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National Electricity Rules As in force in the Northern Territory Version 38

Status Information

This is the latest electronically available version of the National Electricity Rules as in force in the Northern Territory (NT NER) as at 7 November 2019.

This consolidated version of the NT NER reflects the current version of the National Electricity Rules (version 126) as amended by the following regulations made by the Northern Territory under section 13(2)(c) of the National Electricity (Northern Territory) (National Uniform Legislation) Act:

National Electricity (Northern Territory) (National Uniform Legislation) (Modification) Regulations.

Provisions in force

All provisions displayed in this consolidated version of the Rules have commenced. As at the date of this consolidation:

(a) the Australian Energy Market Commission has made certain Rules under Part 7, Division 3 of the National Electricity Law that have not yet commenced. A complete list of these Rules is set out under "Provisions in Force" on the cover sheet of the latest version of the National Electricity Rules.

(b) As at the date of this consolidation, the Northern Territory has adopted (or adopted a modified version of) various provisions of the National Electricity Rules with effect from 1 July 2019 and certain other provisions with effect from the date that the Northern Territory adopts the National Energy Retail Law as a law of the Northern Territory. The provisions to be adopted and the modifications to those provisions (if relevant) are specified in the National Electricity (Northern Territory)(National Uniform Legislation)(Modification) Regulations.

This consolidated version of the NT NER contains drafting notes to indicate the provisions of the National Electricity Rules that have been adopted in the Northern Territory with effect from a later date.

TABLE OF CONTENTS

(NATIONAL ELECTRICITY RULES AS IN FORCE IN THE NORTHERN TERRITORYVERSION 38)

(Page xxviii)

