to make system strength services available under clause 5.20C.3(b) must prepare and submit to AEMO for approval under paragraph (e) the following details for each system strength service:
(1)	the technical specification and performance standards for the system strength service; and
(2)	the arrangements necessary for AEMO to give instructions to enable or cease the provision of the system strength service including:
(i)	the period of any notice that has to be given to the provider of the system strength service for it to be enabled;
(ii)	the response time to any instruction for the system strength service to be enabled or to cease being provided; and
(iii)	communication protocols between it, AEMO and the Registered Participants that provide system strength services.
(e)	The technical specification, performance standards and arrangements necessary for AEMO to give the instructions referred to in paragraph (d) and any change to them must be consistent with the Rules and approved by AEMO.
(f)	A System Strength Service Provider must ensure that AEMO's approval is obtained under paragraph (e) before the system strength service is first made available and in the case of a change, before the change comes into effect.
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.)
(g)	AEMO must use reasonable endeavours to respond to the System Strength Service Provider within 20 business days following the receipt of a request for approval under paragraph (e) stating whether it gives its approval.
(h)	If AEMO does not approve the matters in a request for approval under paragraph (e):
(1)	AEMO must tell the System Strength Service Provider its reasons for withholding approval and may advise the System Strength Service Provider of the changes AEMO requires to be made; and
(2)	the System Strength Service Provider must amend its request to address the matters identified by AEMO and submit to AEMO a new request for approval.
5.21	AEMO's obligation to publish information and guidelines and provide advice
Note
This rule has no effect in this jurisdiction (see regulation 5A of the National Electricity (Northern Territory) (National Uniform Legislation) (Modification) Regulations 2016).
(a)	This rule 5.21 does not apply to actionable ISP projects.
(a1)	In carrying out its NTP functions, AEMO must:
(1)	publish an objective set of criteria for assessing whether a proposed transmission network augmentation is reasonably likely to have a material inter-network impact; and
(2)	prepare and publish augmentation technical reports on proposed transmission network augmentations that are reasonably likely to have a material inter-network impact; and
(3)	publish guidelines to assist Registered Participants to determine when an inter-network test may be required.
(b)	AEMO must develop and publish, and may vary from time to time, an objective set of criteria for assessing whether a proposed transmission network augmentation is reasonably likely to have a material inter-network impact. In developing (or varying) the objective set of criteria, AEMO must:
(1)	proceed in accordance with the Rules consultation procedures; and
(2)	have regard to:
(i)	the relevant guiding objectives and principles provided by the AEMC; and
(ii)	the advice of jurisdictional planning representatives.
(c)	The AEMC must provide AEMO with guiding objectives and principles for the development by AEMO of the objective set of criteria for assessing whether or not a proposed transmission network augmentation is reasonably likely to have a material inter-network impact.
(d)	If AEMO receives a written request for an augmentation technical report on a proposed transmission network augmentation that is reasonably likely to have a material inter-network impact, or AEMO decides in the course of exercising its functions under Chapter 8, Part H, that a proposed transmission network augmentation is reasonably likely to have a material inter-network impact, AEMO must:
(1)	immediately undertake a review of all matters referred to it by the Transmission Network Service Provider in order to assess the proposed augmentation; and
(2)	consult with, and take into account the recommendations of, the jurisdictional planning representatives in relation to the proposed augmentation; and
(3)	make a determination as to:
(i)	the performance requirements for the equipment to be connected; and
(ii)	the extent and cost of augmentations and changes to all affected transmission networks; and
(iii)	the possible material effect of the new connection on the network power transfer capability including that of other transmission networks; and
(4)	within 90 business days of the date of the request or decision (or some other period agreed between the Transmission Network Service Provider and AEMO), AEMO must publish an augmentation technical report that sets out:
(i)	AEMO's determination; and
(ii)	the reasons for the determination (including a statement of any information and assumptions on which the determination is based).
A request for an augmentation technical report on a proposed transmission network augmentation must be accompanied by sufficient information to enable AEMO to make a proper assessment of the proposed augmentation and AEMO's reasonable fees covering the direct costs and expenses of preparing the report.
(e)	AEMO may, for the purpose of preparing an augmentation technical report, by written notice request a Transmission Network Service Provider to provide AEMO with additional information reasonably available to it and the Transmission Network Service Provider must comply with the request.
(f)	The period for AEMO to publish an augmentation technical report will be automatically extended by the time taken by the Transmission Network Service Provider to provide additional information requested by AEMO.
(g)	If the objective set of criteria developed and published under paragraph (b) is changed after a project assessment draft report has been made available to Registered Participants and AEMO, the relevant Transmission Network Service Provider is entitled to choose whether the new criteria, or the criteria that existed when the project assessment draft report was made available to Registered Participants and AEMO, are to be applied.
5.22	Integrated System Plan
5.22.1	Duty of AEMO to make Integrated System Plan
AEMO must publish an Integrated System Plan every two years by 30 June in accordance with the Rules.
5.22.2	Purpose of the ISP
The purpose of the Integrated System Plan is to establish a whole of system plan for the efficient development of the power system that achieves power system needs for a planning horizon of at least 20 years for the long term interests of the consumers of electricity.
5.22.3	Power system needs
(a)	The power system needs are:
(1)	the reliability standard;
(2)	power system security;
(3)	system standards; and
(4)	standards or technical requirements in Schedule 5.1 or in an applicable regulatory instrument.
(b)	In determining power system needs, as it relates to a NEM participating jurisdiction, AEMO may consider a current environmental or energy policy of that participating jurisdiction where that policy has been sufficiently developed to enable AEMO to identify the impacts of it on the power system and at least one of the following is satisfied:
(1)	a commitment has been made in an international agreement to implement that policy;
(2)	that policy has been enacted in legislation;
(3)	there is a regulatory obligation in relation to that policy;
(4)	there is material funding allocated to that policy in a budget of the relevant participating jurisdiction; or
(5)	the MCE has advised AEMO to incorporate the policy.
5.22.4	ISP timetable
(a)	AEMO must publish an ISP timetable within 3 months of the publication of the most recent Integrated System Plan published by AEMO.
(b)	This ISP timetable must set out the timing for the establishment of the ISP consumer panel and the dates of publication for the following matters:
(1)	the Inputs, Assumptions and Scenarios Report;
(2)	if AEMO is not using an existing ISP methodology, the ISP methodology;
(3)	the draft Integrated System Plan; and
(4)	the Integrated System Plan in accordance with clause 5.22.1.
(c)	The ISP timetable may include additional information that AEMO reasonably considers will assist stakeholders, including when information is to be provided or joint planning is to occur under clause 5.14.4.
(d)	AEMO must keep the ISP timetable updated.
(e)	AEMO may, from time to time, make and publish changes to the ISP timetable in which case it must provide a brief explanation for the change.
5.22.5	Guidelines relevant to the ISP
Cost Benefit Analysis Guidelines
(a)	The AER must make, publish and may amend the Cost Benefit Analysis Guidelines in accordance with the Rules consultation procedures.
(b)	The Cost Benefit Analysis Guidelines are to be used:
(1)	by AEMO to prepare an Integrated System Plan; and
(2)	by Transmission Network Service Providers in applying the regulatory investment test for transmission to actionable ISP projects.
(c)	The AER may specify the relevant parts of the Cost Benefit Analysis Guidelines that are binding on AEMO and RIT-T proponents.
Application of Cost Benefit Analysis Guidelines to AEMO for the ISP
(d)	The Cost Benefit Analysis Guidelines must in relation to the preparation of an Integrated System Plan by AEMO:
(1)	be consistent with the purposes of the Integrated System Plan referred to in clause 5.22.2;
(2)	require AEMO to test the robustness of alternative development paths to future uncertainties through the use of scenarios and sensitivities;
(3)	be capable of being applied in a predictable, transparent and consistent manner;
(4)	describe the objective that AEMO should seek to achieve when:
(i)	developing the counterfactual development path; and
(ii)	selecting a set of development paths for assessment;
(5)	describe the framework used to select the optimal development path, including the assessment of the costs and benefits of various development paths across different scenarios; and
(6)	set out how AEMO describes the identified need relating to an actionable ISP project.
Developing and publishing the Cost Benefit Analysis Guidelines
(e)	In developing and publishing the Cost Benefit Analysis Guidelines, the AER must:
(1)	recognise the risks to consumers arising from uncertainty, including over investment, under-investment, premature or overdue investment;
(2)	provide flexibility to AEMO in its approach to scenario development, modelling and selection of the optimal development path;
(3)	require the optimal development path to have a positive net benefit in the most likely scenario;
(4)	have regard to the need for alignment between the Integrated System Plan and the regulatory investment test for transmission as it applies to actionable ISP projects.
(f)	The AER may make minor or administrative amendments to the Cost Benefit Analysis Guidelines without complying with the Rules consultation procedures.
(g)	An amendment to the Cost Benefit Analysis Guidelines does not apply to a current application of the regulatory investment test for transmission for an actionable ISP project or a current process for the development of an Integrated System Plan.
(h)	For the purposes of paragraph (g), a "current application" means any action or process initiated under the Rules which relies on or is referenced to the Cost Benefit Analysis Guidelines and is not completed at the date of the relevant amendment to Cost Benefit Analysis Guidelines.
Forecasting Best Practice Guidelines
(i)	The AER must include in the Forecasting Best Practice Guidelines made under clause 4A.B.5 guidance for AEMO's forecasting practices and processes as they relate to an Integrated System Plan and the process (including consultation requirements) to be used for an ISP update.
(j)	The AER may specify parts of the Forecasting Best Practice Guidelines relevant to the Integrated System Plan that are binding on AEMO.
5.22.6	Content of Integrated System Plan
Contents of an Integrated System Plan
(a)	An Integrated System Plan must:
(1)	identify a range of development paths;
(2)	for each development path, identify the group of projects that form part of the development path;
(3)	describe how each development path performs under any sensitivities AEMO considers reasonable;
(4)	identify the optimal development path which must be based on a quantitative assessment of the costs and benefits of various options across a range of scenarios, in accordance with Cost Benefit Analysis Guidelines;
(5)	for the optimal development path, identify the actionable ISP projects, future ISP projects and ISP development opportunities;
(6)	for each actionable ISP project specify:
(i)	the date by which the project assessment draft report must be published and made available to relevant persons, which date must be:
(A)	at least 6 months after, and within 24 months of, the date of publication of the Integrated System Plan; and
(B)	based on the anticipated commencement date of the actionable ISP project;
(ii)	the relevant Transmission Network Services Providers who will be the RIT-T proponent for the actionable ISP project;
(iii)	the ISP candidate option or ISP candidate options;
(iv)	the non-network options that were considered by AEMO as part of the Integrated System Plan process in relation to that actionable ISP project (where relevant);
(v)	the identified need related to that actionable ISP project and whether it is reliability corrective action;
(vi)	whether the actionable ISP project is a staged project;
(7)	include the results of a net present value analysis for each development path for each scenario, together with an explanatory statement regarding the results.
(b)	An Integrated System Plan may:
(1)	include relevant information about ISP development opportunities;
(2)	identify and provide information on the optimal location and features of areas located in the NEM participating jurisdictions where large scale clusters of renewable energy and/or storage can be efficiently developed from a whole of power system perspective; and
(3)	include sensitivities showing the impacts of energy or environmental policies of a participating jurisdiction where AEMO has been requested to do so by that participating jurisdiction. These sensitivities are in addition to those sensitivities considered in clause 5.22.6(a)(3) and do not form part of any development path.
Preparatory activities
(c)	An Integrated System Plan may specify whether preparatory activities must be carried out by Transmission Network Service Providers for future ISP projects and the timeframes for carrying out preparatory activities.
(d)	A Transmission Network Service Provider must commence preparatory activities:
(1)	in the case of an actionable ISP project, as soon as practicable; and
(2)	in the case of a future ISP project, if the Integrated System Plan provides that preparatory activities must be undertaken for that project, in accordance with the timeframes specified in the Integrated System Plan for that project.
5.22.7	ISP consumer panel
(a)	In respect of the preparation of an Integrated System Plan, AEMO has the function of establishing and supporting a panel ("ISP consumer panel") to provide written reports to AEMO on:
(1)	the Inputs, Assumptions and Scenarios Report that will be used to prepare a draft Integrated System Plan; and
(2)	the draft Integrated System Plan,
(each a "consumer panel report").
(b)	The ISP consumer panel must consist of at least 3 members appointed by AEMO, who have qualifications or experience in a field AEMO considers relevant to the assessment of the Integrated System Plan and who have experience representing consumer interests.
(c)	Prior to appointing members to the ISP consumer panel, AEMO must publish an expression of interest for persons to apply to become a member. The expression of interest must include:
(1)	the terms of reference for the ISP consumer panel; and
(2)	information about the requisite qualifications and experience required to become a member.
(d)	The ISP consumer panel:
(1)	must, in accordance with the terms of reference, give a consumer panel report to AEMO within two months of AEMO publishing the Inputs, Assumptions and Scenarios Report and draft Integrated System Plan respectively;
(2)	must, in preparing the consumer panel report have regard to the long term interests of consumers; and
(3)	may carry out its activities, including the giving of a consumer panel report, in the way it considers appropriate but must seek to give the report by consensus.
(e)	A consumer panel must:
(1)	include the ISP consumer panel’s assessment of the evidence and reasons supporting the Inputs, Assumptions and Scenarios Report or draft Integrated System Plan respectively; and
(2)	state whether the report is given by consensus.
(f)	AEMO must publish a consumer panel report on its website.
(g)	AEMO must have regard to a consumer panel report but is not obliged to give effect to any recommendations in a consumer panel report.
5.22.8	Preliminary consultations
(a)	AEMO must, in accordance with the ISP timetable and the Forecasting Best Practice Guidelines, develop, consult and publish a report on the inputs, assumptions and scenarios to be used for the Integrated System Plan ("Inputs, Assumptions and Scenarios Report").
(b)	In developing the Inputs, Assumptions and Scenarios Report and ISP methodology, AEMO must:
(1)	make an invitation to make submissions as set out in a published notice within a specified timeframe of not less than 30 days from the date of the invitation;
(2)	must take into consideration the submissions received within the specified timeframe; and
(3)	publish an issues summary on material issues and AEMO's response to each issue.
(c)	The Input Assumptions and Scenarios Report may:
(1)	be included in a document that also provides for the assumptions and inputs to be used in preparing other AEMO publications, including a reliability forecast;
(2)	be consulted on as part of the same consultation process with relevant stakeholders in preparing other AEMO publications, including a reliability forecast; and
(3)	be updated for an Integrated System Plan process separately to the consultation process used in preparing a reliability forecast, in accordance with paragraph (b).
(d)	AEMO must, in accordance with the Forecasting Best Practice Guidelines, develop, consult and publish a cost benefits analysis and modelling methodology to be used for Integrated System Plan ("ISP methodology") which is consistent with the Cost Benefit Analysis Guidelines.
5.22.9	AER transparency review on Inputs, Assumptions and Scenarios Report
(a)	The AER, must within one month of the publication of the Inputs, Assumptions and Scenarios Report that will be used to prepare the draft Integrated System Plan, publish a report ("IASR review report") of its review as to the transparency of the Inputs, Assumptions and Scenarios Report, including whether:
(1)	AEMO has adequately explained how it has derived key inputs and assumptions and how key inputs and assumptions have changed since the previous Integrated System Plan; and
(2)	key inputs and assumptions have been based on verifiable sources, or that AEMO has provided stakeholders with adequate opportunity to propose alternative inputs and assumptions where verifiable sources are not readily available.
(b)	The AER is not required to consult on an IASR review report.
(c)	If the IASR review report identifies issues with the Inputs, Assumptions and Scenarios Report, AEMO must:
(1)	as soon as practicable, provide further explanatory information in an addendum to the Inputs, Assumptions and Scenarios Report; and
(2)	consult on the issues in the draft Integrated System Plan.
5.22.10	Preparation of ISP
ISP requirements
(a)	In preparing an Integrated System Plan, AEMO must:
(1)	comply with any requirements set out in the Cost Benefit Analysis Guidelines under clause 5.22.5(c);
(2)	comply with any requirements set out in the Forecasting Best Practice Guidelines under clause 5.22.5(j);
(3)	adopt the inputs and assumptions, material issues and scenarios identified in the Inputs, Assumptions and Scenarios Report, or provide reasons where AEMO has used updated information;
(4)	seek to deliver power system needs;
(5)	consider the following matters:
(i)	the efficient integration of ISP development opportunities;
(ii)	the risks to consumers arising from uncertainty, including over investment, under-investment, premature or overdue investment;
(iii)	fuel security;
(iv)	credible options (including non-network options);
(v)	outcomes of joint planning with Transmission Network Service Providers under clause 5.14.4;
(vi)	relevant intra jurisdictional developments and any incremental works that may be needed to coordinate the Integrated System Plan with intra jurisdictional planning;
(vii)	the forecast quantity of electricity that is expected to flow, and the periods in which electricity is expected to flow, and the magnitude and significance of future network losses on interconnectors, as projected in the Integrated System Plan over the Integrated System Plan planning horizon;
(viii)	the projected capability of the national transmission grid, and the technical requirements of the power system (such as frequency, voltage, inertia and system strength) required to support the secure and reliable operation of the national transmission grid;
(ix)	good electricity industry practice; and
(x)	such other matters as AEMO considers relevant.
Relevant documents
(b)	In preparing an Integrated System Plan, AEMO must have regard to the following documents:
(1)	the ISP methodology;
(2)	the Cost Benefit Analysis Guidelines;
(3)	the Forecasting Best Practice Guidelines;
(4)	the most recent Transmission Annual Planning Reports;
(5)	the most recent statement of opportunities;
(6)	the most recent gas statement of opportunities under the National Gas Law;
(7)	the most recent NSCAS Report, System Security Report and Inertia Report;
(8)	ISP consumer panel reports; and
(9)	any other documents that AEMO considers relevant.
Market benefits
(c)	In preparing an Integrated System Plan, AEMO must:
(1)	consider the following classes of market benefits that could be delivered by the development path:
(i)	changes in fuel consumption arising through different patterns of generation dispatch;
(ii)	changes in voluntary load curtailment;
(iii)	changes in involuntary load shedding, with the market benefit to be considered using a reasonable forecast of the value of electricity to consumers;
(iv)	changes in costs for parties due to:
(A)	differences in the timing of new plant;
(B)	differences in capital costs; and
(C)	differences in the operating and maintenance costs;
(v)	differences in the timing of expenditure;
(vi)	changes in network losses;
(vii)	changes in ancillary services costs;
(viii)	competition benefits;
(ix)	any additional option value (where this value has not already been included in the other classes of market benefits) gained or foregone from implementing that development path with respect to the likely future investment needs of the market; and
(x)	other classes of market benefits that are:
(A)	determined to be relevant by AEMO and agreed to by the AER in writing before the publication of the draft Integrated System Plan; or
(B)	specified as a class of market benefit in the Cost Benefit Analysis Guidelines;
(2)	include a quantification of all classes of market benefits which are determined to be material to the optimal development path in AEMO's reasonable opinion; and
(3)	consider all classes of market benefits as material unless it can provide reasons why:
(i)	a particular class of market benefit is likely not to materially affect the outcome of the assessment of the development path; or
(ii)	the estimated cost of undertaking the analysis to quantify the market benefit is likely to be disproportionate given the level of uncertainty regarding future outcomes.
Costs
(d)	In preparing an Integrated System Plan, AEMO must quantify the following classes of costs:
(1)	costs incurred in constructing or providing the projects in the development path;
(2)	operating and maintenance costs in respect of the projects in the development path;
(3)	the cost of complying with laws, regulations and applicable administrative requirements in relation to the construction and operation of the projects in the development path; and
(4)	any other class of costs that are:
(i)	determined to be relevant by AEMO and agreed to by the AER in writing before the publication of the draft Integrated System Plan; or
(ii)	specified as a class of cost in the Cost Benefit Analysis Guidelines.
5.22.11	Draft Integrated System Plan
(a)	AEMO must publish the draft Integrated System Plan in accordance with the ISP timetable and include:
(1)	all relevant matters referred to in clause 5.22.6;
(2)	if applicable, an explanation of how AEMO has had regard to the consumer panel report on the Inputs, Assumptions and Scenarios Report;
(3)	an invitation for written submissions on the draft Integrated System Plan, which must:
(i)	specify the deadline for when written submissions must be submitted which date must not be earlier than 30 business days after the publication of the draft Integrated System Plan; and
(ii)	list the matters in respect of which submissions are invited; and
(4)	an invitation to participate in public forums on the draft Integrated System Plan.
(b)	AEMO must hold a public forum on the draft Integrated System Plan prior to the deadline for written submissions.
(c)	Any person may make a written submission to AEMO on the matters, documents and information referred to in paragraph (a) and which forms part of the draft Integrated System Plan, by the date specified in the ISP timetable.
(d)	Nothing in this clause 5.22.11 is to be construed as precluding AEMO from publishing any issues, consultation and discussion papers, or holding any conferences and information sessions that AEMO considers appropriate.
(e)	AEMO must publish submissions on its website subject to its confidentiality obligations under section 54 of the National Electricity Law.
5.22.12	Non-network options
(a)	Where a draft Integrated System Plan identifies an actionable ISP project, AEMO must publish a notice at the same time as it publishes the draft Integrated System Plan, that:
(1)	requests submissions for non-network options;
(2)	provides sufficient detail on the technical characteristics that the non-network options must meet; and
(3)	describes the relevant technical characteristics of the identified need that the actionable ISP project (including any non-network option) is addressing, such as:
(i)	the size of the load reduction or additional supply;
(ii)	location; and 
(iii)	operating profile.
(b)	Proponents of non-network options requested under paragraph (a) must submit their non-network option proposal to AEMO within 12 weeks of the publication of the draft Integrated System Plan.
(c)	AEMO and the relevant Transmission Network Service Provider will conduct a preliminary review of the non-network option proposal submitted by a proponent under paragraph (b), as part of the joint planning process under clause 5.14.4.
(d)	AEMO must provide its assessment in the Integrated System Plan on whether the non-network option proposals submitted under paragraph (b) meet, or are reasonably likely to meet, the relevant identified need, as outlined in the draft Integrated System Plan.
(e)	If the assessment of non-network options proposals in the Integrated System Plan concludes:
(1)	that the non-network option proposal is reasonably likely to meet the relevant identified need, the relevant Transmission Network Service Provider must assess that non-network option proposal in their project assessment draft report; or
(2)	that the non-network option proposal will not meet the relevant identified need, the relevant Transmission Network Service Provider does not have to assess that non-network option proposal in their project assessment draft report.
5.22.13	AER transparency review of draft Integrated System Plan
(a)	The AER, must within one month of the publication of the draft Integrated System Plan, publish a report ("ISP review report") of its review as to whether AEMO has adequately explained how it has derived key inputs and assumptions and how key inputs and assumptions have contributed to the outcomes in the draft Integrated System Plan.
(b)	The AER is not required to consult on an ISP review report.
(c)	If the ISP review report identifies issues with the draft Integrated System Plan, AEMO must:
(1)	as soon as practicable, provide further explanatory material in an addendum to the draft Integrated System Plan; and
(2)	consult on the issues.
5.22.14	Final Integrated System Plan
(a)	AEMO must publish the Integrated System Plan in accordance with the Rules and the ISP timetable.
(b)	The Integrated System Plan must include:
(1)	all relevant matters for an Integrated System Plan referred to in clauses 5.22.6 and 5.22.12;
(2)	an explanation of how AEMO has had regard to the consumer panel report on the draft Integrated System Plan;
(3)	the reasons for decisions made in relation to the Integrated System Plan; and
(4)	AEMO's responses to each of the stakeholders' submissions made in response to the addendum to the draft Integrated System Plan to AEMO under clause 5.22.13(c).
(c)	AEMO must publish on its website:
(1)	if the Integrated System Plan identifies and actionable ISP project not included in the draft Integrated System Plan, a notice requesting submissions for non-network options, which notice must include the information specified in clause 5.22.12(a) and the period in which proponents of non-network options must submit their non-network options to AEMO;
(2)	summaries of each issue, that AEMO reasonably considers to be material, contained in valid written submissions received under clauses 5.22.9(c)(2), 5.22.11, and 5.22.13(c)(2);
(3)	AEMO's response to each such issue; and
(4)	subject to its confidentiality obligations under section 54 of the National Electricity Law, copies of those written submissions.
5.22.15	ISP updates
(a)	AEMO must issue an ISP update if:
(1)	a RIT-T proponent's preferred option for an actionable ISP project fails to satisfy the trigger event set out in clause 5.16A.5(b);
(2)	there is no credible option for an actionable ISP project that satisfies the regulatory investment test for transmission under rule 5.16A; or
(3)	in the course of assessing a preferred option in respect of an actionable ISP project for the purposes of clauses 5.16A.5(b), AEMO considers that there is a material change to the need for, or characteristics of another actionable ISP project.
(b)	If, after the publication of the most recent Integrated System Plan:
(1)	new information becomes available to AEMO relating to the matters set out in clause 5.22.6 and, in AEMO's reasonable opinion, that new information, may materially change the outcome of the regulatory investment for transmission for an actionable ISP project that has either commenced or is due to commence prior the publication of the next Integrated System Plan; or
(2)	a RIT-T proponent requests AEMO to assess an actionable ISP project or stage of an actionable ISP project under clause 5.16A.5(b),
then AEMO must as soon as practicable, assess the impact of the new information on the optimal development path under that Integrated System Plan.
(c)	If AEMO is required to publish an ISP update under paragraph (a), or AEMO's assessment under paragraph (b) determines that there is a material change to the need for, or the characteristics of a current actionable ISP project, AEMO must consult on the new information and the impact on the optimal development path under the Integrated System Plan, in accordance with the consultation requirements set out in the Forecasting Best Practice Guidelines for an ISP update.
(d)	An ISP update must include:
(1)	a description of the new information requiring the update in a descriptive form that is consistent with the Integrated System Plan; and
(2)	the impact of that new information on the optimal development path under the Integrated System Plan.
(e)	If AEMO has consulted under paragraph (c), AEMO must publish on its website:
(1)	summaries of each issue, that AEMO reasonably considers to be material, contained in valid written submissions received under paragraph (d);
(2)	AEMO's response to each such issues; and
(3)	subject to its confidentiality obligations under section 54 of the National Electricity Law, copies of those written submissions.
5.22.16	ISP database
(a)	AEMO must establish, maintain and make available to the public, a database ("ISP database") of information that includes: 
(1)	inputs used by it in preparing the most recent Integrated System Plan or ISP update;
(2)	the most recent Inputs, Assumptions and Scenarios Report;
(3)	supporting information in relation to each of the draft and final Integrated System Plan (at the same time as they are published) which will assist in the understanding of the draft and final Integrated System Plan having regard to:
(i)	the Forecasting Best Practice Guidelines;
(ii)	AEMO's confidentiality obligations under section 54 of the National Electricity Law; and
(iii)	the best form of the information for this purpose; and
(4)	NSCAS Reports, System Strength Reports and Inertia Reports.
(b)	Subject to paragraph (c) and its confidentiality obligations under section 54 of the National Electricity Law, AEMO must publish the following on AEMO's website:
(1)	any forecasts prepared under clause 5.22.18(b)(1); and
(2)	sufficient information used to develop the forecasts referred to in subparagraph (1) to enable an understanding of how such forecasts were developed.
(c)	The information referred to in subparagraph (b)(2) must be published at the same time as, or as soon as reasonably practical after, the forecasts referred to in (b)(1).
5.22.17	Jurisdictional planning bodies and jurisdictional planning representatives
(a)	A jurisdictional planning body must provide assistance AEMO reasonably requests in connection with the performance of its NTP functions.
(b)	If there is no jurisdictional planning body or no jurisdictional planning representative for a participating jurisdiction, AEMO may assume the functions of such a body or representative under the Rules.
5.22.18	NTP Functions
(a)	Paragraph (b) has effect for the purposes of section 49(2)(e) of the National Electricity Law.
(b)	The NTP functions also include the following:
(1)	developing any forecasts of electricity demand at a regional or connection point level; and
(2)	AEMO's functions relating to an Integrated System Plan under clause 5.14.4 and rules 5.16A, 5.22 and 5.23.
(c)	AEMO's preparation and publication of Integrated System Plans is undertaken pursuant to, and in satisfaction of, AEMO's NTP functions under sections 49(2)(a) to (d) of the National Electricity Law.
5.23	Disputes in relation to an ISP
5.23.1	Disputing party
(a)	A person (a "disputing party") may, by notice to the AER, raise a dispute on the grounds that one or more of the following procedures required by the Rules to be observed by AEMO in connection with the making of an Integrated System Plan were not observed:
(1)	the processes for the Inputs, Assumptions and Scenarios Report and ISP methodology required in accordance with clause 5.22.8(b);
(2)	the consultation for a draft Integrated System Plan required in accordance with clauses 5.22.11(a)(2) and (3), (b), (c) and (e); and
(3)	the obligations in respect of an Integrated System Plan required under clause 5.22.14(c),
(each, a "prescribed ISP process").
(b)	It is for a disputing party to establish:
(1)	that the person made a submission in the prescribed ISP process;
(2)	that AEMO has not observed a prescribed ISP process;
(3)	the reasons why the AER should accept a dispute notice; and
(4)	if the person did not make a submission to the prescribed ISP process, the reasons for which they did not make a submission and should be entitled to raise a dispute.
(c)	Within 30 days of the date of publication of an Integrated System Plan, a disputing party must:
(1)	give notice of the dispute in writing setting out the matters in paragraph (b) (the dispute notice) to the AER; and
(2)	at the same time, give a copy of the dispute notice to AEMO.
5.23.2	Initial AER review
Within 20 business days of receipt of the dispute notice, the AER must review the dispute notice and may, at its discretion, either:
(a)	reject any dispute by written notice to the person who initiated the dispute if the AER considers that:
(1)	based on the dispute notice, the disputing party has not established a prima facie case in respect of the matters under clause 5.23.1(b)(1), (2), or (3);
(2)	if clause 5.23.1(b)(4) applies, the reasons given are not sufficient to justify an entitlement to raise a dispute;
(3)	the matter was already considered in an IASR review report or ISP review report;
(4)	that the grounds for the dispute and the reasons described are misconceived or lacking in substance; or
(5)	the dispute is vexatious,
and notify AEMO that the dispute has been rejected; or
(b)	accept the dispute notice and notify the disputing party and AEMO that it has been accepted.
5.23.3	Provision of further information
(a)	The AER may request further information regarding the dispute from the disputing party or AEMO.
(b)	A disputing party or AEMO (as the case may be) must as soon as reasonably practicable provide any information requested under paragraph (a) to the AER.
(c)	The relevant period of time in which the AER must make a determination under clause 5.23.4 is automatically extended by the period of time taken by AEMO or a disputing party to provide any additional information requested by the AER under this clause 5.23.3, provided:
(1)	the AER makes the request for the additional information at least 7 business days prior to the expiry of the relevant period; and
(2)	AEMO or the disputing party provides the additional information within 14 business days of receipt of the request.
5.23.4	AER determination
(a)	Where the AER accepts a dispute notice under clause 5.23.2(b), then subject to clause 5.23.3(c), within 40 business days of receipt of a dispute notice, the AER must either:
(1)	reject any dispute by written notice to the person who initiated the dispute if the AER considers that the grounds of the dispute are not established and notify AEMO that the dispute has been rejected; or
(2)	subject to paragraph (c), make and publish a determination:
(i)	directing AEMO to remedy the non-observance with the prescribed ISP process, which direction may include requiring AEMO to consider whether an ISP update is required; or
(ii)	stating that, based on the grounds of the dispute, AEMO will not be required to take any remedial action in respect of the Integrated System Plan.
(b)	AEMO must comply with an AER determination under subparagraph (a)(2)(i) within the timeframe specified in that determination. If, having regard to the determination, AEMO considers that an ISP update is required, then it must publish an ISP update in accordance with clause 5.22.15.
(c)	In making a determination under paragraph (a), the AER:
(1)	must publish its reasons for making a determination;
(2)	may disregard any matter raised by the disputing party or AEMO that the AER considers is misconceived or lacking in substance;
(3)	must only consider compliance with the prescribed ISP process and must not consider the merits of the conclusions of the Integrated System Plan or direct the amendment of the Integrated System Plan or require AEMO to undertake an ISP update; and
(4)	must specify a reasonable timeframe for AEMO to comply with the AER's determination (if applicable).
(d)	The raising of a dispute under clause 5.23.1, or the making of a determination under subparagraph (a)(2)(i), does not affect the validity, or stay the operation, of the Integrated System Plan.
Note:
The Integrated System Plan will remain in effect until such time as replaced in whole or in part by an ISP update.
Schedule 5.1a	System standards
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.
S5.1a.1	Purpose
The purpose of this schedule is to establish system standards that:
(a)	are necessary or desirable for the safe and reliable operation of the facilities of Registered Participants;
(b)	are necessary or desirable for the safe and reliable operation of equipment;
(c)	could be reasonably considered good electricity industry practice; and
(d)	seek to avoid the imposition of undue costs on the industry or Registered Participants.
A Registered Participant should not, by virtue of this schedule, rely on system standards being fully complied with at a connection point under all circumstances. However, a Registered Participant should expect to be reasonably informed of circumstances where the standard of supply at its connection points will not conform to the system standards.
Except for standards of frequency and system stability, a Registered Participant should have the opportunity to negotiate or renegotiate relevant terms of a connection agreement (including relevant charges), to improve the standard of supply to the level of the system standard.
The system standards are set out below.
S5.1a.2	Frequency
The frequency operating standards are system standards and are as determined by the Reliability Panel and published by the AEMC.
S5.1a.3	System stability
The power system should remain in synchronism and be stable:
(a)	Transient stability: following any credible contingency event or protected event; and
(b)	Oscillatory stability: in the absence of any contingency event, for any level of inter-regional or intra-regional power transfer up to the applicable operational limit; and
(c)	Voltage stability: stable voltage control must be maintained following the most severe credible contingency event or any protected event.
For the purposes of clause S5.1a.3 a credible contingency event includes the application of a fault (other than a three-phase fault) to any part of the power system and de-energisation of the faulted element within the allowable clearance time applicable to that element according to clause S5.1a.8.
The halving time of any inter-regional or intra-regional oscillation, being the time for the amplitude of an oscillation to reduce by half, should be less than 10 seconds. To allow for planning and operational uncertainties, the power system should be planned and operated to achieve a halving time of 5 seconds.
S5.1a.4	Power frequency voltage
Except as a consequence of a contingency event, the voltage of supply at a connection point should not vary by more than 10 percent above or below its normal voltage, provided that the reactive power flow and the power factor at the connection point is within the corresponding limits set out in the connection agreement.
As a consequence of a credible contingency event, the voltage of supply at a connection point should not rise above its normal voltage by more than a given percentage of normal voltage for longer than the corresponding period shown in Figure S5.1a.1 for that percentage.
As a consequence of a contingency event, the voltage of supply at a connection point could fall to zero for any period.
Figure S5.1a.1