Introduction1Preliminary3References to the Rules3Italicised expressions3[Deleted]3Background3Nomenclature of and references to provisions of a Chapter3Introduction3Parts, Divisions and Subdivisions3Rules, clauses, paragraphs, subparagraphs and other items4Effect of renumbering of provisions of the Rules4[Deleted]5[Deleted]5Interpretation5General51.7.1AInconsistency with National Measurement Act61.7.1BInstruments6Notices7Service of notices under the Rules7Time of service7Counting of days8Reference to addressee8Retention of Records and Documents8ANTESMO’s costs in connection with these Rules8[Deleted]8AEMO Rule Funds8Registered Participants and Registration112A.Regional Structures15Market Rules19Power System Security234A.Retailer Reliability Obligation27Part AIntroduction294A.ADefinitions294A.A.1Definitions294A.A.2Forecast reliability gap materiality324A.A.3One-in-two year peak demand forecast324A.A.4Peak demand32Part BReliability Forecasts334A.B.1Reliability forecast334A.B.2Reliability forecast components334A.B.3Supporting materials344A.B.4Reliability Forecast Guidelines344A.B.5AER Forecasting Best Practice Guidelines35Part CReliability Instruments36Division 1AEMO request for a reliability instrument364A.C.1AEMO request for a reliability instrument364A.C.2AEMO request for a T-3 reliability instrument364A.C.3AEMO request for a T-1 reliability instrument374A.C.4Related T-3 reliability instrument374A.C.5Notification of a closed forecast reliability gap at T-1374A.C.6Corrections to a request384A.C.7Withdrawing a request38Division 2AER making of a reliability instrument384A.C.8AER making of a reliability instrument384A.C.9When a decision by the AER must be made384A.C.10T-1 reliability instrument components394A.C.11AER decision making criteria394A.C.12Reliability Instrument Guidelines39Part DLiable Entities404A.D.1Application404A.D.2Liable entities404A.D.3New entrants414A.D.4Application to register as large opt-in customer414A.D.5Application to register as prescribed opt-in customer424A.D.6Thresholds434A.D.7Opt-in cut-off day434A.D.8AER approval of applications434A.D.9AER opt-in register444A.D.10Changes to register444A.D.11AER register taken to be correct454A.D.12AEMO Opt-In Procedures454A.D.13AER Opt-In Guidelines45Part EQualifying Contracts and Net Contract Position46Division 1Key concepts464A.E.1Qualifying contracts464A.E.2Net contract position47Division 2Firmness methodologies484A.E.3Firmness methodology484A.E.4Types of methodologies484A.E.5Approval of a bespoke firmness methodology49Division 3Reporting net contract position494A.E.6Reporting requirements49Division 4Adjustment of net contract position504A.E.7Adjustment of net contract position50Division 5Contracts and Firmness Guidelines524A.E.8Contracts and Firmness Guidelines52Part FCompliance with the Retailer Reliability Obligation52Division 1Application524A.F.1Application52Division 2Key concepts534A.F.2Compliance TI534A.F.3Share of one-in-two year peak demand forecast53Division 3AEMO notifications to AER554A.F.4AEMO notification of compliance trading intervals554A.F.5AEMO compliance report55Division 4AER assessment of compliance554A.F.6Reliability Compliance Procedures and Guidelines554A.F.7AER assessment554A.F.8AER notification to AEMO for PoLR costs56Division 5Miscellaneous564A.F.9Demand response information564A.F.10PoLR cost procedures57Part GMarket Liquidity Obligation57Division 1Preliminary574A.G.1Overview of Part G574A.G.2Purpose and application58Division 2Market Generators and trading right holders584A.G.3Market Generators and generator capacity584A.G.4Trading rights and trading right holders58Division 3Trading groups594A.G.5Trading group594A.G.6Controlling entity59Division 4Traced capacity and trading group capacity614A.G.7Traced capacity614A.G.8Tracing capacity to trading groups614A.G.9Trading group capacity62Division 5MLO generators and MLO groups624A.G.10MLO group624A.G.11MLO generator62Division 6Market Generator information624A.G.12MLO register624A.G.13Market Generator information644A.G.14Applications to the AER65Division 7Liquidity period664A.G.15Notices prior to a liquidity period664A.G.16Duration of liquidity period66Division 8Liquidity obligation674A.G.17Liquidity obligation674A.G.18Performing a liquidity obligation674A.G.19Volume limits684A.G.20Appointment of MLO nominee694A.G.21Exemptions70Division 9MLO products and MLO exchange714A.G.22MLO products714A.G.23MLO exchange71Division 10Miscellaneous724A.G.24MLO compliance and reporting724A.G.25MLO Guidelines72Part HVoluntary Book Build734A.H.1Purpose and application734A.H.2Book Build Procedures734A.H.3Commencement of voluntary book build744A.H.4Participation in the voluntary book build754A.H.5Book build fees754A.H.6Reporting75Network Connection Access, Planning and Expansion77Part AIntroduction79Introduction to Chapter 579Structure of this Chapter79Overview of Part B and connection and access under the Rules79Definitions82Part BNetwork Connection and Access835.1AIntroduction to Part B835.1A.1Purpose and Application835.1A.2Principles85A.3Dedicated connection asset service providers86Obligations86Obligations of Registered