S5.1a.5	Voltage fluctuations
The voltage fluctuation level of supply should be less than the "compatibility levels" set out in Table 1 of Australian Standard AS/NZS 61000.3.7:2001. To facilitate the application of this standard Network Service Providers must establish "planning levels" for their networks as provided for in the Australian Standard.
The following principles apply to the use of the shared network:
(a)	the sharing between Network Users of the capability of connection assets to withstand voltage fluctuations is to be managed by Network Service Providers in accordance with the provisions of clause S5.1.5 of schedule 5.1; and
(b)	to the extent practicable, the costs of managing or abating the impact of voltage fluctuations in excess of the costs which would result from the application of an automatic access standard are to be borne by those Network Users whose facilities cause the voltage fluctuations.
S5.1a.6	Voltage waveform distortion
Harmonic voltage distortion level of supply should be less than the "compatibility levels" defined in Table 1 of Australian Standard AS/NZS 61000.3.6:2001. To facilitate the application of this standard Network Service Providers must establish "planning levels" for their networks as provided for in the Australian Standard.
The following principles apply to the use of the shared network:
(a)	the sharing between Network Users of the capability of connection assets to absorb or mitigate harmonic voltage distortion is to be managed by Network Service Providers in accordance with the provisions of clause S5.1.6 of schedule 5.1; and
(b)	to the extent practicable, the costs of managing or abating the impact of harmonic distortion in excess of the costs which would result from the application of an automatic access standard are to be borne by those Network Users whose facilities cause the harmonic voltage distortion.
S5.1a.7	Voltage unbalance
Except as a consequence of a contingency event, the average voltage unbalance, measured at a connection point, should not vary by more than the amount set out in column 2 of Table S5.1a.1, when determined over a 30 minute averaging period.
As a consequence of a credible contingency event or protected event, the average voltage unbalance, measured at a connection point, should not vary by more than the amount set out in column 3 of Table S5.1a.1, when determined over a 30 minute averaging period.
The average voltage unbalance, measured at a connection point, should not vary by more than the amount set out in column 4 of Table S5.1a.1 for the relevant nominal supply voltage, when determined over a 10 minute averaging period.
The average voltage unbalance, measured at a connection point, should not vary more often than once per hour by more than the amount set out in column 5 of Table S5.1a.1 for the relevant nominal supply voltage, when determined over a 1 minute averaging period.
For the purpose of this clause, voltage unbalance is measured as negative sequence voltage.
Table S5.1a.1

Nominal supply voltage (kV)	Maximum negative sequence voltage (% of nominal voltage)	
Column 1	Column 2	Column 3	Column 4	Column 5	
	no contingency event	credible contingency event or protected event	general	once per hour	
	30 minute average	30 minute average	10 minute average	1 minute average	
more than 100	0.5	0.7	1.0	2.0	
more than 10 but not more than 100	1.3	1.3	2.0	2.5	
10 or less	2.0	2.0	2.5	3.0	

S5.1a.8	Fault clearance times
(a)	Faults anywhere within the power system should be cleared sufficiently rapidly that:
(1)	the power system does not become unstable as a result of faults that are credible contingency events;
(2)	inter-regional or intra-regional power transfers are not unduly constrained; and
(3)	consequential equipment damage is minimised.
(b)	The fault clearance time of a primary protection system for a short circuit fault of any fault type anywhere:
(1)	within a substation;
(2)	within connected plant; or
(3)	on at least the half of a power line nearer to the protection system,
should not exceed the relevant time in column 2 of Table S5.1a.2 for the nominal  voltage that applies at the fault location.
(c)	The fault clearance time of a primary protection system for a short circuit fault of any fault type anywhere on the remote portion of a power line for which the near portion is protected by a primary protection system under clause S5.1a8(b) should not exceed the relevant time in column 3 of Table S5.1a.2 for the nominal  voltage that applies at the fault location.
(d)	The fault clearance time of a breaker fail protection system or similar back-up protection system for a short circuit fault of any fault type should not exceed the relevant time in column 4 of Table S5.1a.2 for the nominal voltage that applies at the fault location.
(e)	The owner of the faulted element may require shorter fault clearance times to minimise plant damage.
(f)	The allowable fault clearance times specified in Table S5.1a.2 apply in accordance with the provisions of clause S5.1.9 to facilities constructed or modified on or after the performance standards commencement date.
(g)	For facilities other than those referred to in clause S5.1a.8(f), the applicable allowable fault clearance times must be derived by the relevant Network Service Provider from the existing capability of each facility on the performance standards commencement date.
Table S5.1a.2

Nominal voltage at fault location(kV)	Time(milliseconds)	
Column 1	Column 2	Column 3	Column 4	
400kV and above	80	100	175	
at least 250kV but less than 400kV	100	120	250	
more than 100kV but less than 250kV	120	220	430	
less than or equal 100 kV	As necessary to prevent plant damage and meet stability requirements	

Schedule 5.1	Network Performance Requirements to be Provided or Co-ordinated by Network Service Providers
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.
S5.1.1	Introduction
This schedule describes the planning, design and operating criteria that must be applied by Network Service Providers to the transmission networks and distribution networks which they own, operate or control. It also describes the requirements on Network Service Providers to institute consistent processes to determine the appropriate technical requirements to apply for each connection enquiry or application to connect processed by the Network Service Provider with the objective that all connections satisfy the requirements of this schedule.
The criteria and the obligations of Registered Participants to implement them, fall into two categories, namely:
(a)	those required to achieve adequate levels of network power transfer capability or quality of supply for the common good of all, or a significant number of, Registered Participants; and
(b)	those required to achieve a specific level of network service at an individual connection point.
A Network Service Provider must:
(1)	fully describe the quantity and quality of network services which it agrees to provide to a person under a connection agreement in terms that apply to the connection point as well as to the transmission or distribution system as a whole;
(2)	ensure that the quantity and quality of those network services are not less than could be provided to the relevant person if the national grid were planned, designed and operated in accordance with the criteria set out in this clause S5.1.1 and recognising that levels of service will vary depending on location of the connection point in the network; and
(3)	observe and apply the relevant provisions of the system standards in accordance with this schedule 5.1.
To the extent that this schedule 5.1 does not contain criteria which are relevant to the description of a particular network service, the Network Service Provider must describe the network service in terms which are fair and reasonable.
This schedule includes provisions for Network Service Providers and Registered Participants to negotiate the criteria to apply to a connection within defined ranges between a lower bound (minimum access standard) and an upper bound (automatic access standard). All criteria which are intended to apply to a connection must be recorded in a connection agreement. Where it is intended to apply a negotiated access standard in accordance with clause 5.3.4A of the Rules, the Network Service Provider must first be satisfied that the application of the negotiated access standard will not adversely affect other Registered Participants.
S5.1.2	Network reliability
S5.1.2.1	Credible contingency events
Network Service Providers must plan, design, maintain and operate their transmission networks and distribution networks to allow the transfer of power from generating units to Customers with all facilities or equipment associated with the power system in service and may be required by a Registered Participant under a connection agreement to continue to allow the transfer of power with certain facilities or plant associated with the power system out of service, whether or not accompanied by the occurrence of certain faults (called credible contingency events).
The following credible contingency events and practices must be used by Network Service Providers for planning and operation of transmission networks and distribution networks unless otherwise agreed by each Registered Participant who would be affected by the selection of credible contingency events:
(a)	The credible contingency events must include the disconnection of any single generating unit or transmission line, with or without the application of a single circuit two-phase-to-ground solid fault on lines operating at or above 220 kV, and a single circuit three-phase solid fault on lines operating below 220 kV. The Network Service Provider must assume that the fault will be cleared in primary protection time by the faster of the duplicate protections with installed intertrips available. For existing transmission lines operating below 220 kV but above 66 kV a two-phase to earth fault criterion may be used if the modes of operation are such as to minimise the probability of three-phase faults occurring and operational experience shows this to be adequate, and provided that the Network Service Provider upgrades performance when the opportunity arises.
(b)	For lines at any voltage above 66 kV which are not protected by an overhead earth wire and/or lines with tower footing resistances in excess of 10 ohms, the Network Service Provider may extend the criterion to include a single circuit three-phase solid fault to cover the increased risk of such a fault occurring. Such lines must be examined individually on their merits by the relevant Network Service Provider.
(c)	For lines at any voltage above 66 kV a Network Service Provider must adopt operational practices to minimise the risk of slow fault clearance in case of inadvertent closing on to earths applied to equipment for maintenance purposes. These practices must include but not be limited to:
(1)	Not leaving lines equipped with intertrips alive from one end during maintenance; and
(2)	Off-loading a three terminal (tee connected) line prior to restoration, to ensure switch on to fault facilities are operative.
(d)	The Network Service Provider must ensure that all protection systems for lines at a voltage above 66 kV, including associated intertripping, are well maintained so as to be available at all times other than for short periods (not greater than eight hours) while the maintenance of a protection system is being carried out.
S5.1.2.2	Network service within a region
The following paragraphs of this section set out minimum standards for certain network services to be provided to Registered Participants by Network Service Providers within a region. The amount of network redundancy provided must be determined by the process set out in rules 5.12 and 5.13 of the Rules and is expected to reflect the grouping of generating units, their expected capacity factors and availability and the size and importance of Customer groups.
The standard of service to be provided at each connection point must be included in the relevant connection agreement, and must include a power transfer capability such as that which follows:
(a)	In the satisfactory operating state, the power system must be capable of providing the highest reasonably expected requirement for power transfer (with appropriate recognition of diversity between individual peak requirements and the necessity to withstand credible contingency events) at any time.
(b)	During the most critical single element outage the power transfer available through the power system may be:
(1)	zero (single element supply);
(2)	the defined capacity of a backup supply, which, in some cases, may be provided by another Network Service Provider;
(3)	a nominated proportion of the normal power transfer capability (eg 70 percent); or
(4)	the normal power transfer capability of the power system (when required by a Registered Participant).
In the case of clauses S5.1.2.2(b)(2) and (3) the available capacity would be exceeded sufficiently infrequently to allow maintenance to be carried out on each network element by the Network Service Provider. A connection agreement may state the expected proportion of time that the normal capability will not be available, and the capability at those times, taking account of specific design, locational and seasonal influences which may affect performance, and the random nature of element outages.
A connection agreement may also state a conditional power transfer capability that allows for both circuits of a double circuit line or two closely parallel circuits to be out of service.
S5.1.2.3	Network service between regions
The power transfer capability between regions must be determined by the process set out in Part B of Chapter 5.
The following paragraphs of this section set out a framework within which Network Service Providers must describe to AEMO the levels of network service that apply for power transfer between regions. In cases where power transfer capability is determined by stability considerations on the power system (refer to clause S5.1.8 of this schedule) it is expected that line outages within transmission networks within a region will weaken the network so as to result in reduced power transfer capability even in the absence of outages of the lines between regions.
(a)	In the satisfactory operating state the power transfer capability between regions is defined by a multi-term equation for each connection between regions which takes account of all power system operating conditions which can significantly impact on performance. The majority of these operating conditions are the result of market operation and are outside the control of the Network Service Provider. In the satisfactory operating state the network must be planned by the Network Service Provider and operated by AEMO to withstand the impact of any single contingency with severity less than the credible contingency events stated in clause S5.1.2.1.
(b)	During critical single element outages reduced power transfer capabilities will apply. In those cases where outage of the remaining element will result in breaking of the connection between the regions AEMO must provide for the effect on power system frequency in the separate transmission systems following this event when determining the maximum power transfer.
S5.1.3	Frequency variations
A Network Service Provider must ensure that within the extreme frequency excursion tolerance limits all of its power system equipment will remain in service unless that equipment is required to be switched to give effect to manual load shedding in accordance with clause S5.1.10, or is required by AEMO to be switched for operational purposes or is required to be switched or disconnected for operation of an emergency frequency control scheme.
Sustained operation outside the extreme frequency excursion tolerance limits need not be taken into account by Network Service Providers in the design of plant which may be disconnected if this is necessary for the protection of that plant.
S5.1.4	Magnitude of power frequency voltage
A Transmission Network Service Provider must plan and design its transmission system and equipment for control of voltage such that the minimum steady state voltage magnitude, the maximum steady state voltage magnitude and variations in voltage magnitude are consistent with the levels stipulated in clause S5.1a.4 of the system standards.
(a)	The Network Service Provider must determine the automatic access standard for the voltage of supply at the connection point such that the voltage may vary in accordance with clause S5.1a.4 of the system standards.
(b)	The Network Service Provider must determine the minimum access standard for the voltage of supply at the connection point such that the voltage may vary:
(1)	as a consequence of a credible contingency event or protected event in accordance with clause S5.1a.4; and
(2)	otherwise, between 95 percent and 105 percent of the target voltage.
(c)	For the purposes of clause S5.1.4(b) the target voltage must be determined as follows:
(1)	if the connection point is connected to a transmission line (but not through a transformer), the Network Service Provider must determine the target voltage in consultation with AEMO taking into account the capability of existing facilities that are subject to that supply voltage; and
(2)	otherwise, Network Users that share the same supply voltage must jointly determine the target voltage which may be specified to vary with aggregate loading level;
provided that at all times the supply voltage remains between 90 percent and 110 percent of the normal voltage determined in accordance with clause S5.1a.4 except as a consequence of a contingency event.
(d)	For the purposes of this clause, the voltage of supply is measured as the RMS phase voltage.
Where the independent control of voltage at the connection point is possible without adverse impact on voltage control at another connection point, the Network Service Provider must make reasonable endeavours to meet the request. The target voltage and any agreement to a target range of voltage magnitude must be specified in the relevant connection agreement. The agreement may include a different target range in the satisfactory operating state and after a credible contingency event or protected event (and how these target ranges may be required to vary with loading level).
A Network Service Provider must ensure that each facility that is part of its transmission network or distribution network is capable of continuous uninterrupted operation in the event that variations in voltage magnitude occur due to faults external to the facility. The design of a facility should anticipate the likely time duration and magnitude of variations in the power-frequency phase voltages which may arise dependent on the nature and location of the fault.
S5.1.5	Voltage fluctuations
A Network Service Provider must use reasonable endeavours to design and operate its transmission system or distribution system and include conditions in connection agreements in relation to the permissible variation with time of the power generated or load taken by a Network User to ensure that other Network Users are supplied with a power-frequency voltage which fluctuates to an extent that is less than the levels stipulated in accordance with the provisions of clause S5.1a.5 of the system standards and this clause S5.1.5.
In accordance with AS/NZS 61000.3.7:2001 and guidelines published by Standards Australia and applying the assumption that Customers will comply with their obligations under schedule 5.3, a Network Service Provider must determine "Planning Levels" for connection points on their network in order to maintain voltage fluctuation levels for all supply points to customers supplied from their network below the "Compatibility Levels" defined in Table 1 of AS/NZS 61000.3.7:2001.
The Network Service Provider must allocate emission limits in response to a connection enquiry or an application to connect and evaluate the acceptability for connection of fluctuating sources as follows:
(a)	Automatic access standard: the Network Service Provider must allocate emission limits no more onerous than the lesser of the acceptance levels determined in accordance with either of the stage 1 or the stage 2 evaluation procedures defined in AS/NZS 61000.3.7:2001.
(b)	Minimum access standard: subject to clause S5.1.5(c), the determination by the Network Service Provider of acceptable emission limits must be undertaken in consultation with the party seeking connection using the stage 3 evaluation procedure defined in AS/NZS61000.3.7:2001.
(c)	In respect of each new connection at a level of performance below the automatic access standard the Network Service Provider must include provisions in the relevant connection agreement requiring the Network User if necessary to meet the system standards or allow connection of other Network Users to either upgrade to the automatic access standard or fund the reasonable cost of the works necessary to mitigate their effect of connecting at a standard below the automatic access standard.
(d)	If for existing customer connections the level of voltage fluctuation is, or may be, exceeded as a result of a proposed new connection, the Network Service Provider must, if the cause of that excessive level cannot be remedied by enforcing the provisions of existing connection agreements, undertake all reasonable works necessary to meet the technical standards in this schedule or to permit the proposed new connection within the requirements stated in this clause.
For other than a new connection in accordance with the preceding paragraph, the responsibility of a Network Service Provider for excursions in voltage fluctuations above the levels defined above is limited to voltage fluctuations caused by network plant and the pursuit of all reasonable measures available under the Rules and its connection agreements.
S5.1.6	Voltage harmonic or voltage notching distortion
A Network Service Provider must use reasonable endeavours to design and operate its network and include conditions in connection agreements to ensure that the effective harmonic voltage distortion at any point in the network will be limited to less than the levels stipulated in accordance with the provisions of clause S5.1a.6 of the system standards and this clause S5.1.6.
In accordance with AS/NZS 61000.3.6:2001 and guidelines published by Standards Australia and applying the assumption that Customers will comply with their obligations under schedule 5.3 Network Service Providers must determine "Planning Levels" for connection points on their network in order to maintain harmonic voltage distortion for all supply points to customers supplied from their network below the "Compatibility Levels" defined in Table 1 of AS/NZS 61000.3.6:2001.
The Network Service Provider must allocate emission limits to a connection enquiry or an application to connect and must evaluate the acceptability for connection of distorting sources as follows:
(a)	Automatic access standard: the Network Service Provider must allocate emission limits no more onerous than the lesser of the acceptance levels determined in accordance with either of the stage 1 or the stage 2 evaluation procedures defined in AS/NZS 61000.3.6:2001.
(b)	Minimum access standard: subject to clause S5.1.6(c), the determination by the Network Service Provider of acceptable emission limits must be undertaken in consultation with the party seeking connection using the Stage 3 evaluation procedure defined in AS/NZS61000.3.6:2001.
(c)	In respect of each new connection at a level of performance below the automatic access standard the Network Service Provider must include provisions in the relevant connection agreement requiring the Network User if necessary to meet the system standards or allow connection of other Network Users to either upgrade to the automatic access standard or fund the reasonable cost of the works necessary to mitigate their effect of connecting at a standard below the automatic access standard.
(d)	If for existing customer connections the level of harmonic voltage distortion is, or may be, exceeded as a result of a proposed new connection, the Network Service Provider must, if the cause of that excessive level cannot be remedied by enforcing the provisions of existing connection agreements, undertake all works necessary to meet the technical standards in this schedule or to permit a proposed new connection within the automatic access standard defined in clause S5.3.8 and the requirements stated in this clause.
For other than a new connection in accordance with the preceding paragraph, the responsibility of a Network Service Provider for harmonic voltage distortion outside the range defined above is limited to harmonic voltage distortion caused by network plant and the pursuit of all measures available under the Rules and its connection agreements.
S5.1.7	Voltage unbalance
(a)	A Transmission Network Service Provider must balance the effective impedance of the phases of its network, and a Distribution Network Service Provider must balance the current drawn in each phase at each of its connection points, so as to achieve average levels of negative sequence voltage at all connection points that are equal to or less than the values set out in Table S5.1a.1 as determined in accordance with the accompanying provisions of clause S5.1a.7 of the system standards.
(b)	A Network Service Provider must include conditions in connection agreements to ensure that a Connection Applicant will balance the current drawn in each phase at each of its connection points so as to achieve:
(1)	for those Network Users listed in clause S5.3(a): the levels permitted in accordance with clause S5.3.6 of schedule 5.3;
(2)	for Market Network Service Providers: the levels permitted in accordance with clause S5.3a.9 of schedule 5.3a;
(3)	otherwise: the average levels of negative sequence voltage at each of its connection points that are equal to or less than the values set out in Table S5.1a.1 and the accompanying provisions of clause S5.1a.7 of the system standards.
The responsibility of the Network Service Provider for voltage unbalance outside the ranges defined above is limited to voltage unbalance caused by the network and the pursuit of all measures available under the Rules and its connection agreements.
(c)	A Network Service Provider must include conditions in connection agreements to ensure that each Generator will balance:
(1)	the voltage generated in each phase of its generating system; and
(2)	when not generating, the current drawn in each phase,
in order to achieve average levels of negative sequence voltage at each of the generating system connection points due to phase imbalances within the generating plant that are not more than the values determined by the Network Service Provider to achieve average levels of negative sequence voltage at the connection points of other Network Users in accordance with clause S5.1a.7.
(d)	When including conditions under paragraph (c), the Network Service Provider must have regard to the capabilities of the relevant generating plant technology.
S5.1.8	Stability
In conforming with the requirements of the system standards, the following criteria must be used by Network Service Providers for both planning and operation:
For stable operation of the national grid, both in a satisfactory operating state and following any credible contingency events or any protected event described in clause S5.1.2.1:
(a)	the power system will remain in synchronism;
(b)	damping of power system oscillations will be adequate; and
(c)	voltage stability criteria will be satisfied.
Damping of power system oscillations must be assessed for planning purposes according to the design criteria which states that power system damping is considered adequate if after the most critical credible contingency event or any protected event, simulations calibrated against past performance indicate that the halving time of the least damped electromechanical mode of oscillation is not more than five seconds.
To assess the damping of power system oscillations during operation, or when analysing results of tests such as those carried out under clause 5.7.7 of the Rules, the Network Service Provider must take into account statistical effects. Therefore, the power system damping operational performance criterion is that at a given operating point, real-time monitoring or available test results show that there is less than a 10 percent probability that the halving time of the least damped mode of oscillation will exceed ten seconds, and that the average halving time of the least damped mode of oscillation is not more than five seconds.
The voltage control criterion is that stable voltage control must be maintained following the most severe credible contingency event or any protected event. This requires that an adequate reactive power margin must be maintained at every connection point in a network with respect to the voltage stability limit as determined from the voltage/reactive load characteristic at that connection point. Selection of the appropriate margin at each connection point is at the discretion of the relevant Network Service Provider, subject only to the requirement that the margin (expressed as a capacitive reactive power (in MVAr)) must not be less than one percent of the maximum fault level (in MVA) at the connection point.
In planning a network a Network Service Provider must consider non-credible contingency events such as busbar faults which result in tripping of several circuits, uncleared faults, double circuit faults and multiple contingencies which could potentially endanger the stability of the power system. In those cases where the consequences to any network or to any Registered Participant of such events are likely to be severe disruption a Network Service Provider and/or a Registered Participant must in consultation with AEMO, install, maintain and upgrade emergency controls within the Network Service Provider's or Registered Participant's system or in both, as necessary, to minimise disruption to any transmission or distribution network and to significantly reduce the probability of cascading failure.
A Registered Participant must co-operate with a Network Service Provider to achieve stable operation of the national grid and must use all reasonable endeavours to negotiate with the Network Service Provider regarding the installation of emergency controls as described in the previous paragraph. The cost of installation, maintenance and operation of the emergency controls must be borne by the Network Service Provider who is entitled to include this cost when calculating the Transmission Customer use of system price.
S5.1.9	Protection systems and fault clearance times
Network Users
(a)	A Network Service Provider must determine the automatic access standard and minimum access standard that applies to the protection zone of each protection system in relation to the connection point and the plant to be connected, as follows:
(1)	The automatic access standard for fault clearance time for any fault type is the lesser of the system standard set out in clause S5.1a.8 that applies to the highest nominal voltage within the protection system's protection zone and the corresponding minimum access standard determined under clauses S5.1.9(a)(2) or S5.1.9(a)(3) as applicable.
(2)	The minimum access standard for fault clearance time of a primary protection system is:
(i)	for a fault type that constitutes a credible contingency event in the relevant protection zone, the longest time such that a short circuit fault of that fault type that is cleared in that time would not cause the power system to become unstable when operating at any level of inter-regional or intra-regional power transfer that would be permissible (taking into account all other limiting criteria) if the fault clearance time for such a fault at the connection point were the system standard set out in clause S5.1a.8 that applies to the nominal voltage at the connection point; and
(ii)	for a fault type that does not constitute a credible contingency event in the relevant protection zone:
(A)	if a two phase to ground fault in that protection zone constitutes a credible contingency event, the corresponding fault clearance time for a two phase to ground short circuit fault in that protection zone as determined under clause S5.1.9(a)(2)(i); and
(B)	otherwise, the shortest of the fault clearance times for a two phase to ground short circuit fault in each adjoining protection zone (excluding transformer protection zones and dead zones) as determined under clauses S5.1.9(a)(2)(i) or S5.1.9(e).
(3)	The minimum access standard for fault clearance time of a breaker fail protection system or similar back-up protection system is the longest time such that a short circuit fault of any fault type that is cleared in that time would not damage any part of the power system (other than the faulted element) while the fault current is flowing or being interrupted.
(b)	[Deleted]
Transmission systems and distribution systems
(c)	Subject to clauses S5.1.9(k) and S5.1.9(l), a Network Service Provider must provide sufficient primary protection systems and back-up protection systems (including breaker fail protection systems) to ensure that a fault of any fault type anywhere on its transmission system or distribution system is automatically disconnected in accordance with clause S5.1.9(e) or clause S5.1.9(f).
(d)	If the fault clearance time determined under clause S5.1.9(e) of a primary protection system for a two phase to ground short circuit fault is less than 10 seconds, the primary protection system must have sufficient redundancy to ensure that it can clear short circuit faults of any fault type within the relevant fault clearance time with any single protection element (including any communications facility upon which the protection system depends) out of service.
(e)	The fault clearance time of a primary protection system of a Network Service Provider must not exceed:
(1)	for any fault type that constitutes a credible contingency event in the relevant protection zone, the longest time such that a short circuit fault of that fault type that is cleared in that time would not cause the power system to become unstable when operating at any level of inter-regional or intra-regional power transfer that would be permissible (taking into account all other limiting criteria) if the fault clearance time for such a fault in that protection zone were the relevant system standard set out in clause S5.1a.8; and
(2)	for any fault type that does not constitute a credible contingency event in the relevant protection zone:
(i)	if a two phase to ground fault in that protection zone is a credible contingency event, the corresponding fault clearance time for a two phase to ground fault in that protection zone as determined under clause S5.1.9(e)(1); and
(ii)	otherwise, the shortest of the fault clearance times for a two phase to ground fault in each adjoining protection zone (excluding transformer protection zones and dead zones) as determined under clauses S5.1.9(a)(2)(i), S5.1.9(e)(1)or S5.1.9(e)(2)(i).
(f)	The fault clearance time of each breaker fail protection system or similar back-up protection system of a Network Service Provider must be such that a short circuit fault of any fault type that is cleared in that time would not damage any part of the power system (other than the faulted element) while the fault current is flowing or being interrupted.
(g)	A Network Service Provider must demonstrate to AEMO that each fault clearance time for a primary protection system that is longer than the relevant system standard set out in clause S5.1a.8 and is less than 10 seconds would not cause or require an inter-regional or intra-regional power transfer capability to be reduced.
(h)	A Network Service Provider must include in each connection agreement entered into after the performance standards commencement date:
(1)	the fault clearance times for each fault type of each of its protection systems that could reasonably be expected to interrupt supply to or from the relevant connection point; and
(2)	an agreement to not increase those fault clearance times without the prior written agreement of the other party.
(i)	Network Service Providers must coordinate and cooperate with Network Users to implement breaker fail protection for circuit breakers provided to isolate the Network User's facility from the Network Service Provider's facilities.
(j)	Where practicable and economic to achieve, investments should meet the system standard for fault clearance times as specified in clause S5.1a.8 for two phase to ground short circuit faults.
(k)	A primary protection system may clear faults other than short circuit faults slower than the relevant fault clearance time, provided that such faults would be cleared sufficiently promptly to not adversely impact on power system security compared with its operation for the corresponding short circuit fault. In the case of a fault within equipment at a station, the corresponding short circuit fault is to be taken as a two phase to ground short circuit fault at the external connections of the equipment.
(l)	Protection systems may rely on breaker fail protection systems or other back-up protection systems to completely clear faults of any fault type that:
(1)	occur within a substation between a protection zone and a circuit breaker adjacent to that protection zone that is required to open to clear the fault (a dead zone); and
(2)	remain connected through a power line or transformer after operation of a primary protection system,
provided that the relevant Network Service Provider assesses that the likelihood of a fault occurring within the dead zone is not greater than the likelihood of a fault occurring on busbars.
(m)	For the purposes of this clause S5.1.9, a credible contingency event includes any event that clause S5.1.2.1 requires a Network Service Provider to consider as a credible contingency event.
(n)	The provisions of clause S5.1.9(d) apply to facilities constructed or modified on or after the performance standards commencement date.
(o)	For facilities other than those referred to in clause S5.1.9(n), the requirement for primary protection system redundancy must be derived by the Network Service Provider from the existing capability of each facility on the performance standards commencement date.
S5.1.10	Load, generation and network control facilities
S5.1.10.1	General
Each Network Service Provider in consultation with AEMO must ensure that:
(a)	sufficient load is under the control of underfrequency relays or other facilities where required to minimise or reduce the risk that in the event of the sudden, unplanned simultaneous occurrence of multiple contingency events, the power system frequency moves outside the extreme frequency excursion tolerance limits;
(b)	where determined to be necessary, sufficient load is under the control of undervoltage relays to minimize or reduce the risk of voltage collapse on the occurrence of multiple contingency events; and
(c)	there is sufficient load under manual control either locally or from remotely located control centres to allow the load shedding procedures to be implemented on instruction from AEMO to enable AEMO to maintain power system security.
A Network Service Provider may require load shedding arrangements to be installed to cater for abnormal operating conditions including abnormal operating conditions in which emergency frequency control schemes are intended to operate.
Transmission Network Service Providers and connected Distribution Network Service Providers must cooperate to agree arrangements to implement load shedding. The arrangements may include the opening of circuits in either a transmission or distribution network.
The Transmission Network Service Provider must specify, in the connection agreement, control and monitoring requirements to be provided by a Distribution Network Service Provider for load shedding facilities including emergency frequency control schemes.
S5.1.10.1a	Emergency frequency control schemes
(a)	A Network Service Provider must:
(1)	cooperate with AEMO in the conduct of power system frequency risk reviews and provide to AEMO all information and assistance reasonably requested by AEMO in connection with power system frequency risk reviews; and
(2)	provide to AEMO all information and assistance reasonably requested by AEMO for the development and review of EFCS settings schedules.
(b)	Where a protected event EFCS standard has been determined for an emergency frequency control scheme applicable in respect of a Network Service Provider's transmission or distribution system, the Network Service Provider must:
(1)	design, procure, commission, maintain, monitor, test, modify and report to AEMO in respect of, the emergency frequency control scheme;
(2)	perform its obligations under subparagraph (1) so as to achieve the availability and operation of the scheme in accordance with the protected event EFCS standard; and
(3)	coordinate with AEMO in relation to the monitoring and testing of the scheme once it is in operation.
(c)	A Network Service Provider must use reasonable endeavours to achieve commissioning of a new or upgraded emergency frequency control scheme within the time contemplated by the relevant power system frequency risk review or, where applicable, AEMO's request to the Reliability Panel for declaration of a non-credible contingency event as a protected event and the decision of the Reliability Panel with respect to that request.
(d)	For an over frequency scheme:
(1)	a Network Service Provider must identify which elements of the scheme (if any) can be implemented by facilities provided by a Generator for the Generator's generating unit or by modification to the facilities of the Generator or by changes to the settings of protection systems or control systems for the Generator's generating units.
(2)	Where those opportunities are identified, the Network Service Provider must notify the Generator concerned of the opportunity and must request the Generator to negotiate with the Network Service Provider to reach agreement on the modifications to be made and the other arrangements required by the Network Service Provider to comply with its obligations with respect to the scheme (including commissioning, testing, monitoring and future modification).
(3)	If the Generator declines the request, or if the Generator agrees to the request but good faith negotiations do not result in agreement being reached in a reasonable time (having regard to the implementation timetable for the scheme), the Network Service Provider may make other arrangements to implement the relevant elements of the scheme.
(4)	If the Generator accepts the request, the Generator and the Network Service Provider must each negotiate in good faith with respect to the matters referred to above.
(e)	Nothing in paragraph (d) is intended to prevent the exercise of rights under a connection agreement.
(f)	Nothing in paragraph (d) is intended to constitute or require an application to connect for the purposes of rule 5.3 or rule 5.3A. If clause 5.3.9 applies in respect of alterations for an over frequency scheme the subject of negotiations under paragraph (d), the Network Service Provider cannot charge a fee under clause 5.3.9(e) for assessment of a submission in respect of those alterations.
S5.1.10.2	Distribution Network Service Providers
A Distribution Network Service Provider must:
(a)	provide, install, operate and maintain facilities for load shedding in respect of any connection point at which the maximum load exceeds 10MW in accordance with clause 4.3.5 of the Rules;
(b)	in accordance with the provisions of the relevant connection agreement, co-operate with the Transmission Network Service Providers in conducting periodic functional testing of the facilities and emergency frequency control schemes, which must not require load to be disconnected;
(c)	apply frequency settings to relays or other facilities as determined by AEMO in consultation with the Network Service Provider; and
(d)	apply undervoltage settings to relays as notified by the Transmission Network Service Provider in accordance with clause S5.1.10.3(b).
S5.1.10.3	Transmission Network Service Providers
Transmission Network Service Providers must:
(a)	conduct periodic functional tests of the load shedding facilities and emergency frequency control schemes; and
(b)	notify Distribution Network Service Providers regarding the settings of undervoltage load shed relays as determined by AEMO in consultation with the Transmission Network Service Provider.
S5.1.11	Automatic reclosure of transmission or distribution lines
Where automatic reclose equipment is provided on transmission lines or distribution lines, check or blocking facilities must be applied to the automatic reclose equipment in those circumstances where there is any possibility of the two ends of the transmission line or distribution line being energised from sources that are not in synchronism.
S5.1.12	Rating of transmission lines and equipment
For operational purposes each Network Service Provider must, on reasonable request, advise AEMO of the maximum current that may be permitted to flow (under conditions nominated by AEMO) through each transmission line, distribution line or other item of equipment that forms part of its transmission system or distribution system.
This maximum current is called a current rating of the transmission line, distribution line or item of equipment notwithstanding that it may be determined by equipment associated with its connection to the power system (including switchgear, droppers, current transformers and protection systems).
AEMO may request for a transmission line, distribution line or other item of equipment:
(a)	a continuous current rating, being the level of current that is permitted to flow in that item of equipment for an indefinite period; and
(b)	one or more short term current ratings for a period of time nominated by AEMO after consultation with the Network Service Provider, being the level of current that is permitted to flow in that item of equipment for that period of time if the current had been less than the corresponding continuous current rating for a reasonable prior period taking into account the thermal properties of the item of equipment.
The Network Service Provider may be required by AEMO to advise different current ratings to be applied under nominated conditions including, without limitation:
(a)	ambient weather conditions;
(b)	seasons and/or times of day;
(c)	ratios of the current during an emergency to the current prior to the emergency (taking into account pre-contingent loading history where applicable); and
(d)	period of loading at the nominated level.
A Transmission Network Service Provider is entitled to advise AEMO of short term current ratings which may apply for nominated periods of time to the relevant transmission line or item of equipment provided that these ratings do not materially affect the safety of the transmission line or item of equipment, or the safety of persons. Short-term ratings for transmission lines or items of equipment may be implemented by a methodology or algorithm in a format agreed with AEMO.
S5.1.13	Information to be provided
A Network Service Provider must, in response to a connection enquiry or an application to connect made in accordance with clause 5.3.2 of the Rules, provide the connection applicant electrical design information relevant to the nominal point of connection in accordance with a relevant requirement of schedules 5.2, 5.3 or 5.3a.
Schedule 5.2	Conditions for Connection of Generators
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.
S5.2.1	Outline of requirements
(a)	This schedule sets out details of additional requirements and conditions that Generators must satisfy as a condition of connection of a generating system to the power system.
(b)	This schedule does not apply to any generating system that is:
(1)	subject to an exemption from registration under clause 2.2.1(c); or
(2)	eligible for exemption under any guidelines issued under clause 2.2.1(c),
and which is connected or intended for use in a manner the Network Service Provider considers is unlikely to cause a material degradation in the quality of supply to other Network Users.
(c)	This schedule also sets out the requirements and conditions which subject to clause 5.2.5 of the Rules, are obligations on Generators:
(1)	to co-operate with the relevant Network Service Provider on technical matters when making a new connection; and
(2)	to provide information to the Network Service Provider or AEMO.
(d)	The equipment associated with each generating system must be designed to withstand without damage the range of operating conditions which may arise consistent with the system standards.
(e)	Generators must comply with the performance standards and any attached terms or conditions of agreement agreed with the Network Service Provider or AEMO in accordance with a relevant provision of schedules 5.1a or 5.1.
(f)	This schedule does not set out arrangements by which a Generator may enter into an agreement or contract with AEMO to:
(1)	provide additional services that are necessary to maintain power system security; or
(2)	provide additional services to facilitate management of the market.
(g)	This schedule provides for automatic access standards and the determination of negotiated access standards which once determined, must be recorded together with the automatic access standards in a connection agreement and registered with AEMO as performance standards.
S5.2.2	Application of Settings
A Generator must only apply settings to a control system or a protection system that are necessary to comply with performance requirements of this schedule 5.2 if the settings have been approved in writing by the relevant Network Service Provider and, if the requirement is one that would involve AEMO under clause 5.3.4A(c) of the Rules, also by AEMO. A Generator must not allow its generating unit to supply electricity to the power system without such prior approval.
If a Generator seeks approval from the Network Service Provider to apply or change a setting, then (except in the case of settings to be applied or changed by the Generator in connection with an emergency frequency control scheme) approval must not be withheld unless the Network Service Provider or, if the requirement is one that would involve AEMO under clause 5.3.4A(c) of the Rules, AEMO, reasonably determines that the changed setting would cause the generating unit to not comply with the relevant performance standard or cause an inter-regional or intra-regional  power transfer capability to be reduced.
If the Network Service Provider or, if the requirement is one that would involve AEMO under clause 5.3.4A(c) of the Rules, AEMO, reasonably determines that a setting of a generating unit's control system or protection system needs to change to comply with the relevant performance standard or to maintain or restore an inter-regional or intra-regional power transfer capability, the Network Service Provider or AEMO (as applicable) must consult with the relevant Generator, and the Network Service Provider may request in writing that a setting be applied in accordance with the determination.
The Network Service Provider may also request a test to verify the performance of the relevant plant with the new setting. The Network Service Provider must provide AEMO with a copy of its request to a Generator to apply a setting or to conduct a test.
A Generator who receives such a request must arrange for the notified setting to be applied as requested and for a test to be conducted as requested. After the test, the Generator must, on request, provide both AEMO and the Network Service Provider with a report of a requested test, including evidence of its success or failure. Such a report of a test is confidential information.
A Generator must not change a setting requested by the Network Service Provider without its prior written agreement. If the Network Service Provider requires a Generator to change a setting within 18 months of a previous request, the Network Service Provider must pay the Generator its reasonable costs of changing the setting and conducting the tests as requested.
S5.2.3	Technical matters to be coordinated
(a)	A Generator and the relevant Network Service Provider must use all reasonable endeavours to agree upon relevant technical matters in respect of each new or altered connection of a generating system to a network including:
(1)	design at the connection point;
(2)	physical layout adjacent to the connection point;
(3)	primary protection and backup protection (clause S5.2.5);
(4)	control characteristics (clause S5.2.5);
(5)	communications facilities (clause S5.2.6);
(6)	insulation co-ordination and lightning protection (paragraph (b));
(7)	fault levels and fault clearance (clause S5.2.8);
(8)	switching and isolation facilities (clause S5.2.8);
(9)	interlocking and synchronising arrangements; and
(10)	metering installations.
(b)	A Generator must ensure that in designing a generating system's electrical plant, including any substation for the connection of the generating system to the network, to operate at the same nominal voltage as at the connection point:
(1)	the plant complies with the relevant Australian Standards unless a provision of these Rules allows or requires otherwise;
(2)	the earthing of the plant complies with the ENA EG1-2006: Substation Earthing Guide to reduce step and touch potentials to safe levels;
(3)	the plant is capable of withstanding, without damage the voltage impulse levels specified in the connection agreement;
(4)	the insulation levels of the plant are co-ordinated with the insulation levels of the network to which the generating system is connected as specified in the connection agreement; and
(5)	safety provisions in respect of the plant comply with requirements applicable to the participating jurisdiction in which the generating system is located, as notified by the Network Service Provider.
(c)	If no relevant Australian Standard exists for the purposes of paragraph (b)(1), the Generator must agree with the Network Service Provider for the Generator to comply with another relevant standard.
S5.2.4	Provision of information
(a)	A Generator or person who is negotiating a connection agreement with a Network Service Provider must promptly on request by AEMO or the Network Service Provider provide all data in relation to that generating system specified in schedule 5.5.
(b)	A Generator, or person required under the Rules to register as the Generator in respect of a generating system comprised of generating units with a combined nameplate rating of 30 MW or more, by the earlier of:
(1)	the day on which an application to connect is made under clause 5.3.4(a);
(2)	the day on which amendments to performance standards are submitted under rule 4.14(p) or clause 5.3.9(b);
(3)	three months before commissioning of a generating system or planned alteration to a generating system; or
(4)	5 business days before commissioning of a generating system alteration that is repairing plant after a plant failure, if plant performance after the alteration will differ from performance prior to the plant failure,
must provide:
(5)	to AEMO and the relevant Network Service Provider(s) (including the relevant Transmission Network Service Provider in respect of an embedded generating unit):
(i)	information about the protections systems of the generating system;
(ii)	information about the control systems of the generating system including:
(A)	a set of functional block diagrams, including all functions between feedback signals and generating system output;
(B)	the parameters of each functional block, including all settings, gains, time constants, delays, deadbands and limits;
(C)	the characteristics of non-linear elements;
(D)	encrypted models in a form suitable for the software simulation products nominated by AEMO in the Power System Model Guidelines;
(6)	to AEMO, the model source code (in the circumstances required by the Power System Model Guidelines) associated with the power system simulation model in subparagraph (ii)(D) in an unencrypted form suitable for at least one of the software simulation products nominated by AEMO in the Power System Model Guidelines, and in a form that would allow conversion for use with other software products nominated by AEMO in the Power System Model Guidelines;
(7) 	 [Deleted]
(7A)	to AEMO and the relevant Network Service Provider(s), any other information specified in the Power System Model Guidelines, Power System Design Data Sheet and Power System Setting Data Sheet; and
(8)	to AEMO and the relevant Network Service Providers (including the relevant Transmission Network Service Provider in respect of an embedded generating unit) a releasable user guide.
(b1)	The information provided under paragraph (b) must contain sufficient detail for AEMO and the relevant Network Service Provider(s) to perform power system simulation studies in accordance with the requirements and circumstances specified in the Power System Model Guidelines.
(c)	The information provided under paragraph (b) must:
(1)	encompass all control systems that respond to voltage or frequency disturbances on the power system, and which are either integral to the generating units or otherwise part of the generating system, including those applying to reactive power equipment that forms part of the generating system; and
(2)	conform with the applicable models developed in accordance with the Power System Model Guidelines, or an alternative model agreed with AEMO to be necessary to adequately represent the generating plant to carry out load flow and dynamic simulations and (where applicable) specialised power system studies.
(d)	The Generator must provide to AEMO information that updates the information provided under clause S5.2.4(b) and must provide to the relevant Network Service Providers information that updates the information provided under clause S5.2.4(b)(5):
(1)	within 3 months after commissioning tests or other tests undertaken in accordance with clause 5.7.3 are completed;
(2)	when the Generator becomes aware that the information is incomplete, inaccurate or out of date; or
(3)	on request by AEMO or the relevant Network Service Provider, where AEMO or the relevant Network Service Provider considers that the information in incomplete, inaccurate or out of date.
(d1)	A Generator is only required to provide new information under clause S5.2.4(d) to the extent that it is different to the information previously provided under clause S5.2.4(b).
(e)	For the purposes of clause S5.2.4(e1), a Connection Applicant must be registered as an Intending Participant in accordance with rule 2.7.
(e1)	For the purposes of clause 5.3.2(f), the technical information that a Network Service Provider must, if requested, provide to a Connection Applicant in respect of a proposed connection for a generating system includes:
(1)	the highest expected single phase and three phase fault levels at the connection point with the generating system not connected;
(2)	the clearing times of the existing protection systems that would clear a fault at the location at which the new connection would be connected into the existing transmission system or distribution system;
(3)	the expected limits of voltage fluctuation, harmonic voltage distortion and voltage unbalance at the connection point with the generating system not connected;
(4)	technical information relevant to the connection point with the generating system not synchronised including equivalent source impedance information, sufficient to estimate fault levels, voltage fluctuations, harmonic voltage distortion (for harmonics relevant to the generating system) and voltage unbalance;
(5)	information relating to the performance of the national grid that is reasonably necessary for the Connection Applicant to prepare an application to connect, including:
(i)	a model of the power system, including relevant considered projects and the range of expected operating conditions, sufficient to carry out load flow and dynamic simulations; and
(ii)	information on inter-regional and intra-regional power transfer capabilities and relevant plant ratings; and
(6)	the Network Service Provider's expected three phase fault level at the connection point for the generating system following the connection of the generating system.
(f)	All information provided under this clause S5.2.4 must be treated as confidential information.
S5.2.5	Technical requirements
S5.2.5.1	Reactive power capability
Automatic access standard
(a)	The automatic access standard is a generating system operating at:
(1)	any level of active power output; and
(2)	any voltage at the connection point within the limits established under clause S5.1a.4 without a contingency event,
must be capable of supplying and absorbing continuously at its connection point an amount of reactive power of at least the amount equal to the product of the rated active power of the generating system and 0.395.
Minimum access standard
(b)	The minimum access standard is no capability is required to supply or absorb reactive power at the connection point.
Negotiated access standard
(c)	When negotiating a negotiated access standard, the Generator, the Network Service Provider and AEMO:
(1)	must, subject to any agreement under subparagraph (d)(4), ensure that the reactive power capability of the generating system is consistent with maintaining power system security and sufficient to ensure that all relevant system standards are met before and after credible contingency events under normal and planned outage operating conditions of the power system, taking into account existing power system conditions, considered projects and any other project for the connection of a Network User for which:
(i)	there is an existing connection agreement; or
(ii)	the Network Service Provider and AEMO reasonably consider the Network User will connect to the power system;
(2)	may negotiate either a range of reactive power absorption and supply, or a range of power factor, at the connection point, within which the plant must be operated; and
(3)	may negotiate a limit that describes how the reactive power capability varies as a function of active power output due to a design characteristic of the plant.
(d)	If the generating system is not capable of the level of performance established under paragraph (c)(1) the Generator, depending on what is reasonable in the circumstances, must:
(1)	pay compensation to the Network Service Provider for the provision of the deficit of reactive power (supply and absorption) from within the network;
(2)	install additional equipment connecting at the generating system's connection point or another location, to provide the deficit of reactive power (supply and absorption), and such equipment is deemed to be part of the generating system;
(3)	reach a commercial arrangement with a Registered Participant to provide the deficit of reactive power (supply and absorption); or
(4)	if the inability to meet the performance level only occurs for particular operating conditions, agree to and document as part of the proposed negotiated access standard, operational arrangements by which the plant can achieve an agreed level of performance for those operating conditions.
(e)	The Generator may select one or more options referred to in paragraph (d).
General requirements
(f)	A performance standard must record the agreed value for rated active power and where relevant the method of determining the value.
(g)	A performance standard for consumption of energy by a generating system when not supplying or absorbing reactive power under an ancillary services agreement is to be established under clause S5.3.5 as if the Generator were a Market Customer.
S5.2.5.2	Quality of electricity generated
(a)	For the purpose of this clause S5.2.5.2 in respect of a synchronous generating unit, AS 1359.101 and IEC 60034-1 are plant standards for harmonic voltage distortion.
Automatic access standard
(b)	The automatic access standard is a generating system when generating and when not generating must not produce at any of its connection points for generation:
(1)	voltage fluctuation greater than the limits allocated by the Network Service Provider under clause S5.1.5(a);
(2)	harmonic voltage distortion greater than the emission limits specified by a plant standard under paragraph (a) or allocated by the Network Service Provider under clause S5.1.6(a); and
(3)	voltage unbalance greater than the limits allocated by the Network Service Provider in accordance with clause S5.1.7(c).
Minimum access standard
(c)	The minimum access standard is a generating system when generating and when not generating must not produce at any of its connection points for generation:
(1)	voltage fluctuations greater than limits determined under clause S5.1.5(b);
(2)	harmonic voltage distortion more than the lesser of the emission limits determined by the relevant Network Service Provider under clause  S5.1.6(b) and specified by a plant standard under paragraph (a); and
(3)	voltage unbalance more than limits determined under clause S5.1.7(c).
Negotiated access standard
(d)	A negotiated access standard negotiated under this clause S5.2.5.2 must not prevent the Network Service Provider meeting the system standards or contractual obligations to existing Network Users.
S5.2.5.3	Generating system response to frequency disturbances
(a)	For the purposes of this clause S5.2.5.3:
normal operating frequency band, operational frequency tolerance band, or extreme frequency excursion tolerance limits are references to the widest range specified for those terms for any condition (including an "island" condition) in the frequency operating standards that apply to the region in which the generating unit is located.
stabilisation time and recovery time mean the longest times allowable for the frequency of the power system to remain outside the operational frequency tolerance band and the normal operating frequency band, respectively, for any condition (including an "island" condition) in the frequency operating standards that apply to the region in which the generating unit is located.
transient frequency limit and transient frequency time mean the values of 47.5 Hz and 9 seconds respectively, or such other values determined by the Reliability Panel.
Automatic access standard
(b)	The automatic access standard is a generating system and each of its generating units must be capable of continuous uninterrupted operation for frequencies in the following ranges:
(1)	the lower bound of the extreme frequency excursion tolerance limits to the lower bound of the operational frequency tolerance band for at least the stabilisation time;
(2)	the lower bound of the operational frequency tolerance band to the lower bound of the normal operating frequency band, for at least the recovery time including any time spent in the range under subparagraph (1);
(3)	the normal operating frequency band for an indefinite period;
(4)	the upper bound of the normal operating frequency band to the upper bound of the operational frequency tolerance band, for at least the recovery time including any time spent in the range under subparagraph (5); and
(5)	the upper bound of the operational frequency tolerance band to the upper bound of the extreme frequency excursion tolerance limits for at least the stabilisation time,
unless the rate of change of frequency is outside the range of –4 Hz to 4 Hz per second for more than 0.25 seconds, -3 Hz to 3 Hz per second for more than one second, or such other range as determined by the Reliability Panel from time to time.
Note:
The automatic access standard is illustrated in the following diagram. To the extent of any inconsistency between the diagram and paragraph (b), paragraph (b) prevails.