Participants86Connection agreements87Obligations of network service providers88AObligations of Market Network Service Providers93Obligations of customers94Obligations of Generators95Obligations of AEMO97AAEMO review of technical requirements for connection97Obligations of Dedicated Connection Asset Service Providers985.2ATransmission network connection and access995.2A.1Application995.2A.2Relevant assets995.2A.3Connection and access to transmission services1005.2A.4Transmission services related to connection1015.2A.5Publication and provision of information1055.2A.6Negotiating principles1055.2A.7Third party IUSAs106A.8Access framework for large dedicated connection assets107Establishing or Modifying Connection109Process and procedures109AApplication of rule to connection of embedded generating units110Connection enquiry110Response to connection enquiry112Application for connection1165.3.4ANegotiated access standards117BSystem strength remediation for new connections121Preparation of offer to connect124Offer to connect125Finalisation of connection agreements and network operatingagreements128Provision and use of information130Procedure to be followed by a Generator proposing to alter a generating system132Acceptance of performance standards for generating plant that is altered 134Notification of request to change normal voltage1345.3AEstablishing or modifying connection - embedded generation1355.3A.1Application of rule 5.3A1355.3A.2Definitions and miscellaneous1355.3A.3Publication of Information1365.3A.4Fees1385.3A.5Enquiry1395.3A.6Response to Enquiry1405.3A.7Preliminary Response to Enquiry1405.3A.8Detailed Response to Enquiry1415.3A.9Application for connection1425.3A.10Preparation of offer to connect1435.3A.11Technical Dispute1445.3A.12Network support payments and functions1445.3AAAccess arrangements relating to Distribution Networks145BApplication for connection to declared shared network148Independent Engineer149Application149Establishment of a pool149Initiating the Independent Engineer process150Referral to the Adviser150Proceedings and decisions of the Independent Engineer151Costs of the Independent Engineer1525.4A[Deleted]152AA[Deleted]152Commercial arbitration for prescribed and negotiated transmission services and large DCA services152Application152Notification of dispute153Appointment of commercial arbitrator153Procedures of commercial arbitrator154Powers of commercial arbitrator in determining disputes154Determination of disputes156Costs of dispute157Enforcement of agreement or determination and requirement for reasons157 5.5.9Miscellaneous157A[Deleted]158Part CPost-Connection Agreement matters158Design of Connected Equipment158Application158Advice of inconsistencies158Additional information159Advice on possible non-compliance159A[Deleted]159Inspection and Testing159Right of entry and inspection159Right of testing161Tests to demonstrate compliance with connection requirements for generators163ATests to demonstrate compliance with system strength remediationschemes165Routine testing of protection equipment166Testing by Registered Participants of their own plant requiring changes to normal operation168Tests of generating units requiring changes to normal operation170Inter-network power system tests171Contestable IUSA components177Commissioning177Requirement to inspect and test equipment177Co-ordination during commissioning178Control and protection settings for equipment178Commissioning program179Commissioning tests179Disconnection and Reconnection180Voluntary disconnection180Decommissioning procedures181Involuntary disconnection181Direction to disconnect182ANotification of disconnection183Disconnection during an emergency183Obligation to reconnect183Part DNetwork Planning and Expansion184Network development generally184Content of Part D184Definitions185Interpretation189Forecasts of connection to transmission network and identification of system limitations189Forecasts for connection to transmission network189Identification of network limitations190Transmission annual planning process190Transmission annual planning review190Transmission Annual Planning Report191Distribution annual planning process195Distribution annual planning review195Distribution Annual Planning Report197Distribution system limitation template197ADistribution zone substation information198Joint planning201Joint planning obligations of Transmission Network Service Providers and Distribution Network Service Providers201Joint planning obligations of Distribution Network Service Providers and Distribution Network Service Providers202Joint planning obligations of Transmission Network Service Providers2035.14AJoint planning in relation to retirement or de-ratings of network assets forming part of the Declared Shared Network2035.14BTAPR Guidelines203B.1Development of TAPR Guidelines203Regulatory investment tests generally204Interested parties204Identification of a credible option204Review of costs thresholds205Costs determinations207Regulatory investment test for transmission207Principles207Regulatory investment test for transmission application guidelines210Investments