Minimum access standard
(c)	The minimum access standard is a generating system and each of its generating units must be capable of continuous uninterrupted operation for frequencies in the following ranges:
(1)	the lower bound of the extreme frequency excursion tolerance limits to the transient frequency limit for at least the transient frequency time;
(2)	the transient frequency limit to the lower bound of the operational frequency tolerance band for at least the stabilisation time;
(3)	the lower bound of the operational frequency tolerance band to the lower bound of the normal operating frequency band for at least the recovery time including any time spent in the ranges under subparagraphs (1) and (2);
(4)	the normal operating frequency band for an indefinite period;
(5)	the upper bound of the normal operating frequency band to the upper bound of the operational frequency tolerance band for at least the recovery time including any time spent in the ranges under subparagraph (6) unless the generating system has a protection system to trip a generating unit if the frequency exceeds a level agreed with AEMO; and
(6)	in respect of a generating system:
(i)	of 30 MW or more; and
(ii)	that does not have a protection system to trip the generating unit if the frequency exceeds a level agreed with AEMO,
the upper bound of the operational frequency tolerance band to the upper bound of the extreme frequency excursion tolerance limits (including an "island" condition) for at least the transient frequency time,
unless the rate of change of frequency is outside the range of -2 Hz to 2 Hz per second for more than 0.25 seconds, -1 Hz to 1 Hz per second for more than one second or such other range as determined by the Reliability Panel from time to time.
Note:
The minimum access standard is illustrated in the following diagram. To the extent of any inconsistency between the diagram and paragraph (c), paragraph (c) prevails.

Negotiated access standard
(d)	A negotiated access standard can be accepted by the Network Service Provider provided that AEMO and the Network Service Provider agree that the frequency would be unlikely to fall below the lower bound of the operational frequency tolerance band as a result of over-frequency tripping of generating units.
S5.2.5.4	Generating system response to voltage disturbances
Automatic access standard
(a)	The automatic access standard is a generating system and each of its generating units must be capable of continuous uninterrupted operation where a power system disturbance causes the voltage at the connection point to vary within the following ranges:
(1)	over 130% of normal voltage for a period of at least 0.02 seconds after T(ov);
(2)	125% to 130% of normal voltage for a period of at least 0.2 seconds after T(ov);
(3)	120% to 125% of normal voltage for a period of at least 2.0 seconds after T(ov);
(4)	115% to 120% of normal voltage for a period of at least 20.0 seconds after T(ov);
(5)	110% to 115% of normal voltage for a period of at least 20 minutes after T(ov);
(6)	90% to 110% of normal voltage continuously;
(7)	80% to 90% of normal voltage for a period of at least 10 seconds after T(uv); and
(8)	70% to 80% of normal voltage for a period of at least 2 seconds after T(uv),
where T(ov) means a point in time when the voltage at the connection point first varied above 110% of normal voltage before returning to between 90% and 110% of normal voltage, and T(uv) means a point in time when the voltage at the connection point first varied below 90% of normal voltage before returning to between 90% and 110% of normal voltage.
Minimum access standard
(b)	The minimum access standard is a generating system including all operating generating units must be capable of continuous uninterrupted operation where a power system disturbance causes the voltage at the connection point to vary within the following ranges:
(1)	115% to 120% of normal voltage for a period of at least 0.1 seconds after T(ov);
(2)	110% to 115% of normal voltage for a period of at least 0.9 seconds after T(ov);
(3)	90% to 110% of normal voltage continuously, provided that the ratio of voltage to frequency (as measured at the connection point and expressed as a percentage of normal voltage and a percentage of 50 Hz) does not exceed:
(i)	a value of 1.15 for more than 2 minutes; or
(ii)	a value of 1.10 for more than 10 minutes;
(4)	80% to 90% of normal voltage for a period of at least 5 seconds after T(uv); and
(5)	70% to 80% of normal voltage for a period of at least 2 seconds after T(uv),
where T(ov) means a point in time when the voltage at the connection point first varied above 110% of normal voltage before returning to between 90% and 110% of normal voltage, and T(uv) means a point in time when the voltage at the connection point first varied below 90% of normal voltage before returning to between 90% and 110% of normal voltage.
Negotiated access standard
(c)	In negotiating a negotiated access standard, a generating system and each of its operating generating units must be capable of continuous uninterrupted operation for the range of voltages specified in the automatic access standard, except where AEMO and the Network Service Provider agree that the total reduction of generation in the power system as a result of any voltage excursion within levels specified by the automatic access standard would not exceed 100 MW, or a greater limit based on what AEMO and the Network Service Provider both consider to be reasonable in the circumstances.
(d)	In carrying out assessments of proposed negotiated access standards under this clause S5.2.5.4, AEMO and the Network Service Provider must at a minimum, in addition to the requirements of clauses 5.3.4A(d1) and 5.3.4A(g) respectively, take into account:
(1)	the expected performance of existing networks and considered projects; and
(2)	the expected performance of existing generating plant and other relevant projects.
(e)	[Deleted]
General requirement
(f)	The access standard must include any operational arrangements necessary to ensure the generating system and each of its generating units will meet its agreed performance levels under abnormal network or generating system conditions.
S5.2.5.5	Generating system response to disturbances following contingency events
(a)	In this clause S5.2.5.5 a fault includes a fault of the relevant type having a metallic conducting path.
Automatic access standard
(b)	The automatic access standard is:
(1)	for a generating system and each of its generating units, the requirements of paragraphs (c) and (d);
(2)	for a generating system comprised solely of synchronous generating units, the requirements of paragraph (e);
(3)	for a generating system comprised solely of asynchronous generating units, the requirements of paragraphs (f) to (i); and
(4)	for a generating system comprised of synchronous generating units and asynchronous generating units:
(i)	for that part of the generating system comprised of synchronous generating units, the requirements of paragraph (e); and
(ii)	for that part of the generating system comprised of asynchronous generating units, the requirements of paragraphs (f) to (i).
All generating systems
(c)	A generating system and each of its generating units must remain in continuous uninterrupted operation for any disturbance caused by:
(1)	a credible contingency event;
(2)	a three phase fault in a transmission system cleared by all relevant primary protection systems;
(3)	a two phase to ground, phase to phase or phase to ground fault in a transmission system cleared in:
(i)	the longest time expected to be taken for a relevant breaker fail protection system to clear the fault; or
(ii)	if a protection system referred to in subparagraph (i) is not installed, the greater of the time specified in column 4 of Table S5.1a.2 (or if none is specified, 430 milliseconds) and the longest time expected to be taken for all relevant primary protection systems to clear the fault; or
(4)	a three phase, two phase to ground, phase to phase or phase to ground fault in a distribution network cleared in:
(i)	the longest time expected to be taken for the breaker fail protection system to clear the fault; or
(ii)	if a protection system referred to in subparagraph (i) is not installed, the greater of 430 milliseconds and the longest time expected to be taken for all relevant primary protection systems to clear the fault,
provided that the event is not one that would disconnect the generating unit from the power system by removing network elements from service.
(d)	A generating system and each of its generating units must remain in continuous uninterrupted operation for a series of up to 15 disturbances within any five minute period caused by any combination of the events described in paragraph (c) where:
(1)	up to six of the disturbances cause the voltage at the connection point to drop below 50% of normal voltage;
(2)	in parts of the network where three-phase automatic reclosure is permitted, up to two of the disturbances are three phase faults, and otherwise, up to one three phase fault where voltage at the connection point drops below 50% of normal voltage;
(3)	up to one disturbance is cleared by a breaker fail protection system or similar back-up protection system;
(4)	up to one disturbance causes the voltage at the connection point to vary within the ranges under clause S5.2.5.4(a)(7) and (a)(8);
(5)	the minimum clearance from the end of one disturbance and commencement of the next disturbance may be zero milliseconds; and
(6)	all remaining disturbances are caused by faults other than three phase faults,
provided that none of the events would result in:
(7)	the islanding of the generating system or cause a material reduction in power transfer capability by removing network elements from service;
(8)	the cumulative time that voltage at the connection point is lower than 90% of normal voltage exceeding 1,800 milliseconds within any five minute period; or
(9)	the time integral, within any five minute period, of the difference between 90% of normal voltage and the voltage at the connection point when the voltage at the connection point is lower than 90% of normal voltage exceeding 1 pu second.
Synchronous generating systems
(e)	Subject to any changed power system conditions or energy source availability beyond the Generator's reasonable control, a generating system comprised of synchronous generating units, in respect of the types of fault described in subparagraphs (c)(2) to (4), must supply to or absorb from the network:
(1)	to assist the maintenance of power system voltages during the fault, capacitive reactive current of at least the greater of its pre-disturbance reactive current and 4% of the maximum continuous current of the generating system including all operating synchronous generating units (in the absence of a disturbance) for each 1% reduction (from the level existing just prior to the fault) of connection point voltage during the fault;
(2)	after clearance of the fault, reactive power sufficient to ensure that the connection point voltage is within the range for continuous uninterrupted operation under clause S5.2.5.4; and
(3)	from 100 milliseconds after clearance of the fault, active power of at least 95% of the level existing just prior to the fault.
Asynchronous generating systems
(f)	Subject to any changed power system conditions or energy source availability beyond the Generator's reasonable control, a generating system comprised of asynchronous generating units, in respect of the types of fault described in subparagraphs (c)(2) to (4), must have facilities capable of supplying to or absorbing from the network:
(1)	to assist the maintenance of power system voltages during the fault:
(i)	capacitive reactive current in addition to its pre-disturbance level of at least 4% of the maximum continuous current of the generating system including all operating asynchronous generating units (in the absence of a disturbance) for each 1% reduction of voltage at the connection point below the relevant range in which a reactive current response must commence, as identified in subparagraph (g)(1), with the performance standards to record the required response agreed with AEMO and the Network Service Provider; and
(ii)	inductive reactive current in addition to its pre-disturbance level of at least 6% of the maximum continuous current of the generating system including all operating asynchronous generating units (in the absence of a disturbance) for each 1% increase of voltage at the connection point above the relevant range in which a reactive current response must commence, as identified in subparagraph (g)(1), with the performance standards to record the required response agreed with AEMO and the Network Service Provider,
during the disturbance and maintained until connection point voltage recovers to between 90% and 110% of normal voltage, or such other range agreed with the Network Service Provider and AEMO, except for voltages below the relevant threshold identified in paragraph (h); and
(2)	from 100 milliseconds after clearance of the fault, active power of at least 95% of the level existing just prior to the fault.
(g)	For the purpose of paragraph (f):
(1)	the generating system must commence a response when the voltage is in an under-voltage range of 85% to 90% or an over-voltage range of 110% to 115% of normal voltage. These ranges may be varied with the agreement of the Network Service Provider and AEMO (provided the magnitude of the range between the upper and lower bounds remains at Δ5%); and
(2)	the reactive current response must have a rise time of no greater than 40 milliseconds and a settling time of no greater than 70 milliseconds and must be adequately damped.
(h)	Despite paragraph (f), a generating system is not required to provide a capacitive reactive current response in accordance with subparagraph (f)(1)(i) where:
(1)	the generating system is directly connected to the power system with no step-up or connection transformer; and
(2)	voltage at the connection point is 5% or lower of normal voltage.
(i)	Subject to paragraph (h), despite the amount of reactive current injected or absorbed during voltage disturbances, and subject to thermal limitations and energy source availability, a generating system must make available at all times:
(1)	sufficient current to maintain rated apparent power of the generating system including all operating generating units (in the absence of a disturbance), for all connection point voltages above 115% (or otherwise, above the over-voltage range agreed in accordance with subparagraph (g)(1)); and
(2)	the maximum continuous current of the generating system including all operating generating units (in the absence of a disturbance) for all connection point voltages below 85% (or otherwise, below the under-voltage range agreed in accordance with subparagraph (g)(1)),
except that AEMO and the Network Service Provider may agree limits on active current injection where required to maintain power system security and/or the quality of supply to other Network Users.
Minimum access standard
(j)	The minimum access standard is:
(1)	for a generating system and each of its generating units, the requirements of paragraphs (k) and (l);
(2)	for a generating system comprised solely of synchronous generating units, the requirements of paragraph (m);
(3)	for a generating system comprised solely of asynchronous generating units, the requirements of paragraphs (n) to (p); and
(4)	for a generating system comprised of synchronous generating units and asynchronous generating units:
(i)	for that part of the generating system comprised of synchronous generating units, the requirements of paragraph (m); and
(ii)	for that part of the generating system comprised of asynchronous generating units, the requirements of paragraphs (n) to (p).
All generating systems
(k)	A generating system and each of its generating units must remain in continuous uninterrupted operation for any disturbance caused by:
(1)	a credible contingency event; or
(2)	a single phase to ground, phase to phase or two phase to ground fault in a transmission system or distribution network cleared in the longest time expected to be taken for all relevant primary protection systems to clear the fault, unless AEMO and the Network Service Provider agree that the total reduction of generation in the power system due to that fault would not exceed 100 MW, or a greater limit based on what AEMO and the Network Service Provider both consider to be reasonable in the circumstances,
provided that the event is not one that would disconnect the generating unit from the power system by removing network elements from service.
(l)	A generating system and each of its generating units must remain in continuous uninterrupted operation for a series of up to six disturbances within any five minute period caused by any combination of the events described in paragraph (k) where:
(1)	up to three of the disturbances cause the voltage at the connection point to drop below 50% of normal voltage;
(2)	up to one disturbance causes the voltage at the connection point to vary within the ranges agreed by AEMO and the Network Service Provider under clause S5.2.5.4(a)(7), (a)(8), (b)(4) or (b)(5) (as appropriate);
(3)	the time difference between the clearance of one disturbance and commencement of the next disturbance exceeds 200 milliseconds;
(4)	no more than three of the disturbances occur within 30 seconds; and
(5)	all disturbances are caused by faults other than three phase faults,
provided that none of the events would result in:
(6)	the islanding of the generating system or cause a material reduction in power transfer capability by removing network elements from service;
(7)	the cumulative time that voltage at the connection point is lower than 90% of normal voltage exceeding 1,000 milliseconds within any five minute period; or
(8)	the time integral, within any five minute period, of the difference between 90% of normal voltage and the voltage at the connection point when the voltage at the connection point is lower than 90% of normal voltage exceeding 0.5 pu second,
and there is a minimum of 30 minutes where no disturbances occur following a five minute period of multiple disturbances.
Synchronous generating systems
(m)	Subject to any changed power system conditions or energy source availability beyond the Generator's reasonable control after clearance of the fault, a generating system comprised of synchronous generating units, in respect of the types of fault described in subparagraph (k)(2) must:
(1)	deliver active power to the network, and supply or absorb leading or lagging reactive power, sufficient to ensure that the connection point voltage is within the range for continuous uninterrupted operation agreed under clause S5.2.5.4; and
(2)	return to at least 95% of the pre-fault active power output, after clearance of the fault, within a period of time agreed by the Connection Applicant, AEMO and the Network Service Provider.
Asynchronous generating systems
(n)	Subject to any changed power system conditions or energy source availability beyond the Generator's reasonable control, a generating system comprised of asynchronous generating units must:
(1)	for the types of fault described in subparagraph (k)(2), and to assist the maintenance of power system voltages during the fault, have facilities capable of supplying to or absorbing from the network:
(i)	capacitive reactive current in addition to its pre-disturbance level of at least 2% of the maximum continuous current of the generating system including all operating asynchronous generating units (in the absence of a disturbance) for each 1% reduction of voltage at the connection point below the relevant range in which a reactive current response must commence, as identified in paragraph (o)(1), with the performance standards to record the required response agreed with AEMO and the Network Service Provider; and
(ii)	inductive reactive current in addition to its pre-disturbance level of at least 2% of the maximum continuous current of the generating system including all operating asynchronous generating units (in the absence of a disturbance) for each 1% increase of voltage at the connection point above the relevant range in which a reactive current response must commence, as identified in paragraph (o)(1), with the performance standards to record the required response agreed with AEMO and the Network Service Provider,
during the disturbance and maintained until connection point voltage recovers to between 90% and 110% of normal voltage, or such other range agreed with the Network Service Provider and AEMO, except for voltages below the relevant threshold identified in paragraph (p); and
(2)	return to at least 95% of the pre-fault active power output, after clearance of the fault, within a period of time agreed by the Connection Applicant, AEMO and the Network Service Provider.
(o)	For the purpose of paragraph (n):
(1)	the generating system must commence a response when the voltage is in an under-voltage range of 80% to 90% or an over-voltage range of 110% to 120% of normal voltage. These ranges may be varied with the agreement of the Network Service Provider and AEMO (provided the magnitude of the range between the upper and lower bounds remains at Δ10%);
(2)	where AEMO and the Network Service Provider require the generating system to sustain a response duration of 2 seconds or less, the reactive current response must have a rise time of no greater than 40 milliseconds and a settling time of no greater than 70 milliseconds and must be adequately damped; and
(3)	where AEMO and the Network Service Provider require the generating system to sustain a response duration of greater than 2 seconds, the reactive current rise time and settling time must be as soon as practicable and must be adequately damped.
(p)	Despite paragraph (n), a generating system is not required to provide a capacitive reactive current response in accordance with subparagraph (n)(1)(i) where:
(1)	voltage at the connection point is 15% or lower of normal voltage; or
(2)	where the generating system is directly connected to the power system with no step-up or connection transformer, voltage at the connection point is 20% or lower of normal voltage.
Negotiated access standard
(q)	In carrying out assessments of proposed negotiated access standards under this clause S5.2.5.5, the Network Service Provider and AEMO must take into account, without limitation:
(1)	the expected performance of:
(i)	existing networks and considered projects;
(ii)	existing generating plant and other relevant projects; and
(iii)	control systems and protection systems, including auxiliary systems and automatic reclose equipment; and
(2)	the expected range of power system operating conditions.
(r)	A proposed negotiated access standard may be accepted if the connection of the plant at the proposed access level would not cause other generating plant or loads to trip as a result of an event, when they would otherwise not have tripped for the same event.
General requirement
All generating systems
(s)	The performance standard must include any operational arrangements to ensure the generating system including all operating generating units will meet its agreed performance levels under abnormal network or generating system conditions.
(t)	When assessing multiple disturbances, a fault that is re-established following operation of automatic reclose equipment shall be counted as a separate disturbance.
Asynchronous generating systems
(u)	For the purpose of paragraphs (f) and (n):
(1)	the reactive current contribution may be limited to the maximum continuous current of a generating system, including its operating asynchronous generating units;
(2)	the reactive current contribution and voltage deviation described may be measured at a location other than the connection point (including within the relevant generating system) where agreed with AEMO and the Network Service Provider, in which case the level of injection and absorption will be assessed at that agreed location;
(3)	the reactive current contribution required may be calculated using phase to phase, phase to ground or sequence components of voltages. The ratio of the negative sequence to positive sequence components of the reactive current contribution must be agreed with AEMO and the Network Service Provider for the types of disturbances listed in this clause S5.2.5.5; and
(4)	the performance standards must record all conditions (which may include temperature) considered relevant by AEMO and the Network Service Provider under which the reactive current response is required.
Synchronous generating systems and units
(v)	For a generating system comprised solely of synchronous generating units, the reactive current contribution may be limited to 250% of the maximum continuous current of the generating system.
(w)	For a synchronous generating unit within a generating system (other than a generating system described in paragraph (v)), the reactive current contribution may be limited to 250% of the maximum continuous current of that synchronous generating unit.
S5.2.5.6	Quality of electricity generated and continuous uninterrupted operation
Minimum access standard
The minimum access standard is a generating system including each of its operating generating units and reactive plant, must not disconnect from the power system as a result of voltage fluctuation, harmonic voltage distortion and voltage unbalance conditions at the connection point within the levels specified in clauses S5.1a.5, S5.1a.6 and S5.1a.7.
S5.2.5.7	Partial load rejection
(a)	For the purposes of this clause S5.2.5.7 minimum generation means minimum sent out generation for continuous stable operation.
(b)	[Deleted]
Automatic access standard
(c)	The automatic access standard is a generating system must be capable of continuous uninterrupted operation during and following a power system load reduction of 30% from its pre-disturbance level or equivalent impact from separation of part of the power system in less than 10 seconds, provided that the loading level remains above minimum generation.
Minimum access standard
(d)	The minimum access standard is a generating system must be capable of continuous uninterrupted operation during and following a power system load reduction of 5% or equivalent impact from separation of part of the power system in less than 10 seconds provided that the loading level remains above minimum generation.
[Deleted]
(e)	[Deleted]
(f)	[Deleted]
General requirements
(g)	The agreed partial load rejection performance must be recorded in the performance standards.
S5.2.5.8	Protection of generating systems from power system disturbances
Minimum access standard
(a)	The minimum access standard is:
(1)	subject to subparagraph (2) and paragraph (e), for a generating system or any of its generating units that is required by a Generator or Network Service Provider to be automatically disconnected from the power system in response to abnormal conditions arising from the power system, the relevant protection system or control system must not disconnect the generating system for:
(i)	conditions for which it must remain in continuous uninterrupted operation; or
(ii)	conditions it must withstand under the Rules; and
(2)	a generating system with a nameplate rating of 30MW or more, or generating system comprised of generating units with a combined nameplate rating of 30 MW or more, connected to a transmission system must have facilities to automatically and rapidly reduce its generation:
(i)	by at least half, if the frequency at the connection point exceeds a level nominated by AEMO (not less than the upper limit of the operational frequency tolerance band) and the duration above this frequency exceeds a value nominated by AEMO where the reduction may be achieved:
(A)	by reducing the output of the generating system within 3 seconds, and holding the output at the reduced level until the frequency returns to within the normal operating frequency band; or
(B)	by disconnecting the generating system from the power system within 1 second; or
(ii)	in proportion to the difference between the frequency at the connection point and a level nominated by AEMO (not less than the upper limit of the operational frequency tolerance band), such that the generation is reduced by at least half, within 3 seconds of the frequency reaching the upper limit of the extreme frequency excursion tolerance limits.
[Deleted]
(b)	[Deleted]
General requirements
(c)	AEMO or the Network Service Provider may require that an access standard include a requirement for the generating system to be automatically disconnected by a local or remote control scheme whenever the part of the network to which it is connected has been disconnected from the national grid, forming an island that supplies a Customer.
(d)	The access standard must include specification of conditions for which the generating unit or generating system must trip and must not trip.
(e)	Notwithstanding clauses S5.2.5.3, S5.2.5.4, S5.2.5.5, S5.2.5.6 and S5.2.5.7, a generating system may be automatically disconnected from the power system under any of the following conditions:
(1)	in accordance with an ancillary services agreement between the Generator and AEMO;
(2)	where a load that is not part of the generating system has the same connection point as the generating system and AEMO and the Network Service Provider agree that the disconnection would in effect be under-frequency load shedding;
(3)	where the generating system is automatically disconnected under paragraph (a), clause S5.2.5.9 or by an emergency frequency control scheme;
(4)	where the generating system is automatically disconnected under clause S5.2.5.10; or
(5)	in accordance with an agreement between the Generator and a Network Service Provider (including an agreement in relation to an emergency control scheme under clause S5.1.8) to provide a service that AEMO agrees is necessary to maintain or restore power system security in the event of a specified contingency event.
(f)	The Network Service Provider is not liable for any loss or damage incurred by the Generator or any other person as a consequence of a fault on either the power system, or within the Generator's facility.
S5.2.5.9	Protection systems that impact on power system security
Automatic access standard
(a)	The automatic access standard is:
(1)	subject to clauses S5.1.9(k) and S5.1.9(l), primary protection systems must be provided to disconnect from the power system any faulted element in a generating system and in protection zones that include the connection point within the applicable fault clearance time determined under clause S5.1.9(a)(1);
(2)	each primary protection system must have sufficient redundancy to ensure that a faulted element within its protection zone is disconnected from the power system within the applicable fault clearance time with any single protection element (including any communications facility upon which that protection system depends) out of service; and
(3)	breaker fail protection systems must be provided to clear faults that are not cleared by the circuit breakers controlled by the primary protection system within the applicable fault clearance time determined under clause S5.1.9(a)(1).
(b)	In relation to an automatic access standard under this clause S5.2.5.9, the Generator must provide redundancy in the primary protection systems under paragraph (a)(2) and provide breaker fail protection systems under paragraph (a)(3) if AEMO or the Network Service Provider consider that a lack of these facilities could result in:
(1)	a material adverse impact on power system security or quality of supply to other Network Users; or
(2)	a reduction in inter-regional or intra-regional power transfer capability,
through any mechanism including:
(3)	consequential tripping of, or damage to, other network equipment or facilities of other Network Users, that would have a power system security impact; or
(4)	instability that would not be detected by other protection systems in the network.
Minimum access standard
(c)	The minimum access standard is:
(1)	subject to clauses S5.1.9(k) and S5.1.9(l), protection systems must be provided to disconnect from the power system any faulted element within a generating system and in protection zones that include the connection point within the applicable fault clearance time determined under clause S5.1.9(a)(2); and
(2)	if a fault clearance time determined under clause S5.1.9(a)(2) for a protection zone is less than 10 seconds, a breaker fail protection system must be provided to clear from the power system any fault within that protection zone that is not cleared by the circuit breakers controlled by the primary protection system within the applicable fault clearance time determined under clause S5.1.9(a)(3).
[Deleted]
(d)	[Deleted]
General requirements
(e)	The Network Service Provider and the Generator must cooperate in the design and implementation of protection systems to comply with this clause S5.2.5.9, including cooperation on:
(1)	the use of current transformer and voltage transformer secondary circuits (or equivalent) of one party by the protection system of the other;
(2)	tripping of one party's circuit breakers by a protection system of the other party; and
(3)	co-ordination of protection system settings to ensure inter-operation.
(f)	The protection system design referred to in paragraphs (a) and (c) must:
(1)	be coordinated with other protection systems;
(2)	avoid consequential disconnection of other Network Users' facilities; and
(3)	take into account existing obligations of the Network Service Provider under connection agreements with other Network Users.
S5.2.5.10	Protection to trip plant for unstable operation
Automatic access standard
(a)	The automatic access standard is a generating system must have:
(1)	for its synchronous generating units, a protection system to disconnect it promptly when a condition that would lead to pole slipping is detected, to prevent pole slipping or other conditions where a generating unit causes active power, reactive power or voltage at the connection point to become unstable as assessed in accordance with the power system stability guidelines established under clause 4.3.4(h); and
(2)	for its asynchronous generating units, a protection system to disconnect it promptly for conditions where the active power, reactive power or voltage at the connection point becomes unstable as assessed in accordance with the guidelines for power system stability established under clause 4.3.4(h).
Minimum access standard
(b)	The minimum access standard is a generating system must not cause a voltage disturbance at the connection point due to sustained unstable behaviour of more than the maximum level specified in Table 7 of Australian Standard AS/NZS 61000.3.7:2001.
Negotiated access standard
(c)	If the Network Service Provider and the Generator agree, a protection system may also trip any other part of the generating system to cease the instability.
(d)	Notwithstanding paragraph (c), a protection system must be provided in the access standard to trip the affected generating unit where:
(1)	the Network Service Provider considers it necessary to prevent consequential tripping of, or damage to, other generating units, network equipment or other Network Users' facilities, or
(2)	AEMO considers it necessary to prevent unstable operation having an adverse impact on power system security.
S5.2.5.11	Frequency control
(a)	For the purpose of this clause S5.2.5.11:
droop means, in relation to frequency response mode, the percentage change in power system frequency as measured at the connection point, divided by the percentage change in power transfer of the generating system expressed as a percentage of the maximum operating level of the generating system. Droop must be measured at frequencies that are outside the deadband and within the limits of power transfer.
maximum operating level means in relation to:
(1)	a non-scheduled generating unit, the maximum sent out generation consistent with its nameplate rating;
(2)	a scheduled generating unit or semi-scheduled generating unit, the maximum generation to which it may be dispatched and as provided to AEMO in the most recent bid and offer validation data;
(3)	a non-scheduled generating system, the combined maximum sent out generation consistent with the nameplate ratings of its in-service generating units; and
(4)	a scheduled generating system or semi-scheduled generating system, the combined maximum generation to which its in-service generating units may be dispatched and as provided to AEMO in the most recent bid and offer validation data.
minimum operating level means in relation to:
(1)	a non-scheduled generating unit, its minimum sent out generation for continuous stable operation;
(2)	a scheduled generating unit or semi-scheduled generating unit, its minimum sent out generation for continuous stable operation;
(3)	a non-scheduled generating system, the combined minimum operating level of its in-service generating units; and
(4)	a scheduled generating system or semi-scheduled generating system, the combined minimum sent out generation of its in-service generating units.
Automatic access standard
(b)	The automatic access standard is:
(1)	a generating system's power transfer to the power system must not:
(i)	increase in response to a rise in the frequency of the power system as measured at the connection point; or
(ii)	decrease in response to a fall in the frequency of the power system as measured at the connection point; and
(2)	a generating system must be capable of operating in frequency response mode such that it automatically provides a proportional:
(i)	decrease in power transfer to the power system in response to a rise in the frequency of the power system as measured at the connection point; and
(ii)	increase in power transfer to the power system in response to a fall in the frequency of the power system as measured at the connection point,
sufficiently rapidly and sustained for a sufficient period for the Generator to be in a position to offer measurable amounts of all market ancillary services for the provision of power system frequency control.
Note
Clause 4.4.2(b) of the Rules sets out the obligations on Generators in relation to compliance with the technical requirements in clause S5.2.5.11, including being capable of operating in frequency response mode. Clause 4.4.2(c1) of the Rules sets out the obligations on Scheduled and Semi-Scheduled Generators in relation to the operation of their generating systems in accordance with the Primary Frequency Response Requirements.
Minimum access standard
(c)	The minimum access standard is:
(1)	for a generating system under relatively stable input energy, power transfer to the power system must not:
(i)	increase in response to a rise in the frequency of the power system as measured at the connection point; and
(ii)	decrease more than 2% per Hz in response to a fall in the frequency of the power system as measured at the connection point; and
(2)	a generating system must be capable of operating in frequency response mode such that, subject to energy source availability, it automatically provides:
(i)	a decrease in power transfer to the power system in response to a rise in the frequency of the power system as measured at the connection point; or
(ii)	an increase in power transfer to the power system in response to a fall in the frequency of the power system as measured at the connection point,
where the change in active power is either proportional or otherwise as agreed with AEMO and the Network Service Provider.
Note
Clause 4.4.2(b) of the Rules sets out the obligations on Generators in relation to compliance with the technical requirements in clause S5.2.5.11, including being capable of operating in frequency response mode. Clause 4.4.2(c1) of the Rules sets out the obligations on Scheduled and Semi-Scheduled Generators in relation to the operation of their generating systems in accordance with the Primary Frequency Response Requirements.
[Deleted]
(d)	[Deleted]
(e)	[Deleted]
(f)	[Deleted]
General requirements
(g)	Each control system used to satisfy this clause S5.2.5.11 must be adequately damped.
(h)	The amount of a relevant market ancillary service for which the plant may be registered must not exceed the amount that would be consistent with the performance standard registered in respect of this requirement.
(i)	For the purposes of subparagraph (b)(2), and with respect to a negotiated access standard proposed for the technical requirements relevant to this clause S5.2.5.11:
(1)	the change in power transfer to the power system must occur with no delay beyond that required for stable operation, or inherent in the plant controls, once the frequency of the power system as measured at the connection point leaves a deadband around 50 Hz;
(2)	a generating system must be capable of setting the deadband and droop within the following ranges:
(i)	the deadband referred to in subparagraph (1) must be set within the range of 0 to ± 1.0 Hz. Different deadband settings may be applied for a rise or fall in the frequency of the power system as measured at the connection point; and
(ii)	the droop must be set within the range of 2% to 10%, or such other settings as agreed with the Network Service Provider and AEMO;
(3)	nothing in subparagraph (b)(2) is taken to require a generating system to operate below its minimum operating level in response to a rise in the frequency of the power system as measured at the connection point, or above its maximum operating level in response to a fall in the frequency of the power system as measured at the connection point;
(4)	[Deleted]
(5)	the performance standards must record:
(i)	agreed values for maximum operating level and minimum operating level, and where relevant the method of determining the values, and the values for a generating system must take into account its in-service generating units; and
(ii)	for the purpose of subparagraph (b)(2), or a negotiated access standard offering measureable amounts of market ancillary services under this clause S5.2.5.11, the market ancillary services, including the performance parameters and requirements that apply to each such market ancillary service.
S5.2.5.12	Impact on network capability
Automatic access standard
(a)	The automatic access standard is a generating system must have plant capabilities and control systems that are sufficient so that when connected it does not reduce any inter-regional or intra-regional power transfer capability below the level that would apply if the generating system were not connected.
Minimum access standard
(b)	The minimum access standard is a generating system must have plant capabilities, control systems and operational arrangements sufficient to ensure there is no reduction in:
(1)	the ability to supply Customer load as a result of a reduction in power transfer capability; and
(2)	power transfer capabilities into a region by more than the combined sent out generation of its generating units.
Negotiated access standard
(c)	In carrying out assessments of proposed negotiated access standards under this clause S5.2.5.12, the Network Service Provider and AEMO must take into account:
(1)	the expected performance of:
(i)	existing networks and considered projects;
(ii)	existing generating plant and other relevant projects; and
(iii)	control systems and protection systems, including automatic reclose equipment; and
(2)	the expected range of power system operating conditions.
(d)	The negotiated access standard must include:
(1)	control systems to minimise any reduction in power transfer capabilities; and
(2)	operational arrangements, including curtailment of the generating system's output if necessary to ensure that the generating plant is operated in a way that meets at least the minimum access standard under abnormal network and generating system conditions, so that power system security can be maintained.
(e)	A negotiated access standard under this clause S5.2.5.12 must detail the plant capabilities, control systems and operational arrangements that will be maintained by the Generator, notwithstanding that change to the power system, but not changes to the generating system, may reduce the efficacy of the plant capabilities, control systems and operational arrangements over time.
(f)	[Deleted]
General requirement
(g)	If a Network Service Provider considers that power transfer capabilities of its network would be increased through provision of additional control system facilities to a generating system (such as a power system stabiliser), the Network Service Provider and the Generator may negotiate for the provision of such additional control system facilities as a commercial arrangement.