subject to the regulatory investment test for transmission212Regulatory investment test for transmission procedures214Disputes in relation to application of regulatory investment test for transmission220Determination that preferred option satisfies the regulatory investment test for transmission222Regulatory investment test for distribution223Principles223Regulatory investment test for distribution application guidelines225Projects subject to the regulatory investment test for distribution227Regulatory investment test for distribution procedures228Disputes in relation to application of regulatory investment test for distribution233Construction of funded augmentations2355.18AGenerator connections2365.18A.1Definitions2365.18A.2Register of generator connections2365.18A.3Impact assessment of large generator connections2375.18BCompleted embedded generation projects2385.18B.1Definitions238B.2Register of completed embedded generation projects238SENE Design and Costing Study239Definitions239Interpretation240Request for SENE Design and Costing Study240Content of SENE Design and Costing Study241Co-operation of other Network Service Providers242Publication of SENE Design and Costing Study report242Provision and use of information242National transmission planning243Preliminary consultation243Publication of NTNDP244Development strategies for national transmission flow paths246NTNDP database247Jurisdictional planning bodies and jurisdictional planningrepresentatives248NTP Functions248Inertia and system strength requirements methodologies2485.20AFrequency management planning2495.20A.1Power system frequency risk review2495.20A.2Power system frequency risk review process2515.20A.3Power system frequency risk review report2515.20A.4Request for protected event declaration2515.20A.5Request to revoke a protected event declaration2525.20BInertia sub-networks and requirements2535.20B.1Boundaries of inertia sub-networks2535.20B.2Inertia requirements2535.20B.3Inertia shortfalls2545.20B.4Inertia Service Provider to make available inertia services2555.20B.5Inertia support activities2575.20B.6Inertia network services information and approvals2585.20CSystem strength requirements2605.20C.1System strength requirements2605.20C.2Fault level shortfalls2615.20C.3System Strength Service Provider to make available system strength services262C.4System strength services information and approvals263AEMO's obligation to publish information and guidelines and provide advice265Last resort planning power267Schedule 5.1aSystem standards270S5.1a.1Purpose270S5.1a.2Frequency270S5.1a.3System stability270S5.1a.4Power frequency voltage271S5.1a.5Voltage fluctuations272S5.1a.6Voltage waveform distortion272S5.1a.7Voltage unbalance273S5.1a.8Fault clearance times273Schedule 5.1Network Performance Requirements to be Provided or Co-ordinated by Network Service Providers275S5.1.1Introduction275S5.1.2Network reliability276S5.1.2.1Credible contingency events276S5.1.2.2Network service within a region277S5.1.2.3Network service between regions278S5.1.3Frequency variations278S5.1.4Magnitude of power frequency voltage278S5.1.5Voltage fluctuations279S5.1.6Voltage harmonic or voltage notching distortion280S5.1.7Voltage unbalance281S5.1.8Stability282S5.1.9Protection systems and fault clearance times283S5.1.10Load, generation and network control facilities286S5.1.10.1General286S5.1.10.1aEmergency frequency control schemes287S5.1.10.2Distribution Network Service Providers288S5.1.10.3Transmission Network Service Providers288S5.1.11Automatic reclosure of transmission or distribution lines289S5.1.12Rating of transmission lines and equipment289S5.1.13Information to be provided290Schedule 5.2Conditions for Connection of Generators290S5.2.1Outline of requirements290S5.2.2Application of Settings291S5.2.3Technical matters to be coordinated292S5.2.4Provision of information292S5.2.5Technical requirements295S5.2.5.1Reactive power capability295S5.2.5.2Quality of electricity generated297S5.2.5.3Generating system response to frequency disturbances297S5.2.5.4Generating system response to voltage disturbances300S5.2.5.5Generating system response to disturbances following contingencyevents302S5.2.5.6Quality of electricity generated and continuous uninterrupted operation .310 S5.2.5.7Partial load rejection310S5.2.5.8Protection of generating systems from power system disturbances311S5.2.5.9Protection systems that impact on power system security313S5.2.5.10Protection to trip plant for unstable operation314S5.2.5.11Frequency control315S5.2.5.12Impact on network capability318S5.2.5.13Voltage and reactive power control319S5.2.5.14Active power control326S5.2.6Monitoring and control requirements328S5.2.6.1Remote Monitoring328S5.2.6.2Communications equipment330S5.2.7Power station auxiliary supplies331S5.2.8Fault current331Schedule 5.3Conditions for Connection of Customers333S5.3.1aIntroduction to the schedule333S5.3.1Information334S5.3.2Design standards336S5.3.3Protection systems and settings336S5.3.4Settings of protection and control systems337S5.3.5Power factor requirements338S5.3.6Balancing of load currents339S5.3.7Voltage fluctuations339S5.3.8Harmonics and voltage notching340S5.3.9Design requirements for Network Users' substations340S5.3.10Load shedding facilities341Schedule 5.3aConditions for connection of Market Network Services341S5.3a.1aIntroduction to the schedule341S5.3a.1Provision of Information342S5.3a.2Application of settings344S5.3a.3Technical matters to be co-ordinated345S5.3a.4Monitoring and control requirements345S5.3a.4.1Remote Monitoring345S5.3a.4.2[Deleted]346S5.3a.4.3Communications equipment346S5.3a.5Design standards347S5.3a.6Protection systems and settings347S5.3a.7[Deleted]348S5.3a.8Reactive power capability348S5.3a.9Balancing of load currents349S5.3a.10Voltage fluctuations349S5.3a.11Harmonics and voltage notching350S5.3a.12Design requirements for Market Network Service Providers' substations 350 S5.3a.13Market network service response to disturbances in the power system351S5.3a.14Protection of market network services from power system disturbances 351Schedule 5.4Information to be Provided with Preliminary Enquiry352Schedule 5.4APreliminary Response352Schedule 5.4BDetailed Response to Enquiry355Schedule 5.5Technical Details to Support Application for Connection and Connection Agreement357S5.5.1Introduction to the schedule357S5.5.2Categories of data357S5.5.3Review, change and supply of data358S5.5.4Data Requirements358S5.5.5Asynchronous generating unit data359S5.5.6Generating units smaller than 30MW data359S5.5.7Power System Design Data Sheet, Power System Setting Data Sheet and Power System Model Guidelines360Schedule 5.5.1[Deleted]362Schedule 5.5.2[Deleted]362Schedule 5.5.3Network and plant technical data of equipment at or near connectionpoint362Schedule 5.5.4Network Plant and Apparatus Setting Data366Schedule 5.5.5Load Characteristics at Connection Point368Schedule 5.6Terms and Conditions of Connection agreements and network operating agreements369Part AConnection agreements369Part BNetwork Operating Agreements370Schedule 5.7Annual Forecast Information for Planning Purposes371Schedule 5.8Distribution Annual Planning Report373Schedule 5.9Demand side engagement document (clause 5.13.1(h))379Schedule 5.10Information requirements for Primary Transmission Network Service Providers (clause 5.2A.5)380Schedule 5.11Negotiating principles for negotiated transmission services (clause 5.2A.6)384Schedule 5.12Negotiating principles for large DCA services3865A.Electricity connection for retail customers389Part APreliminary3915A.A.1Definitions3915A.A.2Application of this Chapter3945A.A.3Small Generation Aggregator deemed to be agent of a retail customer395Part BStandardised offers to provide basic and standard connectionservices395Division 1Basic connection services3955A.B.1Obligation to have model standing offer to provide basic connection services3955A.B.2Proposed model standing offer for basic connection services3955A.B.3Approval of terms and conditions of model standing offer to provide basic connection services396Division 2Standard connection services3975A.B.4Standard connection services3975A.B.5Approval of model standing offer to provide standard connection services398Division 3Miscellaneous3995A.B.6Amendment etc of model standing offer3995A.B.7Publication of model standing offers400Part CNegotiated connection4005A.C.1Negotiation of connection4005A.C.2Process of negotiation4015A.C.3Negotiation framework4015A.C.4Fee to cover cost of negotiation403Part DApplication for connection service403Division 1Information4035A.D.1Publication of information4035A.D.1ARegister of completed embedded generation projects404Division 2Preliminary enquiry4055A.D.2Preliminary enquiry405Division 3Applications4065A.D.3Application process4065A.D.4Site inspection407Part EConnection charges4075A.E.1Connection charge principles4075A.E.2Itemised statement of connection charges4085A.E.3Connection charge guidelines4095A.E.4Payment of connection charges411Part FFormation and integration of connection contracts412Division 1Offer and acceptance – basic and standard connection services4125A.F.1Distribution Network Service Provider's response to application4125A.F.2Acceptance of connection offer4125A.F.3Offer and acceptance—application for expedited connection412Division 2Offer and acceptance – negotiated connection4135A.F.4Negotiated connection offer413Division 3Formation of contract4135A.F.5Acceptance of connection offer414Division 4Contractual performance4145A.F.6Carrying out connection work4145A.F.7Retailer required for energisation where new connection414Part GDispute resolution between Distribution Network Service Providers and customers4145A.G.1Relevant disputes4145A.G.2Determination of dispute4155A.G.3Termination of proceedings415SCHEDULE 5A.1 – Minimum content requirements for connection contract416Part AConnection offer not involving embedded generation416Part BConnection offer involving embedded generation417Economic Regulation of Distribution Services419Part AIntroduction4216.0Operation of Chapter 6 in this jurisdiction421AInterpretation421Introduction to Chapter 6422AER's regulatory responsibility422A[Deleted]422Structure of this Chapter422Access to direct control