S5.2.5.13	Voltage and reactive power control
(a)	For the purpose of this clause S5.2.5.13:
static excitation system means in relation to a synchronous generating unit, an excitation control system that does not use rotating machinery to produce the field current.
Automatic access standard
(b)	The automatic access standard is:
(1)	a generating system must have plant capabilities and control systems sufficient to ensure that:
(i)	power system oscillations, for the frequencies of oscillation of the generating unit against any other generating unit, are adequately damped;
(ii)	operation of the generating system does not degrade the damping of any critical mode of oscillation of the power system; and
(iii)	operation of the generating system does not cause instability (including hunting of tap-changing transformer control systems) that would adversely impact other Registered Participants;
(2)	a control system must have:
(i)	for the purposes of disturbance monitoring and testing, permanently installed and operational, monitoring and recording facilities for key variables including each input and output; and
(ii)	facilities for testing the control system sufficient to establish its dynamic operational characteristics;
(2A)	a generating system must have facilities with a control system to regulate voltage, reactive power and power factor, with the ability to:
(i)	operate in any control mode; and
(ii)	switch between control modes,
as shown in the manufacturer's and/or design specifications of the relevant equipment and demonstrated to the reasonable satisfaction of the Network Service Provider and AEMO;
(2B)	a generating system must have a voltage control system that:
(i)	regulates voltage at the connection point or another agreed location in the power system (including within the generating system) to within 0.5% of the setpoint, where that setpoint may be adjusted to incorporate any voltage droop or reactive current compensation agreed with AEMO and the Network Service Provider;
(ii)	regulates voltage in a manner that helps to support network voltages during faults and does not prevent the Network Service Provider from achieving the requirements of clauses S5.1a.3 and S5.1a.4;
(iii)	allows the voltage setpoint to be continuously controllable in the range of at least 95% to 105% of the target voltage (as determined by the Network Service Provider in accordance with clause S5.1.4(c) and recorded in the connection agreement in accordance with clause S5.1.4) at the connection point or agreed location on the power system, without reliance on a tap-changing transformer and subject to the reactive power capability agreed with AEMO and the Network Service Provider under clause S5.2.5.1; and
(iv)	has limiting devices to ensure that a voltage disturbance does not cause a generating unit to trip at the limits of its operating capability;
(3)	a synchronous generating system must have an excitation control system that:
(i)	[Deleted]
(ii)	can operate the stator continuously at 105% of nominal voltage with rated active power output;
(iii)	[Deleted]
(iv)	[Deleted]
(v)	[Deleted]
(vi)	has an excitation ceiling voltage of at least:
(A)	for a static excitation system, 2.3 times; or
(B)	for other excitation control systems, 1.5 times,
the excitation required to achieve generation at the nameplate rating for rated power factor, rated speed and nominal voltage;
(vii)	has settling times for a step change of voltage setpoint or voltage at the location agreed under subparagraph (2B)(i) of:
(A)	generated voltage less than 2.5 seconds for a 5% voltage disturbance with the generating unit not synchronised;
(B)	active power, reactive power and voltage less than 5.0 seconds for a 5% voltage disturbance with the generating unit synchronised, from an operating point where the voltage disturbance would not cause any limiting device to operate; and
(C)	in respect of each limiting device, active power, reactive power and voltage less than 7.5 seconds for a 5% voltage disturbance with the generating unit synchronised, when operating into a limiting device from an operating point where a voltage disturbance of 2.5% would just cause the limiting device to operate;
(viii)	can increase field voltage from rated field voltage to the excitation ceiling voltage in less than:
(A)	0.05 second for a static excitation system; or
(B)	0.5 second for other excitation control systems; and
(ix)	has a power system stabiliser with sufficient flexibility to enable damping performance to be maximised, with characteristics as described in paragraph (c);
(4)	a generating system, other than one comprised of synchronous generating units, must have a voltage control system that:
(i)	[Deleted]
(ii)	[Deleted]
(iii)	[Deleted]
(iv)	[Deleted]
(v)	with the generating system connected to the power system, has settling times for active power, reactive power and voltage due to a step change of voltage setpoint or voltage at the location agreed under clause subparagraph (2B)(i), of less than:
(A)	5.0 seconds for a 5% voltage disturbance with the generating system connected to the power system, from an operating point where the voltage disturbance would not cause any limiting device to operate; and
(B)	7.5 seconds for a 5% voltage disturbance with the generating system connected to the power system, when operating into any limiting device from an operating point where a voltage disturbance of 2.5% would just cause the limiting device to operate;
(vi)	has reactive power rise time, for a 5% step change in the voltage setpoint, of less than 2 seconds; and
(vii)	has a power oscillation damping capability with sufficient flexibility to enable damping performance to be maximised:
(A)	with characteristics as described in paragraph (c); or
(B)	where AEMO has published characteristics for a generating system other than one comprised of synchronous generating units, following consultation in accordance with the Rules consultation procedures, with characteristics as published by AEMO.
(c)	A power system stabiliser provided under paragraph (b) must have:
(1)	for a synchronous generating unit, measurements of rotor speed and active power output of the generating unit as inputs, and otherwise, measurements of power system frequency and active power output of the generating unit as inputs;
(2)	two washout filters for each input, with ability to bypass one of them if necessary;
(3)	sufficient (and not less than two) lead-lag transfer function blocks (or equivalent number of complex poles and zeros) with adjustable gain and time-constants, to compensate fully for the phase lags due to the generating plant;
(4)	an output limiter, which for a synchronous generating unit is continually adjustable over the range of –10% to +10% of stator voltage;
(5)	monitoring and recording facilities for key variables including inputs, output and the inputs to the lead-lag transfer function blocks; and
(6)	facilities to permit testing of the power system stabiliser in isolation from the power system by injection of test signals, sufficient to establish the transfer function of the power system stabiliser.
(c1)	A reactive power or power factor control system provided under paragraph (b)(2A) must:
(1)	regulate reactive power or power factor (as applicable) at the connection point or another agreed location in the power system (including within the generating system), to within:
(i)	for a generating system operating in reactive power mode, 2% of the rating (in MVA) of the generating system (expressed in MVAr); or
(ii)	for a generating system operating in power factor mode, a power factor equivalent to 2% of the rating (in MVA) of the generating system (expressed in MVAr);
(2)	allow the reactive power or power factor setpoint to be continuously controllable across the reactive power capability range established under clause S5.2.5.1; and
(3)	with the generating system connected to the power system, and for a step change in setpoint of at least 50% of the reactive power capability agreed with AEMO and the Network Service Provider under clause S5.2.5.1, or a 5% voltage disturbance at the location agreed under subparagraph (1):
(i)	have settling times for active power, reactive power and voltage of less than 5.0 seconds from an operating point where the voltage disturbance would not cause any limiting device to operate; and
(ii)	have settling times for active power, reactive power and voltage of less than 7.5 seconds when operating into any limiting device from an operating point where a voltage disturbance of 2.5% would just cause the limiting device to operate.
The Network Service Provider may determine whether to use a setpoint step test or a 5% voltage disturbance test for the purposes of this subparagraph (c1)(3).
Minimum access standard
(d)	The minimum access standard is:
(1)	a generating system must have plant capabilities and control systems, including, if appropriate, a power system stabiliser, sufficient to ensure that:
(i)	power system oscillations, for the frequencies of oscillation of the generating unit against any other generating unit, are adequately damped;
(ii)	operation of the generating unit does not degrade:
(A)	any mode of oscillation that is within 0.3 nepers per second of being unstable, by more than 0.01 nepers per second; and
(B)	any other mode of oscillation to within 0.29 nepers per second of being unstable; and
(iii)	operation of the generating unit does not cause instability (including hunting of tap-changing transformer control systems) that would adversely impact other Registered Participants;
(2)	a generating system comprised of generating units with a combined nameplate rating of 30 MW or more must have facilities for testing its control systems sufficient to establish their dynamic operational characteristics;
(2A)	a generating system must have facilities with a control system to regulate:
(i)	voltage; or
(ii)	either of reactive power or power factor with the agreement of AEMO and the Network Service Provider;
(2B)	a voltage control system for a generating system must:
(i)	regulate voltage at the connection point or another agreed location in the power system (including within the generating system), to within 2% of the setpoint, where that setpoint may be adjusted to incorporate any voltage droop or reactive current compensation agreed with AEMO and the Network Service Provider; and
(ii)	allow the voltage setpoint to be controllable in the range of at least 98% to 102% of the target voltage (as determined by the Network Service Provider in accordance with clause S5.1.4(c) and recorded in the connection agreement in accordance with clause S5.1.4) at the connection point or the agreed location, subject to the reactive power capability agreed with AEMO and the Network Service Provider under clause S5.2.5.1;
(3)	a generating system's reactive power or power factor control system must:
(i)	regulate reactive power or power factor (as applicable) at the connection point or another agreed location in the power system (including within the generating system), to within:
(A)	for a generating system operating in reactive power mode, 5% of the rating (in MVA) of the generating system (expressed in MVAr); or
(B)	for a generating system operating in power factor mode, a power factor equivalent to 5% of the rating (in MVA) of the generating system (expressed in MVAr); and
(ii)	allow the reactive power or power factor setpoint to be continuously controllable across the reactive power capability range established under clause S5.2.5.1;
(4)	a synchronous generating system with a nameplate rating of 30 MW or more, with an excitation control system required to regulate voltage under subparagraph (d)(2A)(i) must:
(i)	[Deleted]
(ii)	have excitation ceiling voltage of at least 1.5 times the excitation required to achieve generation at the nameplate rating for rated power factor, rated speed and nominal voltage;
(iii)	subject to co-ordination under paragraph (i), have a settling time of less than 7.5 seconds for a 5% voltage disturbance with the generating unit synchronised, from an operating point where such a voltage disturbance would not cause any limiting device to operate; and
(iv)	have over and under excitation limiting devices sufficient to ensure that a voltage disturbance does not cause the generating unit to trip at the limits of its operating capability; and
(5)	a generating system comprised of asynchronous generating units with a nameplate rating of 30 MW or more, with a voltage control system required to regulate voltage under subparagraph (d)(2A)(i) must:
(i)	[Deleted]
(ii)	subject to co-ordination under paragraph (i), have a settling time less than 7.5 seconds for a 5% voltage disturbance with the generating unit electrically connected to the power system from an operating point where such a voltage disturbance would not cause any limiting device to operate; and
(iii)	have limiting devices to ensure that a voltage disturbance would not cause the generating unit to trip at the limits of its operating capability.
Negotiated access standard
(e)	[Deleted]
(f)	The negotiated access standard proposed by the Generator under clause 5.3.4A(b1) must be the highest level that the generating system can reasonably achieve, including by installation of additional dynamic reactive power equipment, and through optimising its control systems.
(g)	[Deleted]
General requirements
(g1)	For the purposes of subparagraph (b)(2A), the Network Service Provider and AEMO will nominate one or more control modes to be implemented when the generating system is commissioned, and may require additional control modes to be commissioned after connection if the Network Service Provider or AEMO reasonably considers such additional modes to be necessary to ensure power system security or quality of supply. Where a generating system has been commissioned for more than one control mode, the Generator, Network Service Provider and AEMO must agree on a procedure for switching between control modes. The initial operating mode, other available modes and the procedure for switching between modes must be recorded as part of the performance standard.
(h)	A limiting device provided under paragraphs (b) and (d) must:
(1)	not detract from the performance of any power system stabiliser or power oscillation damping capability; and
(2)	be co-ordinated with all protection systems.
(i)	The Network Service Provider may require that the design and operation of the control systems of a generating unit or generating system be coordinated with the existing voltage control systems of the Network Service Provider and of other Network Users, in order to avoid or manage interactions that would adversely impact on the Network Service Provider and other Network Users.
(j)	Any requirements imposed by the Network Service Provider under paragraph (i) must be recorded in the performance standard.
(k)	The assessment of impact of the generating units on power system stability and damping of power system oscillations shall be in accordance with the guidelines for power system stability established under clause 4.3.4(h).
S5.2.5.14	Active power control
(a)	The automatic access standard is a generating system must have an active power control system capable of:
(1)	for a scheduled generating unit or a scheduled generating system:
(i)	maintaining and changing its active power output in accordance with its dispatch instructions;
(ii)	ramping its active power output linearly from one level of dispatch to another; and
(iii)	receiving and automatically responding to signals delivered from the automatic generation control system, as updated at a rate of once every 4 seconds (or such other period specified by AEMO as required);
(2)	subject to energy source availability, for a non-scheduled generating unit or non-scheduled generating system:
(i)	automatically reducing or increasing its active power output within 5 minutes, at a constant rate, to or below the level specified in an instruction electronically issued by a control centre, subject to subparagraph (iii);
(ii)	automatically limiting its active power output, to below the level specified in subparagraph (i); and
(iii)	not changing its active power output within 5 minutes by more than the raise and lower amounts specified in an instruction electronically issued by a control centre; and
(3)	subject to energy source availability, for a semi-scheduled generating unit or a semi-scheduled generating system:
(i)	automatically reducing or increasing its active power output within 5 minutes at a constant rate, to or below the level specified in an instruction electronically issued by a control centre;
(ii)	automatically limiting its active power output, to or below the level specified in subparagraph (i);
(iii)	not changing its active power output within 5 minutes by more than the raise and lower amounts specified in an instruction electronically issued by a control centre;
(iv)	ramping its active power output linearly from one level of dispatch to another; and
(v)	receiving and automatically responding to signals delivered from the automatic generation control system, as updated at a rate of once every 4 seconds (or such other period specified by AEMO as required).
Minimum access standard
(b)	The minimum access standard is a generating system must have an active power control system capable of:
(1)	for a scheduled generating unit or a scheduled generating system:
(i)	maintaining and changing its active power output in accordance with its dispatch instructions; and
(ii)	receiving and automatically responding to signals delivered from the automatic generation control system, as updated at a rate of once every four seconds (or such other period specified by AEMO as required);
(2)	for a non-scheduled generating system:
(i)	reducing its active power output, within 5 minutes, to or below the level required to manage network flows that is specified in a verbal instruction issued by the control centre;
(ii)	limiting its active power output, to or below the level specified in subparagraph (i); and
(iii)	subject to energy source availability, ensuring that the change of active power output in a 5 minute period does not exceed a value agreed with AEMO and the Network Service Provider; and
(3)	subject to energy source availability, for a semi-scheduled generating unit or a semi-scheduled generating system:
(i)	maintaining and changing its active power output in accordance with its dispatch instructions;
(ii)	not changing its active power output within five minutes by more than the rise and lower amounts specified in an instruction electronically issued by a control centre; and
(iii)	receiving and automatically responding to signals delivered from the automatic generation control system, as updated at a rate of once every 4 seconds (or such other period specified by AEMO as required).
Negotiated access standard
(c)	A negotiated access standard may provide that if the number or frequency of verbal instructions becomes difficult for a control centre to manage, AEMO may require the Generator to upgrade its facilities to receive electronic instructions and fully implement them within 5 minutes.
(d)	The negotiated access standard must document to AEMO's satisfaction any operational arrangements necessary to manage network flows that may include a requirement for the generating system to be operated in a manner that prevents its output changing within 5 minutes by more than an amount specified by a control centre.
(e)	[Deleted]
General requirements
(f)	Each control system used to satisfy the requirements of paragraphs (a) and (b) must be adequately damped.
S5.2.6	Monitoring and control requirements
S5.2.6.1	Remote Monitoring
Automatic access standard
(a)	The automatic access standard is a:
(1)	scheduled generating unit;
(2)	scheduled generating system;
(3)	non-scheduled generating unit;
(4)	non-scheduled generating system;
(5)	semi-scheduled generating unit; or
(6)	semi-scheduled generating system,
must have remote monitoring equipment and remote control equipment to transmit to, and receive from, AEMO's control centres in real time in accordance with rule 4.11 the quantities that AEMO reasonably requires to discharge its market and power system security functions set out in Chapters 3 and 4.
(b)	The remote monitoring quantities referred to under paragraph (a) that AEMO may request include:
(1)	in respect of a generating system of a type referred to in subparagraphs (a)(1) to (6):
(i)	the status of all switching devices that carry the generation;
(ii)	tap-changing transformer tap position(s) and voltages;
(iii)	active power and reactive power aggregated for groups of identical generating units;
(iv)	either the number of identical generating units operating or the operating status of each non-identical generating unit;
(v)	active power and reactive power for the generating system; and
(vi)	voltage control system setpoint and mode (as applicable);
(2)	in respect of a generating unit with a nameplate rating of 30 MW or more, current, voltage, active power and reactive power in respect of generating unit stators or power conversion systems (as applicable);
(3)	in respect of an auxiliary supply system with a capacity of 30 MW or more associated with a generating unit or generating system, active power and reactive power;
(4)	in respect of reactive power equipment that is part of a generating system but not part of a particular generating unit, its reactive power;
(5)	in respect of a semi-scheduled generating system, all data specified as mandatory in the relevant energy conversion model applicable to that type of semi-scheduled generating system;
(6)	in respect of a scheduled generating system or semi-scheduled generating system:
(i)	maximum active power limit;
(ii)	minimum active power limit;
(iii)	maximum active power raise ramp rate; and
(iv)	maximum active power lower ramp rate;
(7)	in respect of a run-back scheme agreed with the Network Service Provider:
(i)	run-back scheme status; and
(ii)	active power, reactive power or other control limit, as applicable;
(8)	the mode of operation of the generating unit, turbine control limits, or other information required to reasonably predict the active power response of the generating system to a change in power system frequency at the connection point; and
(9)	any other quantity that AEMO reasonably requires to discharge its market and power system security functions as set out in Chapters 3 and 4.
(b1)	The remote control quantities referred to under paragraph (a) that AEMO may request include:
(1)	in respect of a generating system:
(i)	voltage control setpoint; and
(ii)	voltage control mode (where applicable);
(2)	in respect of a scheduled generating system or semi-scheduled generating system, the automatic generation control system signal; and
(3)	in respect of a non-scheduled generating system, to the extent required to manage network flows:
(i)	active power limit; and
(ii)	active power ramp limit.
Minimum access standard
(c)	The minimum access standard is a:
(1)	scheduled generating unit;
(2)	scheduled generating system;
(3)	non-scheduled generating system;
(4)	semi-scheduled generating unit; or
(5)	semi-scheduled generating system,
must have remote monitoring equipment to transmit to AEMO's control centres in real time in accordance with rule 4.11 the quantities that AEMO reasonably requires to discharge its market and power system security functions set out in Chapters 3 and 4.
(d)	The quantities referred to under paragraph (c) that AEMO may request include:
(1)	the active power output of the generating unit or generating system (as applicable);
(2)	if connected to a transmission system, the reactive power output of the generating unit or generating system (as applicable); and
(3)	if a semi-scheduled generating system, all data specified as mandatory in the relevant energy conversion model applicable to that type of semi-scheduled generating system.
S5.2.6.2	Communications equipment
Automatic access standard
(a)	The automatic access standard is a Generator must:
(1)	provide and maintain two separate telephone facilities using independent telecommunications service providers, for the purposes of operational communications between the Generator's responsible operator under clause 4.11.3(a) and AEMO's control centre; and
(2)	provide electricity supplies for remote monitoring equipment and remote control equipment installed in relation to its generating system capable of keeping such equipment available for at least 3 hours following total loss of supply at the connection point for the relevant generating unit.
Minimum access standard
(b)	The minimum access standard is a Generator must:
(1)	provide and maintain a telephone facility for the purposes of operational communications between the Generator's responsible operator under clause 4.11.3(a) and AEMO's control centre; and
(2)	provide electricity supplies for remote monitoring equipment and remote control equipment installed in relation to its generating system capable of keeping such equipment available for at least 1 hour following total loss of supply at the connection point for the relevant generating unit.
Negotiated access standard
(c)	A negotiated access standard must include, where the Network Service Provider or AEMO reasonably require, a back-up telephone facility be independent of commercial telephone service providers, and the Network Service Provider must provide and maintain the separate facility on a cost-recovery basis only through the charge for connection.
(d)	A negotiated access standard must include that a Generator must provide communications paths (with appropriate redundancy) from the remote monitoring equipment or remote control equipment installed for each of its generating systems as appropriate, to an interface for communication purposes in a location reasonably acceptable to the Network Service Provider at the relevant generation facility.
(e)	Communications systems between the interface for communication purposes under paragraph (d) and the control centre must be the responsibility of the Network Service Provider unless otherwise agreed by the Generator and the Network Service Provider.
(f)	A negotiated access standard must include that the Generator provide accommodation and secure power supplies for communications facilities provided by the Network Service Provider under this clause S5.2.6.2.
S5.2.7	Power station auxiliary supplies
In cases where a generating system takes its auxiliary supplies via a connection point through which its generation is not transferred to the network, the access standards must be established under clause S5.3.5 as if the Generator were a Market Customer.
S5.2.8	Fault current
Automatic access standard
(a)	The  automatic access standard is:
(1)	the contribution of the generating system to the fault current on the connecting network through its connection point must not exceed the contribution level that will ensure that the total fault current can be safely interrupted by the circuit breakers of the connecting network and safely carried by the connecting network for the duration of the applicable breaker fail protection system fault clearance times, as specified for the relevant connection point by the Network Service Provider;
(2)	a generating system's connected plant must be capable of withstanding fault current through the connection point up to the higher of:
(i)	the level specified in clause S5.2.4(e1)(1) ; and
(ii)	the highest level of current at the connection point that can be safely interrupted by the circuit breakers of the connecting network and safely carried by the connecting network for the duration of the applicable breaker fail protection system fault clearance times, as specified by the Network Service Provider; and
(3)	a circuit breaker provided to isolate a generating unit or generating system from the network must be capable of breaking, without damage or restrike, the maximum fault currents that could reasonably be expected to flow through the circuit breaker for any fault in the network or in the generating unit or generating system, as specified in the connection agreement.
Minimum access standard
(b)	The minimum access standard is:
(1)	the generating system does not need to limit fault current contribution;
(2)	a generating system's connected plant must be capable of withstanding fault current through the connection point up to the level specified in clause S5.2.4(e1)(1) ; and
(3)	a circuit breaker provided to isolate a generating unit or generating system from the network must be capable of breaking, without damage or restrike, the maximum fault currents that could reasonably be expected to flow through the circuit breaker for any fault in the network or in the generating unit or generating system, as specified in the connection agreement.
Negotiated access standard
(c)	In negotiating a negotiated access standard, the Network Service Provider must consider alternative network configurations in the determination of the applicable fault current level and must prefer those options that maintain an equivalent level of service to other Network Users and which, in the opinion of the Generator, impose the least obligation on the Generator.
(d)	In carrying out assessments of proposed negotiated access standards under this clause S5.2.8, the Network Service Provider must take into account, without limitation:
(1)	the expected performance of existing networks and considered projects;
(2)	the expected performance of existing generating plant and other relevant projects; and
(3)	the expected range of power system operating conditions.
Schedule 5.3	Conditions for Connection of Customers
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.
S5.3.1a	Introduction to the schedule
(a)	This schedule applies to the following classes of Network User:
(1)	a First-Tier Customer in respect of its first-tier load;
(2)	a Second-Tier Customer in respect of its second-tier load;
(3)	a Market Customer in respect of its market load;
(4)	a Non-Registered Customer in respect of supply it takes from a network; and
(5)	a Distribution Network Service Provider in respect of its distribution network.
(b)	For the purposes of this schedule 5.3 the term Network Service Provider must be interpreted to mean the Network Service Provider with whom the Connection Applicant has sought, or is seeking, a connection in accordance with clause 5.3.2 of the Rules.
(c)	All Network Users must comply with the requirements for the establishment of performance standards in accordance with provisions contained in schedule 5.1a for system standards or schedule 5.1 for Network Service Providers and this schedule 5.3 for Customers.
(d)	If the Connection Applicant is a Registered Participant in relation to the proposed connection, the Network Service Provider may include as terms and conditions of the connection agreement any provision of this schedule that is expressed as an obligation on a Network User. If the Connection Applicant is not a Registered Participant in relation to the proposed connection, the Network Service Provider must include as terms and conditions of the connection agreement:
(1)	each provision of this schedule that is expressed as an obligation on a Network User; and
(2)	each agreed performance standard and an obligation to comply with it.
(e)	The purpose of this schedule is to:
(1)	describe the information that must be exchanged for the connection enquiry and application to connect processes described in rule 5.3 of the Rules;
(2)	establish the automatic access standards and minimum access standards that will apply to the process of negotiating access standards under clause 5.3.4A of the Rules; and
(3)	establish obligations to apply prudent design standards for the plant to be connected.
S5.3.1	Information
(a)	Before a Network User connects any new or additional equipment to a network, the Network User must submit the following kinds of information to the Network Service Provider:
(1)	a single line diagram with the protection details;
(2)	metering system design details for any metering equipment being provided by the Network User;
(3)	a general arrangement locating all the equipment on the site;
(4)	a general arrangement for each new or altered substation showing all exits and the position of all electrical equipment;
(5)	type test certificates for all new switchgear and transformers, including measurement transformers to be used for metering purposes in accordance with Chapter 7 of the Rules;
(6)	earthing details;
(7)	the proposed methods of earthing cables and other equipment to comply with the regulations of the relevant participating jurisdiction;
(8)	plant and earth grid test certificates from approved test authorities;
(9)	a secondary injection and trip test certificate on all circuit breakers;
(10)	certification that all new equipment has been inspected before being connected to the supply; and
(11)	operational arrangements.
(a1)	Before a Network User connects any new or additional equipment to a network, the Network User must submit:
(1)	to AEMO and the relevant Network Service Provider(s), information about the protection systems of the equipment;
(2)	to AEMO and the relevant Network Service Provider(s), information about the control systems of the equipment including:
(i)	a set of functional block diagrams, including all functions between feedback signals and output;
(ii)	the parameters of each functional block, including all settings, gains, time constants, delays, deadbands and limits;
(iii)	the characteristics of non-linear elements;
(iv)	encrypted models in a form suitable for the software simulation products nominated by AEMO in the Power System Model Guidelines;
(3)	to AEMO and the relevant Network Service Provider(s), any other information specified in the Power System Model Guidelines, Power System Design Data Sheet and Power System Setting Data Sheet;
(4)	to AEMO, model source code (in the circumstances required by the Power System Model Guidelines) associated with the model in subparagraph (2)(iv) in an unencrypted form suitable for at least one of the software simulation products nominated by AEMO in the Power System Model Guidelines and in a form that would allow conversion for use with other software simulation products nominated by AEMO in the Power System Model Guidelines.
(a2)	The information provided under paragraph (a1) must contain sufficient detail for AEMO and the relevant Network Service Provider(s) to perform power system simulation studies in accordance with the requirements and circumstances specified in the Power System Model Guidelines.
(a3)	Notwithstanding paragraph (a1), AEMO may exempt a Network User or class of Network Users from the requirement to provide some or all of the information specified in paragraph (a1), and must do so in accordance with the circumstances set out in the Power System Model Guidelines.
(a4)	All information provided to AEMO and the relevant Network Service Provider(s) under paragraph (a1) or pursuant to paragraph (a3) must be treated as confidential information by those recipients.
(b)	For the purposes of clause 5.3.2(f) of the Rules, the technical information that a Network Service Provider must, if requested, provide to a Connection Applicant in respect of the proposed connection includes:
(1)	the highest expected single phase and three phase fault levels at the connection point without the proposed connection;
(2)	the clearing times of the existing protection systems that would clear a fault at the location at which the new connection would be connected into the existing transmission system or distribution system;
(3)	the expected limits of voltage fluctuation, harmonic voltage distortion and voltage unbalance at the connection point without the proposed connection;
(4)	technical information relevant to the connection point without the proposed connection including equivalent source impedance information, sufficient to estimate fault levels, voltage fluctuations, harmonic voltage distortion and voltage unbalance; and
(5)	any other information or data not being confidential information relating to the performance of the Network Service Provider's facilities that is reasonably necessary for the Connection Applicant to prepare an application to connect;
except where the Connection Applicant agrees the Network Service Provider may provide alternative or less detailed technical information in satisfaction of this clause S5.3.1.(b).
S5.3.2	Design standards
A Network User must ensure that:
(a)	the electrical plant in its facility complies with the relevant Australian Standards as applicable at the time of first installation of that electrical plant in the facility;
(b)	circuit breakers provided to isolate the Network User's facilities from the Network Service Provider's facilities are capable of breaking, without damage or restrike, fault currents nominated by the Network Service Provider in the relevant connection agreement; and
(c)	new equipment including circuit breakers provided to isolate the Network User's facilities from the Network Service Provider's facilities is capable of withstanding, without damage, power frequency voltages and impulse levels nominated by the Network Service Provider to apply at the connection point in accordance with the relevant provisions of the system standards and recorded in the relevant connection agreement.
S5.3.3	Protection systems and settings
A Network User must ensure that all connections to the network are protected by protection devices which effectively and safely disconnect any faulty circuit automatically within a time period specified by the Network Service Provider in accordance with the following provisions:
(a)	The automatic access standard is:
(1)	Primary protection systems must be provided to disconnect any faulted element from the power system within the applicable fault clearance time determined under clause S5.1.9(a)(1), but subject to clauses S5.1.9(k) and S5.1.9(l).
(2)	Each primary protection system must have sufficient redundancy to ensure that a faulted element within its protection zone is disconnected from the power system within the applicable fault clearance time with any single protection element (including any communications facility upon which that protection system depends) out of service.
(3)	Breaker fail protection systems must be provided to clear faults that are not cleared by the circuit breakers controlled by the primary protection system, within the applicable fault clearance time determined under clause S5.1.9(a)(1).
(b)	The minimum access standard is:
(1)	Primary protection systems must be provided to disconnect from the power system any faulted element within their respective protection zones within the applicable fault clearance time determined under clause S5.1.9(a)(2), but subject to clauses S5.1.9(k) and S5.1.9(l).
(2)	If a fault clearance time determined under clause S5.1.9(a)(2) for a protection zone is less than 10 seconds, a breaker fail protection system must be provided to clear from the power system any fault within that protection zone that is not cleared by the circuit breakers controlled by the primary protection system, within the applicable fault clearance time determined under clause S5.1.9(a)(3).
(c)	The Network Service Provider and the Network User must cooperate in the design and implementation of protection systems to comply with this clause, including cooperation with regard to:
(1)	the use of current transformer and voltage transformer secondary circuits (or equivalent) of one party by the protection system of the other;
(2)	tripping of one party's circuit breakers by a protection system of the other party; and
(3)	co-ordination of protection system settings to ensure inter-operation.
Before the Network User's installation is connected to the Network Service Provider's transmission or distribution system the Network User's protection system must be tested and the Network User must submit the appropriate test certificate to the Network Service Provider.
The application of settings of the protection scheme must be undertaken in accordance with clause S5.3.4.
S5.3.4	Settings of protection and control systems
A Network User must only apply settings to a control system or a protection system that are necessary to comply with performance requirements of this schedule 5.3 if the settings have been approved in writing by the Network Service Provider and, if the requirement is one that would involve AEMO under clause 5.3.4A(c) of the Rules, also by AEMO. A Network User must not allow its plant to take supply of electricity from the power system without such prior approval.
If a Network User seeks approval from the Network Service Provider to apply or change a setting, approval must not be withheld unless the Network Service Provider or, if the requirement is one that would involve AEMO under clause 5.3.4A(c) of the Rules, AEMO, reasonably determines that the changed setting would cause the plant to not comply with the relevant performance standard or cause an inter-regional or intra-regional power transfer capability to be reduced.
If the Network Service Provider or, if the requirement is one that would involve AEMO under clause 5.3.4A(c) of the Rules, AEMO, reasonably determines that a setting of a control system or protection system of the plant needs to change to comply with the relevant performance standard or to maintain or restore an inter-regional or intra-regional power transfer capability, the Network Service Provider or AEMO (as applicable) must consult with the Network User, and the Network Service Provider may request in writing that a setting be applied in accordance with the determination.
The Network Service Provider may also request a test to verify the performance of the relevant plant with the new setting.
A Network User who receives such a request must arrange for the notified setting to be applied as requested and for a test to be conducted as requested. After the test, the Network User must, on request, provide both AEMO and the Network Service Provider with a report of a requested test, including evidence of its success or failure. Such a report of a test is confidential information.
A Network User must not change a setting requested by the Network Service Provider without its prior written agreement. If the Network Service Provider requires a Network User to change a setting within 18 months of a previous request, the Network Service Provider must pay the Network User its reasonable costs of changing the setting and conducting the tests as requested.
S5.3.5	Power factor requirements
Automatic access standard: For loads equal to or greater than 30 percent of the maximum demand at the connection point the power factors for Network Users and for distribution networks connected to another transmission network or distribution network are shown in Table S5.3.1:
Table S5.3.1

Permissible Range	
Supply Voltage (nominal)	Power Factor Range	
> 400 kV	0.98 lagging to unity	
250 kV - 400 kV	0.96 lagging to unity	
50 kV - 250 kV	0.95 lagging to unity	
1 kV < 50 kV	0.90 lagging to 0.90 leading	

For load less than 30 percent of the maximum demand at the connection point a Network Service Provider may accept a power factor outside the range stipulated in Table S5.3.1 provided this does not cause the system standards to be violated.
Minimum access standard: A Network Service Provider may permit a lower lagging or leading power factor where the Network Service Provider is advised by AEMO that this will not detrimentally affect power system security or reduce intra-regional or inter-regional power transfer capability.
General:
If the power factor falls outside the relevant performance standard over any critical loading period nominated by the Network Service Provider, the Network User must, where required by the Network Service Provider in order to maintain satisfactory voltage levels at the connection point or to restore intra-regional or inter-regional power transfer capability, take action to ensure that the power factor falls within range as soon as reasonably practicable. This may be achieved by installing additional reactive plant or reaching a commercial agreement with the Network Service Provider to install, operate and maintain equivalent reactive plant as part of the connection assets or by alternative commercial arrangements with another party.
A Registered Participant who installs shunt capacitors to comply with power factor requirements must comply with the Network Service Provider's reasonable requirements to ensure that the design does not severely attenuate audio frequency signals used for load control or operations, or adversely impact on harmonic voltage levels at the connection point.
S5.3.6	Balancing of load currents
A Network Service Provider may require a connected Registered Participant's load to be balanced across all phases in order to maintain the negative sequence voltage at each connection point at less than or equal to the limits set out in Table S5.1a.1 of the system standards for the applicable nominal supply voltage level.
Automatic access standard: A Network User must ensure that:
(a)	for connections at 30 kV or higher voltage, the current in any phase is not greater than 102 percent or less than 98 percent of the average of the currents in the three phases; and
(b)	for connections at voltages less than 30 kV, that the current in any phase is not greater than 105 percent or less than 95 percent of the average of the currents in the three phases.
Minimum access standard: Where agreed with the relevant Network Service Provider and subject to any specific conditions imposed, a Network User may cause current unbalance greater than that specified in the automatic access standard provided the Network User does not cause the limits specified in clause S5.1a.7 to be exceeded at any point in the network.
General:
The limit to load current unbalance must be included in the connection agreement and is subject to verification of compliance by the Network Service Provider.
Where these requirements cannot be met the Registered Participant may enter into a commercial arrangement with the Network Service Provider for the installation of equipment to correct the phase unbalance. Such equipment must be considered as part of the connection assets for the Registered Participant.
The limit to load current unbalance must be included in the connection agreement and is subject to verification of compliance by the Network Service Provider.
S5.3.7	Voltage fluctuations
(a)	Automatic access standard: The voltage fluctuations caused by variations in loading level at the connection point, including those arising from energisation, de-energisation or other operation of plant, must not exceed the limits determined under clause S5.1.5(a).
(b)	Minimum access standard: The voltage fluctuations caused by variations in loading level at the connection point, including those arising from energisation, de-energisation or other operation of plant, must not exceed the limits determined under clause S5.1.5(b).
The voltage fluctuation emission limits and any specified conditions must be included in the connection agreement, and are subject to verification of compliance by the Network Service Provider.
S5.3.8	Harmonics and voltage notching
(a)	Automatic access standard: The harmonic voltage distortion caused by non-linearity, commutation of power electronic equipment, harmonic resonance and other effects within the plant, must not exceed the limits determined under clause S5.1.6(a).
(b)	Minimum access standard: The harmonic voltage distortion caused by non-linearity, commutation of power electronic equipment, harmonic resonance and other effects within the plant, must not exceed the limits determined under clause S5.1.6(b).
The harmonic voltage distortion emission limits and any special conditions must be included in the connection agreement, and is subject to verification of compliance by the Network Service Provider.
S5.3.9	Design requirements for Network Users' substations
A Network User must comply with the following requirements applicable to the design, station layout and choice of equipment for a substation:
(a)	safety provisions must comply with requirements applicable to the participating jurisdiction notified by the Network Service Provider;
(b)	where required by the Network Service Provider, appropriate interfaces and accommodation must be incorporated for communication facilities, remote monitoring and control and protection of plant which is to be installed in the substation;
(c)	a substation must be capable of continuous uninterrupted operation with the levels of voltage, harmonics, unbalance and voltage fluctuation specified in the system standards as modified in accordance with the relevant provisions of schedule 5.1;
(d)	earthing of primary plant in the substation must be in accordance with the Electricity Supply Association of Australia Safe Earthing Guide and must reduce step and touch potentials to safe levels;
(e)	synchronisation facilities or reclose blocking must be provided if a generating unit is connected through the substation;
(f)	secure electricity supplies of adequate capacity must be provided for plant performing communication, monitoring, control and protection functions;
(g)	plant must be tested to ensure that the substation complies with the approved design and specifications as included in a connection agreement;
(h)	the protection equipment required would normally include protection schemes for individual items of plant, back-up arrangements, auxiliary DC supplies and instrumentation transformers; and
(i)	insulation levels of plant in the substation must co-ordinate with the insulation levels of the network to which the substation is connected as nominated in the connection agreement.
S5.3.10	Load shedding facilities
Network Users who are Market Customers and who have expected peak demands in excess of 10MW must provide automatic interruptible load in accordance with clause 4.3.5 of the Rules.
Load shedding procedures may be applied by AEMO, or EFCS settings schedules may be determined, in accordance with the provisions of clause 4.3.2 of the Rules for the shedding of all loads including sensitive loads.
Schedule 5.3a	Conditions for connection of Market Network Services
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.
S5.3a.1a	Introduction to the schedule
This schedule sets out obligations of Market Network Service Providers who connect to either a transmission network or a distribution network. It represents the requirements to be met for access to a network. Particular provisions may be varied by the Network Service Provider under the provisions of the Rules for the application of minimum access standards and automatic access standards.
This schedule includes specific provisions for the determination of automatic access standards and negotiated access standards which, once determined, must be recorded together with the automatic access standards in a connection agreement and registered with AEMO as performance standards.
In this schedule, the term Network Service Provider applies only to the Network Service Provider with whom the Market Network Service Provider has lodged, or is considering lodging, an application to connect.
(a)	The schedule includes, in respect of each market network service, provisions regarding the capability to:
(1)	automatically control the transfer of real power at the connection point for any given set of system conditions within the limits permitted under the Rules;
(2)	respond to control requirements under expected normal and abnormal conditions;
(3)	comply with general requirements to meet quality of supply obligations in accordance with clauses S5.3a.9, S5.3a.10 and S5.3a.11 and to maintain security of supply to other Registered Participants; and
(4)	automatically disconnect itself when necessary to prevent any damage to the market network service facilities or threat to power system security.
(b)	This schedule also sets out the requirements and conditions, which (subject to clause 5.2.3 of the Rules) are obligations of Market Network Service Providers to:
(1)	co--operate with the relevant Network Service Provider on technical matters when making a new connection;
(2)	provide information to the Network Service Provider or AEMO; and
(3)	observe and apply the relevant provisions of the system standards contained in schedule 5.1a in relation to the planning, design and operation of its market network service facilities.
(c)	This schedule does not set out arrangements by which a Market Network Service Provider may enter into an agreement or contract with AEMO to:
(1)	provide additional services that are necessary to maintain power system security; or
(2)	provide additional service to facilitate management of the market.
S5.3a.1	Provision of Information
(a)	Before a Market Network Service Provider connects any new or additional equipment to a network, the Market Network Service Provider must submit the following kinds of information to the Network Service Provider:
(1)	a single line diagram with the protection details;
(2)	metering system design details for any metering equipment being provided by the Market Network Service Provider;
(3)	a general arrangement locating all relevant equipment on the site;
(4)	a general arrangement for each new or altered substation showing all exits and the position of all electrical equipment;
(5)	type test certificates for all new switchgear and transformers, including measurement transformers to be used for metering purposes in accordance with Chapter 7 of the Rules;
(6)	earthing details;
(7)	the proposed methods of earthing cables and other equipment to comply with the regulations of the relevant participating jurisdiction;
(8)	plant and earth grid test certificates from approved test authorities;
(9)	a secondary injection and trip test certificate on all circuit breakers;
(10)	certification that all new equipment has been inspected before being connected to the supply; and
(11)	operational arrangements.
(a1)	Before a Market Network Service Provider connects any new or additional equipment to a network, the Market Network Service Provider must submit:
(1)	to AEMO and the relevant Network Service Provider(s), information about the protection systems of the equipment;
(2)	to AEMO and the relevant Network Service Provider(s), information about the control systems of the equipment including:
(i)	a set of functional block diagrams, including all functions between feedback signals and output;
(ii)	the parameters of each functional block, including all settings, gains, time constraints, delays, deadbands and limits;
(iii)	the characteristics of non-linear elements;
(iv)	encrypted models in a form suitable for the software simulation products nominated by AEMO in the Power System Model Guidelines;
(3)	to AEMO and the relevant Network Service Provider(s), any other information specified in the Power System Model Guidelines, Power System Design Data Sheet and Power System Setting Data Sheet;
(4)	to AEMO, model source code (in the circumstances required by the Power System Model Guidelines) associated with the model in subparagraph (2)(iv) in an unencrypted form suitable for at least one of the software simulation products nominated by AEMO in the Power System Model Guidelines and in a form that would allow conversion for use with other software simulation products nominated by AEMO in the Power System Model Guidelines.
(a2)	The information provided under paragraph (a1) must contain sufficient detail for AEMO and the relevant Network Service Provider(s) to perform power system simulation studies in accordance with the requirements and circumstances specified in the Power System Model Guidelines.
(a3)	All information provided to AEMO and the relevant Network Service Provider(s) under paragraph (a1) must be treated as confidential information by those recipients.
(b)	For the purposes of clause 5.3.2(f) of the Rules, the technical information that a Network Service Provider must, if requested, provide to a Connection Applicant in respect of the proposed connection of a market network service facility includes:
(1)	the highest expected single phase and three phase fault levels at the connection point without the proposed connection;
(2)	the clearing times of the existing protection systems that would clear a fault at the location at which the new connection would be connected into the existing transmission system or distribution system;
(3)	the expected limits of voltage fluctuation, harmonic voltage distortion and voltage unbalance at the connection point without the proposed connection;
(4)	technical information relevant to the connection point without the proposed connection including equivalent source impedance information, sufficient to estimate fault levels, voltage fluctuations, harmonic voltage distortion and voltage unbalance; and
(5)	any other information or data not being confidential information relating to the performance of the Network Service Provider's facilities that is reasonably necessary for the Connection Applicant to prepare an application to connect;
except where the Connection Applicant agrees the Network Service Provider may provide alternative or less detailed technical information in satisfaction of this clause S5.3a.1(b).
S5.3a.2	Application of settings
A Market Network Service Provider must only apply settings to a control system or a protection system that are necessary to comply with performance requirements of this schedule 5.3a if the settings have been approved in writing by the Network Service Provider and, if the requirement is one that would involve AEMO under clause 5.3.4A(c) of the Rules, also by AEMO. A Market Network Service Provider must not allow its market network service facilities to take electricity from the power system without such prior approval.
If a Market Network Service Provider seeks approval from the Network Service Provider to apply or change a setting, approval must not be withheld unless the Network Service Provider or, if the requirement is one that would involve AEMO under clause 5.3.4A(c) of the Rules, AEMO, reasonably determines that the changed setting would cause the market network service facilities to not comply with the relevant performance standard or cause an inter-regional or intra-regional power transfer capability to be reduced.
If the Network Service Provider or, if the requirement is one that would involve AEMO under clause 5.3.4A(c) of the Rules, AEMO, reasonably determines that a setting of a market network service facility's control system or protection system needs to change to comply with the relevant performance standard or to maintain or restore an inter-regional or intra-regional power transfer capability, the Network Service Provider or AEMO (as applicable) must consult with the Market Network Service Provider, and may request in writing that a setting be applied in accordance with the determination.
The Network Service Provider may also request a test to verify the performance of the relevant plant with the new setting. The Network Service Provider must provide AEMO with a copy of its request to a Market Network Service Provider to apply a setting or to conduct a test.
A Market Network Service Provider who receives such a request must arrange for the notified setting to be applied as requested and for a test to be conducted as requested. After the test, the Market Network Service Provider must, on request, provide both AEMO and the Network Service Provider with a report of a requested test, including evidence of its success or failure. Such a report of a test is confidential information.
A Market Network Service Provider must not change a setting requested by the Network Service Provider without its prior written agreement. If the Network Service Provider requires a Market Network Service Provider to change a setting within 18 months of a previous request, the Network Service Provider must pay the Market Network Service Provider its reasonable costs of changing the setting and conducting the tests as requested.
S5.3a.3	Technical matters to be co-ordinated
A Market Network Service Provider and the relevant Network Service Provider must use all reasonable endeavours to agree upon the following matters in respect of each new or altered connection of a market network service facility to a network:
(a)	design at the connection point;
(b)	physical layout adjacent to the connection point;
(c)	primary protection and backup protection (clause S5.3a.6);
(d)	control characteristics (clause S5.3a.4);
(e)	communications and alarms (clause S5.3a.4);
(f)	insulation co-ordination and lightning protection;
(g)	fault levels and fault clearance times;
(h)	switching and isolation facilities;
(i)	interlocking arrangements; and
(j)	metering installations as described in Chapter 7 of the Rules.
S5.3a.4	Monitoring and control requirements
S5.3a.4.1	Remote Monitoring
(a)	Automatic access standard:
(1)	Each market network service facility must have remote monitoring equipment to transmit to AEMO's control centres in real time, the quantities that AEMO reasonably requires to discharge its market and power system security functions as set out in Chapters 3 and 4 of the Rules respectively.
(2)	The quantities may include such data as current, voltage, active power, reactive power, operational limits and critical temperatures in respect of connection points and power conversion systems.
(b)	Minimum access standard:
(1)	Each market network service facility must have remote monitoring equipment to transmit to AEMO's control centres in real time:
(A)	connection point active power flow, reactive power flow and voltage;
(B)	active power, reactive power and voltage for AC power lines, transformers and busbars, and power and voltage (or alternatively current) for DC power lines; and
(C)	the status of circuit breakers.
(c)	[Deleted]
S5.3a.4.2	[Deleted]
S5.3a.4.3	Communications equipment
A Market Network Service Provider must provide electricity supplies for remote monitoring equipment and remote control equipment installed in relation to its market network service facilities capable of keeping such equipment available for at least three hours following total loss of supply at the connection point for the relevant market network service facility.
A Market Network Service Provider must provide communications paths (with appropriate redundancy) from the remote monitoring equipment or remote control equipment installed at any of its market network service facilities to a interface for communication purposes in a location reasonably acceptable to the Network Service Provider at the relevant connection point. Communications systems between this interface for communication purposes and the control centre are the responsibility of the Network Service Provider unless otherwise agreed by the Market Network Service Provider and the Network Service Provider.
Telecommunications between Network Service Providers and Market Network Service Providers for operational communications must be established in accordance with the requirements set down below.
(a) 	  Primary Speech Facility 
The relevant Network Service Provider must provide and maintain equipment by means of which routine and emergency control telephone calls may be established between the Market Network Service Provider's responsible Engineer/Operator and AEMO.
The facilities to be provided, including the interface requirement between the Network Service Provider's equipment and the Market Network Service Provider's equipment, must be specified by the Network Service Provider.
The costs of the equipment must be recovered by the Network Service Provider only through the charge for connection.
(b) 	  Back-up Speech Facility 
Where the Network Service Provider or AEMO reasonably determines that a back-up speech facility to the primary facility is required, the Network Service Provider must provide and maintain a separate telephone link or radio installation on a cost-recovery basis only through the charge for connection.
The Network Service Provider is responsible for radio system planning and for obtaining all necessary radio licences.
S5.3a.5	Design standards
A Market Network Service Provider must ensure that:
(a)	the electrical plant in its facility complies with the relevant Australian Standards as applicable at the time of first installation of that electrical plant in the facility;
(b)	circuit breakers provided to isolate the Market Network Service Provider's facilities from the Network Service Provider's facilities are capable of breaking, without damage or restrike, fault currents nominated by the Network Service Provider in the relevant connection agreement; and
(c)	all new equipment including circuit breakers provided to isolate the Market Network Service Provider's facilities from the Network Service Provider's facilities is capable of withstanding, without damage, power frequency voltages and impulse levels nominated by the Network Service Provider in accordance with the relevant provisions of the system standards and recorded in the relevant connection agreement.
S5.3a.6	Protection systems and settings
A Market Network Service Provider must ensure that all connections to the network are protected by protection devices which effectively and safely disconnect any faulty circuit automatically within a time period specified by the Network Service Provider in accordance with the following provisions:
(a)	The automatic access standard is:
(1)	Primary protection systems must be provided to disconnect any faulted element from the power system within the applicable fault clearance time determined under clause S5.1.9(a)(1), but subject to clauses S5.1.9(k) and S5.1.9(l).
(2)	Each primary protection system must have sufficient redundancy to ensure that a faulted element within its protection zone is disconnected from the power system within the applicable fault clearance time with any single protection element (including any communications facility upon which that protection system depends) out of service.
(3)	Breaker fail protection systems must be provided to clear faults that are not cleared by the circuit breakers controlled by the primary protection system, within the applicable fault clearance time determined under clause S5.1.9(a)(1).
(b)	The minimum access standard is:
(1)	Primary protection systems must be provided to disconnect from the power system any faulted element within their respective protection zones within the applicable fault clearance time determined under clause S5.1.9(a)(2), but subject to clauses S5.1.9(k) and S5.1.9(l).
(2)	If a fault clearance time determined under clause S5.1.9(a)(2) for a protection zone is less than 10 seconds, a breaker fail protection system must be provided to clear from the power system any fault within that protection zone that is not cleared by the circuit breakers controlled by the primary protection system, within the applicable fault clearance time determined under clause S5.1.9(a)(3).
(c)	The Network Service Provider and the Market Network Service Provider must cooperate in the design and implementation of protection systems to comply with this clause, including cooperation with regard to:
(1)	the use of current transformer and voltage transformer secondary circuits (or equivalent) of one party by the protection system of the other;
(2)	tripping of one party's circuit breakers by a protection system of the other party; and
(3)	co-ordination of protection system settings to ensure inter-operation.
The Market Network Service Provider must ensure that the protection settings of its protective equipment grade with the Network Service Provider's transmission system or distribution system protection settings. Similarly the grading requirements of fuses must be co-ordinated with the Network Service Provider. The Market Network Service Provider must provide details of the protection scheme implemented by the Market Network Service Provider to the Network Service Provider and must liaise with the Network Service Provider when determining gradings and settings.
The application of settings of the protection scheme must be undertaken in accordance with clause S5.3a.2.
Before the Market Network Service Provider's installation is connected to the Network Service Provider's transmission or distribution system the Market Network Service Provider's protection system must be tested and the Market Network Service Provider must submit the appropriate test certificate to the Network Service Provider.
S5.3a.7	[Deleted]
S5.3a.8	Reactive power capability
Subject to the access standards stated in this clause S5.3a.8, if additional reactive support is required as a result of the connection or operation of the network elements which provide a market network service then the requisite reactive support must be supplied or paid for by the Market Network Service Provider.
Additional reactive support is required if, at rated power output as measured at the connection point of the market network service the market network service has a lagging power factor of less than 0.9 or a leading power factor of less than 0.95.
Automatic access standard: For power export, at rated power output and target network voltage as determined in accordance with clause S5.1a.4 of the system standards when measured at the connection point of the market network service, the market network service must be capable of operation in the range from a lagging power factor of 0.9 to a leading power factor of 0.95. For power import, the power factor must satisfy the requirements of clause S5.3.5 of schedule 5.3.
Minimum access standard: With the agreement of AEMO and the Network Service Provider, a power factor capability less than that defined by the automatic access standard may be provided if the requirements of the system standards are satisfied under all operating conditions of the market network service.
S5.3a.9	Balancing of load currents
A Network Service Provider may require a Market Network Service Provider's power transfer to be balanced at a connection point in order to maintain the negative sequence voltage at each connection point at less than or equal to the limits set out in Table S5.1a.1 of the system standards for the applicable nominal supply voltage level.
Automatic access standard: A Market Network Service Provider must ensure that for connections at 11kV or higher voltage, the current in any phase drawn by its equipment from the Network Service Provider's network is not greater than 102 percent or less than 98 percent of the average of the currents in the three phases.
Minimum access standard: Where agreed with the relevant Network Service Provider and subject to any specific conditions imposed, a Market Network Service Provider may cause current unbalance greater than that specified in the automatic access standard provided the Market Network Service Provider does not cause the limits specified in clause S5.1a.7 of the system standards to be exceeded at any point in the network.
Where these requirements cannot be met the Market Network Service Provider may enter into a commercial arrangement with the Network Service Provider for the installation of equipment to correct the phase unbalance. Such equipment must be considered as part of the connection assets for the Market Network Service Provider.
The limit to power transfer current unbalance must be included in the connection agreement and is subject to verification of compliance by the Network Service Provider.
S5.3a.10	Voltage fluctuations
(a)	Automatic access standard: The voltage fluctuations caused by variations in loading level at the connection point, including those arising from energisation, de-energisation or other operation of plant, must not exceed the limits determined under clause S5.1.5(a).
(b)	Minimum access standard: The voltage fluctuations caused by variations in loading level at the connection point, including those arising from energisation, de-energisation or other operation of plant, must not exceed the limits determined under clause S5.1.5(b).
The voltage fluctuation emission limits and any specified conditions must be included in the connection agreement, and are subject to verification of compliance by the Network Service Provider.
S5.3a.11	Harmonics and voltage notching
(a)	Automatic access standard: The harmonic voltage distortion caused by non-linearity, commutation of power electronic equipment, harmonic resonance and other effects within the plant, must not exceed the limits determined under clause S5.1.6(a).
(b)	Minimum access standard: The harmonic voltage distortion caused by non-linearity, commutation of power electronic equipment, harmonic resonance and other effects within the plant, must not exceed the limits determined under clause S5.1.6(b).
A Market Network Service Provider must ensure that all of its plant connected to a transmission network or distribution network is capable of withstanding the effects of harmonic levels produced by that plant plus those imposed from the network.
The harmonic voltage distortion emission limits and any special conditions must be included in the connection agreement, and are subject to verification of compliance by the Network Service Provider.
S5.3a.12	Design requirements for Market Network Service Providers' substations
A Market Network Service Provider must comply with the following requirements applicable to the design, station layout and choice of equipment for a substation:
(a)	safety provisions must comply with requirements applicable to the participating jurisdiction notified by the Network Service Provider;
(b)	where required by the Network Service Provider, appropriate interfaces and accommodation must be incorporated for communication facilities, remote monitoring and control and protection of plant which is to be installed in the substation;
(c)	a substation must be capable of continuous uninterrupted operation with the levels of voltage, harmonics, unbalance and voltage fluctuation specified in the system standards as modified in accordance with the relevant provisions of schedule 5.1;
(d)	earthing of primary plant in the substation must be in accordance with the Electricity Supply Association of Australia Safe Earthing Guide and must reduce step and touch potentials to safe levels;
(e)	synchronisation facilities or reclose blocking must be provided if necessary;
(f)	secure electricity supplies of adequate capacity must be provided for plant performing communication, monitoring, control and protection functions;
(g)	plant must be tested to ensure that the substation complies with the approved design and specifications as included in a connection agreement;
(h)	the protection equipment required would normally include protection schemes for individual items of plant, back-up arrangements, auxiliary DC supplies and instrumentation transformers; and
(i)	insulation levels of plant in the substation must co-ordinate with the insulation levels of the network to which the substation is connected as nominated in the connection agreement.
S5.3a.13	Market network service response to disturbances in the power system
(a)	Each market network service must be capable of continuous uninterrupted operation during the occurrence of:
(1)	power system frequency within the frequency operating standards; or
(2)	the range of voltage variation conditions permitted by the system standards.
(b)	The equipment associated with each market network service must be designed to withstand without damage or reduction in life expectancy the harmonic distortion and voltage unbalance conditions determined to apply in accordance with the provisions of schedule 5.1, clauses S5.1.6 and S5.1.7, respectively, at the connection point.
S5.3a.14	Protection of market network services from power system disturbances
(a)	Minimum access standard: If a Connection Applicant requires that its market network service facility be automatically disconnected from the power system in response to abnormal conditions arising from the power system, the relevant protection system or control system must not disconnect the facility for conditions under which it must continuously operate or must withstand under a provision of the Rules.
(b)	There is no automatic access standard for this technical requirement.
(c)	For the purposes of this clause S5.3a.14, the abnormal conditions include:
(1)	frequency outside the extreme frequency excursion tolerance limits;
(2)	sustained and uncontrollable DC current beyond a short term current rating for the period assigned to that rating;
(3)	DC voltage above the voltage maximum rating or sustained below any lower limit for stable operation;
(4)	voltage to frequency ratio beyond a transformer magnetic flux based voltage to frequency rating;
(5)	sustained voltage fluctuations at the connection point beyond the level determined under clause S5.1.5(a);
(6)	sustained harmonic voltage distortion at the connection point beyond the level determined under clause S5.1.6(a);
(7)	sustained negative phase sequence voltage at the connection point beyond the level determined under clause S5.1.7(a); and
(8)	any similar condition agreed between the Market Network Service Provider and AEMO after consultation with each relevant Network Service Provider.
(d)	[Deleted]
(e)	The Network Service Provider is not liable for any loss or damage incurred by the Market Network Service Provider or any other person as a consequence of a fault on either the power system, or within the Market Network Service Provider's facility.
Schedule 5.4	Information to be Provided with Preliminary Enquiry
The following items of information are required to be submitted with a preliminary enquiry for connection or modification of an existing connection:
(a)	Type of plant – (eg. gas turbine generating unit; rolling mill, etc.).
(b)	Preferred site location – (listing any alternatives in order of preference as well).
(c)	Maximum power generation or demand of whole plant – (maximum MW and/or MVA, or average over 15 minutes or similar).
(d)	Expected energy production or consumption (MWh per month).
(e)	Plant type and configuration – (eg. number and type of generating units or number of separate production lines).
(f)	Nature of any disturbing load (size of disturbing component MW/MVAr, duty cycle, nature of power electronic plant which may produce harmonic distortion).
(g)	Technology of proposed generating unit (e.g. synchronous generating unit, induction generator, photovoltaic array, etc).
(h)	When plant is to be in service – (eg. estimated date for each generating unit).
(i)	Name, ABN, ACN and address of enquirer, and, if relevant, of the party for whom the enquirer is acting.
(j)	Other information may be requested by the Network Service Provider, such as amount and timing of power required during construction or any auxiliary power requirements.
Schedule 5.4A	Preliminary Response
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.
Note
The local definitions in clause 5.10.2 apply to this schedule.
For the purposes of clause 5.3A.7(a), the following information must be included in the preliminary response:
(a)	relevant technical information about the Distribution Network Service Provider's distribution network, including guidance on how the Connection Applicant may meet the following requirements if it were to proceed to prepare an application to connect:
(1)	primary protection and backup protection;
(2)	other protection and control requirements applicable to embedded generating units and associated plant;
(3)	remote monitoring equipment and control communications facilities;
(4)	insulation co-ordination and lightning protection;
(5)	existing maximum and minimum fault levels and fault clearance times of relevant local zone substations;
(6)	switching and isolation facilities;
(7)	interlocking and synchronising arrangements;
(8)	metering installations; and
(9)	remedy or avoid an adverse system strength impact caused by the connection;
(b)	if not otherwise provided in accordance with paragraph (a), to the extent the Distribution Network Service Provider holds technical information necessary to prepare an application to connect, that information;
(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;
(d)	the identity of other parties that the Distribution Network Service Provider considers:
(1)	will need to be involved in planning to make the connection or must be involved under clause 5.3A.10(c); and
(2)	must be paid for transmission services or distribution services;
(e)	whether it will be necessary for any of the parties identified in subparagraph (d) to enter into an agreement with the Connection Applicant in respect of the provision of connection services or other transmission services or distribution services or both, to the Connection Applicant;
(f)	where relevant the Distribution Network Service Provider is to identify whether any service required to establish a connection is contestable in the relevant participating jurisdiction;
(g)	worked examples of connection service charges relevant to the enquiry and an explanation of the factors on which the charges depend;
(h)	information regarding the Distribution Network Service Provider and its network, system limitations for sub-transmission lines and zone substations and other information relevant to constraints on the network as such information is relevant to the application to connect;
(i)	an indication of whether network augmentation may be required and if required, what work the network augmentation may involve;
(i1)	an indication of whether the new connection is expected in the reasonable opinion of a Network Service Provider to have an adverse system strength impact;
(j)	a hyperlink to the Distribution Network Service Provider's information pack;
(k)	the contact details for the relevant point of contact within the Distribution Network Service Provider managing the connection enquiry;
(l)	the Distribution Network Service Provider's response to the objectives of the connection sought as included by the Connection Applicant in its enquiry under clause 5.3A.5(c)(1);
(m)	a description of the process for the provision of the detailed response, including the further information to be provided by the Connection Applicant and analysis to be undertaken by the Distribution Network Service Provider as part of the preparation of the detailed response;
(n)	an overview of any available options for connection to the Distribution Network Service Provider's network, as relevant to an enquiry lodged, at more than one connection point in a network, including:
(1)	example single line diagram and relevant protection systems and control systems used by existing connection arrangements;
(2)	a description of the characteristics of supply; and
(3)	an indication of the likely impact on terms and conditions of connection,
as relevant to each optional differing connection point;
(o)	a statement of further information required from the Connection Applicant for the preparation of the detailed response, including:
(1)	details of the Connection Applicant's connection requirements, and the Connection Applicant's specifications of the facility to be connected, consistent with the requirements advised in accordance with paragraphs (a) to (c); and
(2)	details of the Connection Applicant's reasonable expectations of the level and standard of service of power transfer capability that the network should provide;
(3)	the Connection Applicant's proposal for any system strength remediation scheme;
(p)	an estimate of the enquiry fee payable by the Connection Applicant for the detailed response, including details of how components of the fee were calculated;
(q)	the component of the estimate of the enquiry fee payable by the Connection Applicant to request the detailed response;
(r)	an estimate of the application fee which is payable on submitting an application to connect; and
(s)	any additional information relevant to the enquiry.
Schedule 5.4B	Detailed Response to Enquiry
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.
For the purposes of clause 5.3A.8(g), the following information must be included in the detailed response:
(a)	the contact details for the relevant point of contact within the Distribution Network Service Provider who will manage the application to connect;
(b)	written details of each technical requirement relevant to the proposed plant under jurisdictional electricity legislation;
(c)	details of the connection requirements based on the Connection Applicant's specifications of the facility to be connected;
(d)	details of the level and standard of service of power transfer capability that the Distribution Network Service Provider, with reasonable endeavours, considers the network provides at the location of the connection point or connection points, if options have been made available under clause S5.4A(n);
(e)	negotiated access standards that will require AEMO's involvement in accordance with clause 5.3.4A(c);
(e1)	written details of:
(1)	the minimum three phase fault level at the connection point; and
(2)	the results of the Network Service Provider's preliminary assessment of the impact of the new connection undertaken in accordance with the system strength impact assessment guidelines and clause 5.3.4B;
(f)	a list of the technical data to be included with the application to connect, which may vary depending on the connection requirements and the type, rating and location of the facility to be connected. The list provided under this paragraph (f) will generally be in the nature of the information set out in schedule 5.5 but may be varied by the Distribution Network Service Provider as appropriate to suit the size and complexity of the proposed facility to be connected;
(g)	commercial information to be supplied by the Connection Applicant to allow a Network Service Provider (as is relevant) to make an assessment of the ability of the Connection Applicant to satisfy the prudential requirements set out in rule 6.21;
(h)	so far as is relevant, and in relation to services that the Distribution Network Service Provider intends to provide, an itemised estimate of connection costs including:
(1)	connection services charges;
(2)	costs associated with the proposed metering requirements for the connection;
(3)	costs of any network extension;
(4)	details of augmentation required to provide the connection and associated costs;
(5)	details of the interface equipment required to provide the connection and associated costs;
(6)	details of any ongoing operation and maintenance costs and charges to be undertaken by the Distribution Network Service Provider; and
(7)	other incidental costs and their basis of calculation;
(i)	an explanation of the factors affecting each component of the itemised estimate of connection costs and the further information that will be taken into account by the Distribution Network Service Provider in preparing the final itemised statement of connection costs to be provided under clause 5.3.6(b2)(1);
(j)	using reasonable endeavours, all risks and obligations in respect of the proposed connection associated with planning and environmental laws not contained in the Rules;
(k)	a draft connection agreement that contains the proposed terms and conditions for connection to the network including those of the kind set out in schedule 5.6 and:
(1)	an explanation of the terms and conditions in the connection agreement that need to be finalised; and
(2)	if relevant, further information necessary from the Connection Applicant to finalise the connection agreement;
(l)	a description of the process for lodging the application to connect, including:
(1)	the options open to the Connection Applicant in submitting an application to connect in accordance with clause 5.3A.9;
(2)	the further analysis to be undertaken by the Distribution Network Service Provider as part of the Distribution Network Service Provider's assessment of the application to connect;
(3)	further information required from the Connection Applicant for the Distribution Network Service Provider to assess the application to connect; and
(4)	an outline of proposed milestones (and their timeframes) for connection and access activities which may be modified from time to time by agreement of the parties, where such agreement must not be unreasonably withheld;
(m)	the application fee payable when submitting an application to connect;
(n)	whether the Distribution Network Service Provider agrees to the detailed response remaining valid for a specified period of time to allow the Connection Applicant to lodge an application to connect within that time; and
(o)	any additional information relevant to the application to connect.
Schedule 5.5	Technical Details to Support Application for Connection and Connection Agreement
Note
This schedule has no effect in this jurisdiction (see regulation 5A of the National Electricity (Northern Territory) (National Uniform Legislation) (Modification) Regulations 2016).
S5.5.1	Introduction to the schedule
Various sections of the Rules require that Registered Participants submit technical data to the Network Service Provider. This schedule lists the range of data which may be required. The actual data required will be advised by the Network Service Provider, and will form part of the technical specification in the connection agreement. These data will also be made available to AEMO and to other Network Service Providers by the Network Service Provider at the appropriate time.
S5.5.2	Categories of data
Data is coded in categories, according to the stage at which it is available in the build-up of data during the process of forming a connection or obtaining access to a network, with data acquired at each stage being carried forward, or enhanced in subsequent stages, eg. by testing.
The Power System Model Guidelines, Power System Design Data Sheet and Power System Setting Data Sheet identify for each type of data, its category in terms of clause S5.5.2.
Codes:
S = Standard Planning Data
D = Detailed Planning Data
R = Registered Data (R1 pre-connection, R2 post-connection)
Preliminary system planning data
Preliminary system planning data is required for submission with the application to connect, to allow the Network Service Provider to prepare an offer of terms and conditions for a connection agreement and to assess the requirement for, and effect of, network augmentation or extension options. Such data is normally limited to the items denoted as Standard Planning Data (S) in the Power System Model Guidelines, Power System Design Data Sheet, Power System Setting Data Sheet and in schedules 5.5.3 to 5.5.5.
The Network Service Provider may, in cases where there is reasonable doubt as to the viability of a proposal, require the submission of other data before making an offer to connect or to amend a connection agreement.
Registered system planning data
Registered system planning data is the class of data which will be included in the connection agreement signed by both parties. It consists of the preliminary system planning data plus those items denoted in the attached schedules as Detailed Planning Data (D). The latter must be submitted by the Registered Participant in time for inclusion in the connection agreement.
Registered data
Registered Data consists of data validated and agreed between the Network Service Provider and the Registered Participant, such data being:
(a)	prior to actual connection and provision of access, data derived from manufacturers' data, detailed design calculations, works or site tests etc. (R1); and
(b)	after connection, data derived from on-system testing (R2).
All of the data will, from this stage, be categorised and referred to as Registered Data; but for convenience the schedules omit placing a higher ranked code next to items which are expected to already be valid at an earlier stage.
S5.5.3	Review, change and supply of data
Note
This schedule has no effect in this jurisdiction (see regulation 5A of the National Electricity (Northern Territory) (National Uniform Legislation) (Modification) Regulations 2016).
Data will be subject to review at reasonable intervals to ensure its continued accuracy and relevance. The Network Service Provider must initiate this review. A Registered Participant may change any data item at a time other than when that item would normally be reviewed or updated by submission to the Network Service Provider of the revised data, together with authentication documents, eg. test reports.
The Network Service Provider must supply data relating to its system to other Network Service Providers for planning purposes and to other Registered Participants and AEMO as specified in the various sections of the Rules, including through the statement of opportunities.
S5.5.4	Data Requirements
Note
This schedule has no effect in this jurisdiction (see regulation 5A of the National Electricity (Northern Territory) (National Uniform Legislation) (Modification) Regulations 2016).
Schedules 5.5.3 to 5.5.5 cover the following data areas:
(a)	schedule 5.5.3 - Network Plant Technical Data. This comprises fixed electrical parameters.
(b)	schedule 5.5.4 - Plant and Apparatus Setting Data. This comprises settings which can be varied by agreement or by direction of the Network Service Provider or AEMO.
(c)	schedule 5.5.5 - Load Characteristics. This comprises the estimated design parameters of loads.
The documents and schedules applicable to each class of Registered Participant are as follows:
(a)	Generators: the Power System Model Guidelines, Power System Design Data Sheet and Power System Setting Data Sheet;
(b)	Customers and Network Service Providers: schedules 5.5.3, 5.5.4 and the Power System Model Guidelines, Power System Design Data Sheet and Power System Setting Data Sheet;
(c)	Customers: schedule 5.5.5 and the Power System Model Guidelines, Power System Design Data Sheet and Power System Setting Data Sheet; and
(d)	Market Network Service Providers: schedules 5.5.3 and 5.5.4 and the Power System Model Guidelines, Power System Design Data Sheet and Power System Setting Data Sheet.
S5.5.5	Asynchronous generating unit data
Note
This schedule has no effect in this jurisdiction (see regulation 5A of the National Electricity (Northern Territory) (National Uniform Legislation) (Modification) Regulations 2016).
A Generator that connects a generating system, that is an asynchronous generating unit, must be given exemption from complying with those parts of the Power System Model Guidelines, Power System Design Data Sheet and Power System Design Data Sheet that are determined by the Network Service Provider to be not relevant to such generating systems, but must comply with those parts of schedules 5.5.3, 5.5.4, and 5.5.5 that are relevant to such generating systems, as determined by the Network Service Provider.
S5.5.6	Generating units smaller than 30MW data
A Generator that connects a generating unit smaller than 30 MW or generating units totalling less than 30 MW to a connection point to a distribution network must submit registered system planning data and registered data to AEMO and the relevant Network Service Provider in accordance with the requirements specified in the Power System Model Guidelines, Power System Design Data Sheet and Power System Setting Data Sheet.
Codes:
S = Standard Planning Data
D = Detailed Planning Data
R = Registered Data (R1 pre-connection,R2 post-connection)
S5.5.7	Power System Design Data Sheet, Power System Setting Data Sheet and Power System Model Guidelines
(a)	AEMO must, subject to paragraphs (b) and (c), develop, publish and maintain, in accordance with the Rules consultation procedures:
(1)	a Power System Design Data Sheet describing, for relevant plant technologies, plant design parameters including plant configurations, impedances, time constants, non-linearities, ratings and capabilities to be provided under clauses 3.11.5(b)(5), 3.11.9(g), 4.3.4(o), 5.2.3(j), 5.2.3(k), 5.2.3A(a), 5.2.4(c), 5.2.4(d), 5.2.5(d), 5.2.5(e), 5.3.9(b)(2), S5.2.4, S5.3.1, S5.3a.1 and this schedule 5.5;
(2)	a Power System Setting Data Sheet describing, for relevant power systems and control system technologies, the protection system and control system functions and their settings, including configurations, gains, time constants, delays, deadbands, non-linearities and limits to be provided under clauses 3.11.5(b)(5), 3.11.9(g), 4.3.4(o), 5.2.3(j), 5.2.3(k), 5.2.3A(a), 5.2.3A(b), 5.2.4(c), 5.2.4(d), 5.2.5(d), 5.2.5(e), 5.3.9(b)(2), S5.2.4, S5.3.1, S5.3a.1 and this schedule 5.5; and
(3)	Power System Model Guidelines describing, for relevant power system technologies at the transmission system and distribution system level, AEMO's requirements when developing mathematical models for plant, including the impact of their control systems and protection systems on power system security to be provided under clauses 3.11.5(b)(5), 3.11.9(g), 4.3.4(o), 5.2.3(j), 5.2.3(k), 5.2.3A(a), 5.2.3A(b), 5.2.4(c), 5.2.4(d), 5.2.5(d), 5.2.5(e), 5.3.9(b)(2), S5.2.4, S5.3.1, S5.3a.1 and this schedule 5.5.
(b)	When developing, publishing and maintaining the Power System Model Guidelines, the Power System Design Data Sheet and the Power System Setting Data Sheet under paragraph (a), AEMO must have regard to the purpose of the Power System Model Guidelines, the Power System Design Data Sheet and the Power System Setting Data Sheet, which is to:
(1)	allow plant and equipment to be mathematically modelled by AEMO with sufficient accuracy to permit:
(i)	the power system operating limits for ensuring power system security to be quantified with the lowest practical safety margins;
(ii)	the assessment of proposed negotiated access standards;
(iii)	settings of control systems and protection systems of plant and networks to be assessed and quantified for maximum practical performance of the power system; and
(iv)	the efficient procurement of system restart ancillary services and network support and control ancillary services; and
(2)	identify for each type of data its category in terms of clause S5.5.2.
(b1)	The Power System Model Guidelines must specify:
(1)	the information, including the types of models, that:
(i)	Generators must provide under clause 5.2.5(d), clause 5.2.5(e), clause 5.3.9(b)(2), clause S5.2.4 and clause S5.5.6;
(ii)	Network Service Providers must provide under clause 4.3.4(o), clause 5.2.3(j) and clause 5.2.3(k);
(iii)	Network Users must provide under clause 5.2.4(c), clause 5.2.4(d) and clause S5.3.1(a1);
(iv)	Market Network Service Providers must provide under clause 5.2.3A(a), clause 5.2.3A(b) and clause S5.3a.1(a1);
(v)	prospective NSCAS tenderers must provide under clause 3.11.5(b)(5); and
(vi)	prospective SRAS Providers must provide under clause 3.11.9(g);
(2)	the model accuracy requirements that are applicable to each type of model provided, as well as the types of generating systems and plant and equipment that the model accuracy requirements apply to;
(3)	when information to which the Power System Model Guidelines relates must be provided;
(4)	a process to be followed in circumstances where a person is unable to provide information required to be provided under clauses 3.11.5(b)(5), 3.11.9(g), 4.3.4(o), 5.2.3(j), 5.2.3(k), 5.2.3A(a), 5.2.3A(b), 5.2.4(c), 5.2.4(d), 5.2.5(d), 5.2.4(e), 5.3.9(b)(2), S5.2.4, S5.3.1, S5.3a.1, S5.5.6, schedule 5.5 or as otherwise required by the Power System Model Guidelines, Power System Design Data Sheet or Power System Setting Data Sheet;
(5)	guidance on the factors that AEMO will take into account when determining the circumstances under which AEMO will request information to be provided, including the power system conditions that necessitate the usage of a certain type of model in order to achieve the desired level of accuracy;
(6)	the format in which information must be provided and any material AEMO requires to assess the accuracy of information provided to it; and
(7)	the circumstances in which model source code is required to be provided.
(c)	In developing and amending the Power System Model Guidelines, the Power System Design Data Sheet and the Power System Setting Data Sheet, AEMO must:
(1)	have regard to the reasonable costs of efficient compliance by Registered Participants with those guidelines and data sheets compared to the likely benefits from the use of the information provided under the guidelines and data sheets;
(2)	have regard to any requirements to protect the intellectual property and confidential information of third parties, including where those third parties are not Registered Participants; and
(3)	have regard to Distribution Network Service Providers' and Transmission Network Service Providers' requirements for data and modelling information that is reasonably necessary for the relevant provider to fulfil its obligations under the Rules or jurisdictional electricity legislation.
(d)	AEMO may amend the Power System Model Guidelines, the Power System Design Data Sheet or the Power System Setting Data Sheet from time to time.
(e)	Any person may submit a written request (with reasons) for AEMO to amend the Power System Model Guidelines, the Power System Design Data Sheet or the Power System Setting Data Sheet from time to time.
(f)	In developing and amending the Power System Model Guidelines, the Power System Design Data Sheet or the Power System Setting Data Sheet, AEMO must, subject to paragraph (g), consult with Registered Participants and such other persons who, in AEMO's reasonable opinion have, or have identified themselves as having, an interest in the Power System Model Guidelines, in accordance with the Rules consultation procedures.
(g)	AEMO is not required to comply with the Rules consultation procedures when making minor or administrative amendments to the Power System Model Guidelines, the Power System Design Data Sheet or the Power System Setting Data Sheet.
(h)	AEMO may at the conclusion of the Rules consultation procedures under paragraph (f) or otherwise under paragraph (g), amend the relevant data sheet or guidelines (if necessary).
Schedule 5.5.1	[Deleted]
Schedule 5.5.2	[Deleted]
Schedule 5.5.3	Network and plant technical data of equipment at or near connection point
Note
This schedule has no effect in this jurisdiction (see regulation 5A of the National Electricity (Northern Territory) (National Uniform Legislation) (Modification) Regulations 2016).

Data Description	Units	Data Category	
 	Voltage Rating	
Nominal voltage 	kV	S, D	
Highest voltage	kV	D	
 	 	
 	Insulation Co-ordination	
Rated lightning impulse withstand voltage	kVp	D	
Rated short duration power frequency withstand voltage	kV	D	
 	 	
 	Rated Currents	
Circuit maximum current	kA	S, D	
Rated Short Time Withstand Current	kA for seconds	D	
Ambient conditions under which above current applies	Text	S,D	
 	 	
 	Earthing	
System Earthing Method	Text	S, D	
Earth grid rated current	kA for seconds	D	
 	 	
 	Insulation Pollution Performance	
Minimum total creepage	mm	D	
Pollution level	Level of IEC 815	D	
 	 	
 	Controls	
Remote control and data transmission arrangements	Text	D	
 	 	
 	Metering Provided by Customer	
Measurement transformer ratios:	 	D	
Current transformers 	A/A	D	
Voltage transformers 	V/kV	D	
Measurement Transformer Test Certification details	Text	R1	
 	 	
 	Network Configuration	
Operation Diagrams showing the electrical circuits of the existing and proposed main facilities within the Registered Participant's ownership including busbar arrangements, phasing arrangements, earthing arrangements, switching facilities and operating voltages.	Single line Diagrams	S, D, R1	
 	 	
 	Network Impedance	
For each item of plant:
details of the positive, negative and zero sequence series and shunt impedance, including mutual coupling between physically adjacent elements.	% on 100 MVA base	S, D, R1	
 	 	
 	Short Circuit Infeed to the Network	
Maximum generator 3-phase short circuit infeed including infeeds from generating units connected to the Registered Participant's system, calculated by method of AS 3851 (1991).	kA symmetrical	S, D, R1	
The total infeed at the instant of fault (including contribution of induction motors).	kA	D, R1	
Minimum zero sequence impedance of Registered Participant's network at connection point.	% on 100 MVA base	D, R1	
Minimum negative sequence impedance of Registered Participant's network at connection point.	% on 100 MVA base	D, R1	
 	 	
 	Load Transfer Capability:	
Where a load, or group of loads, may be fed from alternative connection points:	 	 	
Load normally taken from connection point X	MW	D, R1	
Load normally taken from connection point Y	MW	D, R1	
Arrangements for transfer under planned or fault outage conditions	Text	D	
 	 	
 	Circuits Connecting Embedded Generating Units to the Network:	
For all generating units, all connecting lines/cables, transformers etc.	 	 	
Series Resistance	% on 100 MVA base	D, R	
Series Reactance	% on 100 MVA base	D, R	
Shunt Susceptance	% on 100 MVA base	D, R	
Normal and short-time emergency ratings	MVA	D,R	
Technical Details of generating units and generating systems as per the Power System Design Data Sheet, Power System Setting Data Sheet and the Power System Model Guidelines where such details are not confidential information	 	 	
 	 	
 	Transformers at connection points:	
Saturation curve	Diagram	R	
Equipment associated with DC Links	 	 	
Number of poles	MVA	D,R	
Converters per station	Quantity	D,R	
Reactive Power consumption of converters	MCAr	D,R	
Location and Rating of A.C. Filters	MVAr	D,R	
Location and Rating of Shunt Capacitors	MVAr	D,R	
Location and Rating of Smoothing Reactor	MVAr	D,R	
Location and Rating of DC Filter	MVAr	D,R	

Schedule 5.5.4	Network Plant and Apparatus Setting Data
Note
This schedule has no effect in this jurisdiction (see regulation 5A of the National Electricity (Northern Territory) (National Uniform Legislation) (Modification) Regulations 2016).