services and negotiated distribution services423Prohibition of DUOS charges for the export of energy424Part BClassification of Distribution Services and DistributionDeterminations424Classification424Classification of distribution services424Classification of direct control services as standard control services or alternative control services425Term for which classification operates425ADistribution Service Classification Guidelines426Duty of AER to make distribution determinations426Control mechanisms for direct control services427Basis of control mechanisms for direct control services428Negotiated distribution services428Guidelines428Part CBuilding Block Determinations for standard control services429Building block determinations429Introduction429Contents of building block determination430Post-tax revenue model430Preparation, publication and amendment of post-tax revenue model430Contents of post-tax revenue model431Building block approach431Shared assets433Expenditure Forecast Assessment Guidelines4346.4ACapital expenditure incentive mechanisms4356.4BAsset exemptions4366.4B.1Asset exemption decisions and Asset Exemption Guidelines436B.2Exemption applications437Matters relevant to the making of building block determinations437Regulatory asset base437Return on capital438Estimated cost of corporate income tax439[Deleted]439Depreciation439Forecast operating expenditure440Forecast capital expenditure442Efficiency benefit sharing scheme446ACapital expenditure sharing scheme448The X factor449Pass through events450Adjustments after making of building block determination.450Cost pass through4506.6.1AACost pass through – deemed determinations4576.6.1ABCost pass through – NT events458AReporting on jurisdictional schemes463Service target performance incentive scheme464Demand management incentive scheme465ADemand management innovation allowance mechanism466Small-scale incentive scheme467Reopening of distribution determination for capital expenditure4686.6AContingent Projects4726.6A.1Acceptance of a contingent project in a distribution determination472A.2Amendment of distribution determination for contingent project474Part DNegotiated distribution services478Negotiated distribution services478Principles relating to access to negotiated distribution services478Determination of terms and conditions of access for negotiated distribution services480Negotiating framework determination481Negotiated Distribution Service Criteria determination481Preparation of and requirements for negotiating framework for negotiated distribution services481Confidential information483Part DAConnection policies4846.7AConnection policy requirements484A.1Preparation of, and requirements for, connection policy484Part ERegulatory proposal and proposed tariff structure statement485Regulatory proposal and proposed tariff structure statement485AER's framework and approach paper485ANotification of approach to forecasting expenditure487Submission of regulatory proposal, tariff structure statement and exemption application487Preliminary examination and consultation490Preliminary examination490Resubmission of proposal490AConfidential information490Consultation491Draft distribution determination and further consultation492Making of draft distribution determination492Publication of draft determination and consultation492Submission of revised proposal493Submissions on specified matters494Distribution determination494Making of distribution determination494AOut of scope revised regulatory proposal or late submissions495Notice of distribution determination495Commencement of distribution determination496Requirements relating to draft and final distribution determinations496Constituent decisions496Reasons for decisions500Extent of AER's discretion in making distribution determinations500Revocation and substitution of distribution determination for wrong information or error502Miscellaneous502ADistribution Confidentiality Guidelines503Part FCost Allocation504Cost allocation504Duty to comply with Cost Allocation Method504Cost Allocation Principles504Cost Allocation Guidelines505Cost Allocation Method505Part GDistribution consultation procedures507Distribution consultation procedures507Part HRing-Fencing Arrangements for Distribution Network Service Providers508Distribution Ring-Fencing Guidelines508Compliance with Distribution Ring-Fencing Guidelines508BApplication of Distribution Ring-Fencing Guidelines in this jurisdiction.508Development of Distribution Ring-Fencing Guidelines509Part IDistribution Pricing Rules510Distribution Pricing Rules510Application of this Part5106.18.1ATariff structure statement5106.18.1BAmending a tariff structure statement with the AER's approval511CSub-threshold tariffs512Pricing proposals513Tariff classes514Principles governing assignment or re-assignment of retail customers to tariff classes and assessment and review of basis of charging515Pricing principles515Side constraints on tariffs for standard control services517Recovery of designated pricing proposal charges518ARecovery of jurisdictional scheme amounts518Approval of pricing proposal522Publication of