Data Description	Units	Data Category	
Protection Data for Protection relevant to Connection Point:	 	 	
Reach of all protections on transmission lines, or cables	ohms or % on 100 MVA base	S, D	
Number of protections on each item	Text	S, D	
Total fault clearing times for near and remote faults	ms	S, D, R1	
Line reclosure sequence details	Text	S, D, R1	
 	 	
Tap Change Control Data:	 	 	
Time delay settings of all transformer tap changers.	Seconds	D, R1	
 	 	
Reactive Compensation:	 	 	
Location and Rating of individual shunt reactors	MVAr	D, R1	
Location and Rating of individual shunt capacitor banks	MVAr	D, R1	
Capacitor bank capacitance	microfarads	D	
Inductance of switching reactor (if fitted)	millihenries	D	
Resistance of capacitor plus reactor	Ohms	D	
Details of special controls (e.g. Point-on-wave switching)	Text	D	
 	 	
 	For each shunt reactor or capacitor bank:	
Method of switching	Text	S	
Details of automatic control logic such that operating characteristics can be determined	Text	D, R1	
 	 	
 	FACTS Installation:	
Data sufficient to enable static and dynamic performance of the installation to be modelled	Text, diagrams control settings	S, D, R1	
Transmission line flow control device	Text,	D	
Details of the operation of the control device under normal operation conditions (including startup and shutdown of the line) and during a fault (close up and remote)	diagrams	 	
Models for the control device and transmission line appropriate for load flow, small signal stability and transient stability analysis	Text, diagrams	D	
Capability of the line flow control device	KA, MVA, MW	D	
Details of the rate of change of flow capability of the control device	Text	D	
Details of the capability of the control device to provide frequency and voltage control	Text	D	
Description of possible failure modes of control device	Text	D	
Details of performance of the control device under disturbance conditions including changes in AC frequency, variations in AC system voltages and Ac system waveform distortion.	Text	D	
For DC control devices, contribution to the AC system short circuit level	KA, MVA	D	
 	 	
 	Short circuit ratio	
The lowest short circuit ratio at the connection point for which the generating system, including its control systems: (i) will be commissioned to maintain stable operation; and (ii) has the design capability to maintain stable operation.	Numeric ratio	S, D, R1	
For the purposes of the above, "short circuit ratio" is the synchronous three phase fault level (expressed in MVA) at the connection point divided by the rated output of the generating system (expressed in MW or MVA).	 	 	

Schedule 5.5.5	Load Characteristics at Connection Point
Note
This schedule has no effect in this jurisdiction (see regulation 5A of the National Electricity (Northern Territory) (National Uniform Legislation) (Modification) Regulations 2016).

Data Description	Units	Data Category	
For all Types of Load	 	 	
 	 	 	
Type of Load	Text	S	
 	eg controlled rectifiers or large motor drives	
 	 	
 	For Fluctuating Loads	
Cyclic variation of active power over period	Graph
MW/time	S	
Cyclic variation of reactive power over period	Graph
MVAr/time	S	
Maximum rate of change of active power	MW/s	S	
Maximum rate of change of reactive power	MVAr/s	S	
Shortest Repetitive time interval between fluctuations in active and reactive power reviewed annually	s	S	
 	 	
 	Largest Step Change:	
In active power	MW	S	
In reactive power	MVAr	S	

Schedule 5.6	Terms and Conditions of Connection agreements and network operating agreements
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.
Part A	Connection agreements
The connection agreements must contain the specific conditions that have been agreed to for connection and access to the transmission or distribution network, including but not limited to:
(a)	details of the connection point including the distribution network coupling points where appropriate;
(b)	metering arrangements and adjustments for losses where the point of metering is significantly different to the connection point;
(c)	authorised demand which may be taken or supplied at the connection point (under specified conditions);
(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.
(c2)	details of any system strength remediation scheme agreed, determined or modified in accordance with clause 5.3.4B and associated terms and conditions;
(c3)	details of any system strength connection works;
(d)	connection service charges;
(e)	payment conditions;
(f)	duration and termination conditions of the connection agreement;
(g)	terms, conditions and constraints that have been agreed to for connection to the network to protect the legitimate interest of the Network Service Providers including rights to disconnect the Registered Participant for breach of commercial undertakings;
(h)	details of any agreed standards of reliability of transmission service or distribution service at the connection points or within the network;
(i)	testing intervals for protection systems associated with the connection point;
(j)	agreed protocols for maintenance co-ordination;
(k)	where an expected load, to be connected to a network, has a peak load requirement in excess 10 MW, the provision, installation, operation and maintenance of automatic load shedding facilities for 60 percent of the load at anytime;
(l)	terms and conditions of access to the metering installation for the Metering Provider and access to metering installations type 4A, 5 and 6 for the Metering Data Provider.
(m)	the arrangements for the provision of services relating to non-contestable IUSA components (if applicable);
(n)	the functional specifications for the contestable IUSA components; and
(o)	if the Connection Applicant has obtained services related to a contestable IUSA components other than from the Primary Transmission Network Service Provider and intends to transfer ownership of some or all of those components to the Primary Transmission Network Service Provider, arrangements for the transfer of ownership of those components upon energisation of the identified user shared asset to the Primary Transmission Network Service Provider (if applicable) and how any defects liabilities will be managed.
The connection agreements may include other technical, commercial and legal conditions governing works required for the connection or extension to the network which the parties have negotiated and agreed to. The circumstances under which the terms of the connection agreement would require renegotiation may also be included.
Part B	Network Operating Agreements
A network operating agreement between the Primary Transmission Network Service Provider and the owner of contestable IUSA components must include provisions relating to:
(a)	agreed boundaries and physical connection obligations and interface between the identified user shared asset and the transmission network;
(b)	conditions to transfer operational control of the asset to the Primary Transmission Network Service Provider;
(c)	the standard of care to apply to the Primary Transmission Network Service Provider in providing operation and maintenance services;
(d)	insurance obligations;
(e)	termination, events of default and force majeure regime;
(f)	liability and indemnity; and
(g)	defect warranties.
Schedule 5.7	Annual Forecast Information for Planning Purposes
This schedule sets out the information in respect of each connection point that must be provided to the relevant Network Service Provider by each Registered Participant that has a connection point to a transmission network of that Network Service Provider.

Data Description	Units	Time Scale	Data Category	
At each connection point to a transmission network, a forecast of:	 	 	 	
 	 	 	 	
Annual Maximum Active power- Winter	MW	years 1-10	Annual	
 	 	
Coincident Reactive Power - Winter	MVAr	years 1-10	Annual	
 	 	
Annual Maximum Active power- Summer	MW	years 1-10	Annual	
 	 	
Coincident Reactive Power- Summer	MVAr	years 1-10	Annual	
 	 	
Forecast load diversity between each connection point to the network (winter and summer)	%	years 1-5	Annual	
 	 	
 	Load Profiles:	
 	 	
The following forecast daily profiles of connection point half-hourly average active and reactive loads are required, net of all generating plant:	 	 	 	
 	 	
Day of the peak summer and winter MW peak load at connection point	MW and MVAr	years 1-5	Annual	
 	 	
Day of network peak summer and winter MW load (as specified)	MW and MVAr	years 1-5	Annual	

Data Description	Units	Time Scale	Data Category	
Each July, October, January, April under average conditions representing:	 	 	 	
 	 	 	 	
(a)	weekdays	MW and MVAr	years 1-5	Annual	
 	 	 	 	
(b)	Saturdays	MW and MVAr	years 1-5	Annual	
 	 	 	 	
(c)	Sundays/holidays	MW and MVAr	years 1-5	Annual	
 	 	
Day of the network minimum demand (as specified)	MW and MVAr	years 1-5	Annual	
 	 	
 	Undispatched generation:	
 	 	
For each connection point to the network the following information is required:	 	 	 	
 	 	
No. of generating units	No.	years 1-5	Annual	
 	 	
Capacity of each generating unit	MW (sent out)	years 1-5	Annual	
 	 	
Daily/Seasonal Operating characteristics	Text	years 1-5	Annual	
 	 	
Expected output at time of peak network Winter load (as specified)	MW	years 1-5	Annual	
 	 	
Expected output at time of peak network Summer load (as specified)	MW	years 1-5	Annual	

Schedule 5.8	Distribution Annual Planning Report
Note
The local definitions in clause 5.10.2 apply to this schedule.
Note
The application of paragraph (m) of this schedule will be revisited as part of the phased implementation of the Rules in this jurisdiction.
For the purposes of clause 5.13.2(c), the following information must be included in a Distribution Annual Planning Report:
(a)	information regarding the Distribution Network Service Provider and its network, including:
(1)	a description of its network;
(2)	a description of its operating environment;
(3)	the number and types of its distribution assets;
(4)	methodologies used in preparing the Distribution Annual Planning Report, including methodologies used to identify system limitations and any assumptions applied; and
(5)	analysis and explanation of any aspects of forecasts and information provided in the Distribution Annual Planning Report that have changed significantly from previous forecasts and information provided in the preceding year;
(b)	forecasts for the forward planning period, including at least:
(1)	a description of the forecasting methodology used, sources of input information, and the assumptions applied;
(2)	load forecasts:
(i)	at the transmission-distribution connection points;
(ii)	for sub-transmission lines; and
(iii)	for zone substations,
including, where applicable, for each item specified above:
(iv)	total capacity;
(v)	firm delivery capacity for summer periods and winter periods;
(vi)	peak load (summer or winter and an estimate of the number of hours per year that 95% of peak load is expected to be reached);
(vii)	power factor at time of peak load;
(viii)	load transfer capacities; and
(ix)	generation capacity of known embedded generating units;
(3)	forecasts of future transmission-distribution connection points (and any associated connection assets), sub-transmission lines and zone substations, including for each future transmission-distribution connection point and zone substation:
(i)	location;
(ii)	future loading level; and
(iii)	proposed commissioning time (estimate of month and year);
(4)	forecasts of the Distribution Network Service Provider's performance against any reliability targets in a service target performance incentive scheme; and
(5)	a description of any factors that may have a material impact on its network, including factors affecting;
(i)	fault levels;
(ii)	voltage levels;
(iii)	other power system security requirements;
(iv)	the quality of supply to other Network Users (where relevant); and
(v)	ageing and potentially unreliable assets;
(b1)	for all network asset retirements, and for all network asset de-ratings that would result in a system limitation, that are planned over the forward planning period, the following information in sufficient detail relative to the size or significance of the asset:
(1)	a description of the network asset, including location;
(2)	the reasons, including methodologies and assumptions used by the Distribution Network Service Provider, for deciding that it is necessary or prudent for the network asset to be retired or de-rated, taking into account factors such as the condition of the network asset;
(3)	the date from which the Distribution Network Service Provider proposes that the network asset will be retired or de-rated; and
(4)	if the date to retire or de-rate the network asset has changed since the previous Distribution Annual Planning Report, an explanation of why this has occurred;
(b2)	for the purposes of subparagraph (b1), where two or more network assets are:
(1)	of the same type;
(2)	to be retired or de-rated across more than one location;
(3)	to be retired or de-rated in the same calendar year; and
(4)	each expected to have a replacement cost less than $200,000 (as varied by a cost threshold determination),
those assets can be reported together by setting out in the Distribution Annual Planning Report:
(5)	a description of the network assets, including a summarised description of their locations;
(6)	the reasons, including methodologies and assumptions used by the Distribution Network Service Provider, for deciding that it is necessary or prudent for the network assets to be retired or de-rated, taking into account factors such as the condition of the network assets;
(7)	the date from which the Distribution Network Service Provider proposes that the network assets will be retired or de-rated; and
(8)	if the calendar year to retire or de-rate the network assets has changed since the previous Distribution Annual Planning Report, an explanation of why this has occurred;
(c)	information on system limitations for sub-transmission lines and zone substations, including at least:
(1)	estimates of the location and timing (month(s) and year) of the system limitation;
(2)	analysis of any potential for load transfer capacity between supply points that may decrease the impact of the system limitation or defer the requirement for investment;
(3)	impact of the system limitation, if any, on the capacity at transmission-distribution connection points;
(4)	a brief discussion of the types of potential solutions that may address the system limitation in the forward planning period, if a solution is required; and
(5)	where an estimated reduction in forecast load would defer a forecast system limitation for a period of at least 12 months, include:
(i)	an estimate of the month and year in which a system limitation is forecast to occur as required under subparagraph (1);
(ii)	the relevant connection points at which the estimated reduction in forecast load may occur; and
(iii)	the estimated reduction in forecast load in MW or improvements in power factor needed to defer the forecast system limitation;
(d)	for any primary distribution feeders for which a Distribution Network Service Provider has prepared forecasts of maximum demands under clause 5.13.1(d)(1)(iii) and which are currently experiencing an overload, or are forecast to experience an overload in the next two years the Distribution Network Service Provider must set out:
(1)	the location of the primary distribution feeder;
(2)	the extent to which load exceeds, or is forecast to exceed, 100% (or lower utilisation factor, as appropriate) of the normal cyclic rating under normal conditions (in summer periods or winter periods);
(3)	the types of potential solutions that may address the overload or forecast overload; and
(4)	where an estimated reduction in forecast load would defer a forecast overload for a period of 12 months, include:
(i)	estimate of the month and year in which the overload is forecast to occur;
(ii)	a summary of the location of relevant connection points at which the estimated reduction in forecast load would defer the overload;
(iii)	the estimated reduction in forecast load in MW needed to defer the forecast system limitation;
(e)	a high-level summary of each RIT-D project for which the regulatory investment test for distribution has been completed in the preceding year or is in progress, including:
(1)	if the regulatory investment test for distribution is in progress, the current stage in the process;
(2)	a brief description of the identified need;
(3)	a list of the credible options assessed or being assessed (to the extent reasonably practicable);
(4)	if the regulatory investment test for distribution has been completed a brief description of the conclusion, including:
(i)	the net economic benefit of each credible option;
(ii)	the estimated capital cost of the preferred option; and
(iii)	the estimated construction timetable and commissioning date (where relevant) of the preferred option; and
(5)	any impacts on Network Users, including any potential material impacts on connection charges and distribution use of system charges that have been estimated;
(f)	for each identified system limitation which a Distribution Network Service Provider has determined will require a regulatory investment test for distribution, provide an estimate of the month and year when the test is expected to commence;
(g)	a summary of all committed investments to be carried out within the forward planning period with an estimated capital cost of $2 million or more (as varied by a cost threshold determination) that are to address an urgent and unforeseen network issue as described in clause 5.17.3(a)(1), including:
(1)	a brief description of the investment, including its purpose, its location, the estimated capital cost of the investment and an estimate of the date (month and year) the investment is expected to become operational;
(2)	a brief description of the alternative options considered by the Distribution Network Service Provider in deciding on the preferred investment, including an explanation of the ranking of these options to the committed project. Alternative options could include, but are not limited to, generation options, demand side options, and options involving other distribution or transmission networks;
(h)	the results of any joint planning undertaken with a Transmission Network Service Provider in the preceding year, including:
(1)	a summary of the process and methodology used by the Distribution Network Service Provider  and relevant Transmission Network Service Providers to undertake joint planning;
(2)	a brief description of any investments that have been planned through this process, including the estimated capital costs of the investment and an estimate of the timing (month and year) of the investment; and
(3)	where additional information on the investments may be obtained;
(i)	the results of any joint planning undertaken with other Distribution Network Service Providers in the preceding year, including:
(1)	a summary of the process and methodology used by the Distribution Network Service Providers to undertake joint planning;
(2)	a brief description of any investments that have been planned through this process, including the estimated capital cost of the investment and an estimate of the timing (month and year) of the investment; and
(3)	where additional information on the investments may be obtained;
(j)	information on the performance of the Distribution Network Service Provider's network, including:
(1)	a summary description of reliability measures and standards in applicable regulatory instruments;
(2)	a summary description of the quality of supply standards that apply, including the relevant codes, standards and guidelines;
(3)	a summary description of the performance of the distribution network against the measures and standards described under subparagraphs (1) and (2) for the preceding year;
(4)	where the measures and standards described under subparagraphs (1) and (2) were not met in the preceding year, information on the corrective action taken or planned;
(5)	a summary description of the Distribution Network Service Provider's processes to ensure compliance with the measures and standards described under subparagraphs (1) and (2); and
(6)	an outline of the information contained in the Distribution Network Service Provider's most recent submission to the AER under the service target performance incentive scheme;
(k)	information on the Distribution Network Service Provider's  asset management approach, including:
(1)	a summary of any asset management strategy employed by the Distribution Network Service Provider;
(1A)	an explanation of how the Distribution Network Service Provider takes into account the cost of distribution losses when developing and implementing its asset management and investment strategy;
(2)	a summary of any issues that may impact on the system limitations identified in the Distribution Annual Planning Report that has been identified through carrying out asset management; and
(3)	information about where further information on the asset management strategy and methodology adopted by the Distribution Network Service Provider may be obtained;
(l)	information on the Distribution Network Service Provider's demand management activities, including:
(1)	a qualitative summary of:
(i)	non-network options that have been considered in the past year, including generation from embedded generating units;
(ii)	key issues arising from applications to connect embedded generating units received in the past year;
(iii)	actions taken to promote non-network proposals in the preceding year, including generation from embedded generating units; and
(iv)	the Distribution Network Service Provider's plans for demand management and generation from embedded generating units over the forward planning period;
(2)	a quantitative summary of:
(i)	connection enquiries received under clause 5.3A.5;
(ii)	applications to connect received under clause 5.3A.9; and
(iii)	the average time taken to complete applications to connect;
(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
(n)	a regional development plan consisting of a map of the Distribution Network Service Provider's network as a whole, or maps by regions, in accordance with the Distribution Network Service Provider's planning methodology or as required under any regulatory obligation or requirement, identifying:
(1)	sub-transmission lines, zone substations and transmission-distribution connection points; and
(2)	any system limitations that have been forecast to occur in the forward planning period, including, where they have been identified, overloaded primary distribution feeders.
Schedule 5.9	Demand side engagement document (clause 5.13.1(h))
Note
The local definitions in clause 5.10.2 apply to this schedule.
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.
For the purposes of clause 5.13.1(h), the following information must be included in a Distribution Network Service Provider's demand side engagement document:
(a)	a description of how the Distribution Network Service Provider will investigate, develop, assess and report on potential non-network options;
(b)	a description of the Distribution Network Service Provider's process to engage and consult with potential non-network providers to determine their level of interest and ability to participate in the development process for potential non-network options;
(c)	an outline of the process followed by the Distribution Network Service Provider when negotiating with non-network providers to further develop a potential non-network option;
(d)	an outline of the information a non-network provider is to include in a non-network proposal, including, where possible, an example of a best practice non-network proposal;
(e)	an outline of the criteria that will be applied by the Distribution Network Service Provider in evaluating non-network proposals;
(f)	an outline of the principles that the Distribution Network Service Provider considers in developing the payment levels for non-network options;
(g)	a reference to any applicable incentive payment schemes for the implementation of non-network options and whether any specific criteria is applied by the Distribution Network Service Provider in its application and assessment of the scheme;
(h)	the methodology to be used for determining avoided Customer TUOS charges, in accordance with clauses 5.4AA and 5.5; and;
(i)	a summary of the factors the Distribution Network Service Provider takes into account when negotiating connection agreements with Embedded Generators;
(j)	the process used, and a summary of any specific regulatory requirements, for setting charges and the terms and conditions of connection agreements for embedded generating units;
(k)	the process for lodging an application to connect for an embedded generating unit and the factors taken into account by the Distribution Network Service Provider when assessing such applications;
(l)	worked examples to support the description of how the Distribution Network Service Provider will assess potential non-network options in accordance with paragraph (a);
(m)	a hyperlink to any relevant, publicly available information produced by the Distribution Network Service Provider;
(n)	a description of how parties may be listed on the demand side engagement register; and
(o)	the Distribution Network Service Provider's contact details.
Note
Paragraph (h) of this schedule has no effect in this jurisdiction, and the remainder of this schedule 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 paragraph (h) of this schedule will be revisited as part of the phased implementation of the Rules in this jurisdiction.
Schedule 5.10	Information requirements for Primary Transmission Network Service Providers (clause 5.2A.5)

Information	Via website or direct enquiry	Additional fee	Comments	
Technical specification	
Generic interface works	Website	No	Typical standards and layouts must be published. This information:
(a)	may be generic but should provide a high level overview of the components of a connection; and
(b)	must provide Connection Applicants with a high level understanding of what a connection consists of.
Primary Transmission Network Service Providers must provide the design standards which are specific to their network.
 	
Generic substation layouts	Website	No		
Typical overhead line structures	Website	No		
Typical underground cable arrangements	Website	No		
Typical primary plant	Website	No		
Design standards	Website	No		
Typical secondary systems	Website	No		
Detailed technical requirements for a particular connection	Direct enquiry	No	Functional specification to describe the requirements that must be met by the detailed design.
The functional specifications must include:
(a)	description of any proposed augmentation; and
(b)	references to typical plant including primary and secondary equipment so that the detailed design will interface to the existing network and be able to be adopted by the Primary Transmission Network Service Provider.	
Operation and maintenance	
Typical operation and maintenance scheduling	Website	No	Operation and maintenance intervals for specific items of plant used regularly by the Primary Transmission Network Service Provider must be published. These are routine activities irrespective of whether assets are unregulated or regulated and should be in line with good electricity industry practice.	
Timescales	
Easement acquisition (site specific)	Direct enquiry	Yes	Site specific timescales may be discussed and negotiated on a project by project basis as part of the connection enquiry / connection application process if the Connection Applicant requests it at their election.	
Commission- ing (generic)	Website	No	Generic timescales must be published.	
Commission- ing (site specific)	Direct enquiry	Yes	Site specific timescales may be provided as part of the connection enquiry / connection application process if the Connection Applicant requests it at their election.	
Legal	
Standard connection agreements	Website	No	Standard forms of these agreements and deeds to be published.
The standard form construction agreement must cover the construction of any interface works.
The standard form connection agreement must cover the connection of the asset to the transmission network.
The standard form network operating agreement must cover those aspects referred to in clause 5.2.7(b).	
Standard network operating agreement	Website	No		
Standard interface works construction agreements	Website	No		
Standard relocation deeds	Website	No		
Environment- al approvals (generic)	Website	No	Standard forms or lists of required approvals must be published.
Site specific information may be provided as part of the connection enquiry / connection application process if Connection Applicant requests it at their election.	
Environment- al approvals (site specific)	Direct enquiry	Yes		
Development approvals (generic)	Website	No		
Development approvals (site specific)	Direct enquiry	Yes		
Financial	
Amount and terms and conditions of the connection application charge	Website	No	A guide to the structure of the application fee under clause 5.3.4, and the terms and conditions under which the charge is paid, must be published.	
Relocation of existing assets	Direct enquiry	Yes	Specific information about relocation of existing assets may be provided by the Primary Transmission Network Service Provider, if the Connection Applicant requests it at their election.
The Connection Applicant would be required to pay for any costs associated with the relocation of assets.	

Schedule 5.11	Negotiating principles for negotiated transmission services (clause 5.2A.6)
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.
1	The price for a negotiated transmission service should be based on the costs incurred in providing that service, determined in accordance with the principles and policies set out in the Cost Allocation Methodology for the relevant Transmission Network Service Provider.
2	Subject to paragraphs (3) and (4), the price for a negotiated transmission service should be at least equal to the avoided cost of providing it but no more than the cost of providing it on a stand-alone basis.
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.
4	If the negotiated transmission service is the provision of a shared transmission service that does not meet (and does not exceed) the network performance requirements set out in schedules 5.1a and 5.1, 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 set out in schedules 5.1a and 5.1 should reflect the amount of the Transmission Network Service Provider's avoided cost of providing that service.
5	The price for a negotiated transmission service must be the same for all Transmission Network Users unless there is a material difference in the costs of providing the negotiated transmission service to different Transmission Network Users or classes of Transmission Network Users.
6	The price for a negotiated transmission service should be subject to adjustment over time to the extent that the assets used to provide that service are subsequently used to provide services to another person, in which case such adjustment should reflect the extent to which the costs of that asset is being recovered through charges to that other person.
7	The price for a negotiated transmission service should be such as to enable the Transmission Network Service Provider to recover the efficient costs of complying with all regulatory obligations or requirements associated with the provision of the negotiated transmission service.
8	The terms and conditions of access for a negotiated transmission service should be fair and reasonable and consistent with the safe and reliable operation of the power system in accordance with the Rules (for these purposes, the price for a negotiated transmission service is to be treated as being fair and reasonable if it complies with principles (1) to (7) (other than principles (1) and (4)) of this schedule 5.11).
9	The terms and conditions of access for a negotiated transmission service (including, in particular, any exclusions and limitations of liability and indemnities) must not be unreasonably onerous taking into account the allocation of risk between the Transmission Network Service Provider and the other party, the price for the negotiated transmission service and the costs to the Transmission Network Service Provider of providing the negotiated transmission service.
10	The terms and conditions of access for a negotiated transmission service should be provided in a manner that does not adversely affect the safe and reliable operation of the power system in accordance with the Rules.
11	The Connection Applicant should only be required to pay the costs directly incurred as a result of its connection, including its share of costs associated with an identified user shared asset.
12	Subsequent connections to an identified user shared asset by other connecting parties should not adversely affect the negotiated transmission services provided to the original identified user group for that identified user shared asset.
13	Subject to principle 11, future Connection Applicants should pay for a proportion of the costs paid by the identified user groups for negotiated transmission services. The proportion of costs will be calculated with respect to:
(1)	the relative capacity of the Connection Applicant's generating plant; or
(2)	the relative number of bays; or
(3)	respective bays,
with the applicable cost sharing methodology determined as appropriate by the nature of the negotiated transmission services.
Schedule 5.12	Negotiating principles for large DCA services
1	Principles 2 -7 of schedule 5.11 (other than principle 4) apply in relation to connection and access to large DCA services, except a reference to a negotiated transmission service and a Transmission Network Service Provider will be taken to be a reference to a large DCA service and a Dedicated Connection Asset Service Provider respectively.
2	An applicant for large DCA services should pay for the cost of any enlargement or increase in capacity of (an "upgrade"), or alterations to, an existing large dedicated connection asset required to provide it with large DCA services, including the moving of metering and other related equipment, necessary for the applicant's connection to the large dedicated connection asset.
3	The connection of an applicant to an existing large dedicated connection asset and access to large DCA services must not adversely affect the access standards, including performance standards and power transfer capability of an existing connecting party at the time of the access application by the applicant.
4	The connection of an applicant to an existing large dedicated connection asset and access to large DCA services must not adversely affect contractual obligations of an existing connecting party to the large dedicated connection asset with the relevant Dedicated Connection Asset Service Provider.
5	An applicant must compensate the Dedicated Connection Asset Service Provider (and any existing connecting party) for any lost revenue incurred during an upgrade of, or alterations to, an existing large dedicated connection asset and metering and other related equipment moves to provide for the connection and operation of the applicant's facilities and access to large DCA services.
6	The connection of an applicant to a large dedicated connection asset and access to large DCA services must not:
(a)	prevent an existing connecting party at the time of the applicant's access application from obtaining a sufficient amount of large DCA services to be able to meet that person's reasonably anticipated requirements, measured at the time of the access application by the applicant;
(b)	result in the applicant becoming the owner (or one of the owners) of any part of the existing large dedicated connection asset or upgrade of that asset without the consent of the existing owner;
(c)	require an existing connecting party or the owner of the large dedicated connection asset to bear all or some of the costs of an upgrade of the large dedicated connection asset or maintaining an upgrade;
(d)	require an existing connecting party to the large dedicated connection asset to bear all or some of the costs of an interconnection to the large dedicated connection asset or maintaining an interconnection.