information about tariffs and tariff classes523Data Required for Distribution Service Pricing524Forecast use of networks by Distribution Customers and Embedded Generators524Confidentiality of distribution network pricing information524Part JBilling and Settlements524Billing and Settlements Process524Billing for distribution services524Minimum information to be provided in distribution network servicebills526Settlement between Distribution Network Service Providers527Obligation to pay527Part KPrudential requirements, capital contributions and prepayments527Distribution Network Service Provider Prudential Requirements527Prudential requirements for distribution network service527Capital contributions, prepayments and financial guarantees528Treatment of past prepayments and capital contributions528Part LDispute resolution528Dispute Resolution528Dispute Resolution by the AER528Determination of dispute529Termination of access dispute without access determination530Part MSeparate disclosure of transmission and distribution charges531Separate disclosure of transmission and distribution charges531Part NDual Function Assets532Dual Function Assets532Application of this Part532Dual Function Assets532AER determination of applicable pricing regime for Dual Function Assets532Division of Distribution Network Service Provider's revenue533Part OAnnual Benchmarking Report535Annual Benchmarking Report535Part PDistribution Reliability Measures Guidelines535Distribution Reliability Measures Guidelines535Schedule 6.1Contents of building block proposals535S6.1.1Information and matters relating to capital expenditure535S6.1.2Information and matters relating to operating expenditure537S6.1.3Additional information and matters539Schedule 6.2Regulatory Asset Base541S6.2.1Establishment of opening regulatory asset base for a regulatory control period541S6.2.2Prudency and efficiency of capital expenditure546S6.2.2AReduction for inefficient past capital expenditure547S6.2.2BDepreciation549S6.2.3Roll forward of regulatory asset base within the same regulatory control period549S6.2.3AEstablishment of opening regulatory asset base for distribution system in this jurisdiction for 1st regulatory control period5506A.Economic Regulation of Transmission Services5556B.Retail Markets559Metering5637A.Metering567Part AIntroduction5697A.1Introduction to the Metering Chapter5697A.1.1Purpose and application5697A.1.2Contents5697A.1.3Definitions5697A.1.4Inconsistency570Part BRoles and Responsibilities5717A.2Role and responsibility of financially responsible participant5717A.3Role and responsibility of Metering Coordinator5717A.3.1Responsibility of the Metering Coordinator5717A.3.2Role of the Metering Coordinator5727A.4Qualification and requirements of Metering Providers and Metering Data Providers5747A.4.1Qualification and requirements of Metering Providers5747A.4.2Qualification and requirements of Metering Data Providers575Part CAppointment of Metering Coordinator5757A.5Appointment of Metering Coordinator575Part DMetering installation5767A.6Metering installation arrangement5767A.6.1Metering installation requirements5767A.6.2Metering installation components5767A.6.3Emergency management5797A.6.4Network devices5797A.6.5Metering point5807A.6.6Metering installation types and accuracy5807A.6.7Functionality requirements for type 1, 2, 3 and 4 metering installations5817A.6.8Meter churn5817A.6.9Metering installation malfunctions5817A.6.10Timeframes for meters to be installed – new connection5827A.6.11Timeframes for meters to be installed – where a connection service is not required5837A.6.12Timeframes for meters to be installed – where a connection alteration is required5847A.6.13Changing a metering installation5857A.6.14Prepayment metering5867A.7Maintenance, inspection, testing and auditing of metering installations5867A.7.1Maintenance5867A.7.2Responsibility for inspection and testing5867A.7.3Actions in event of non-compliance5887A.7.4Audits of information held in metering installations5887A.7.5Appointment of external auditor5897A.7.6Errors found in metering tests, inspections or audits5907A.7.7Retention of test records and documents590Part EMetering data5917A.8Metering data services5917A.8.1Metering data services5917A.8.2Collection of energy data and estimation of metering data5927A.8.3Data management and storage5937A.8.4Provision of metering data to certain persons5947A.8.5Use of check metering data5957A.8.6Periodic energy metering5957A.8.7Verification of metering data Metering installations other than type 7 metering installations5967A.8.8Time settings5977A.8.9Metering data performance standards5977A.9Metering data and data base5997A.9.1Metering database5997A.9.2Data validation, substitution and estimation6007A.9.3Changes to energy data or to metering data6007A.10Register of metering information6017A.10.1Metering register6017A.10.2Metering installation registration process6017A.10.3Metering register discrepancy6017A.11Disclosure of information6027A.11.1Provision of data to retailers6027A.12Metering data provision to retail customers603Part FSecurity of metering installations and energy data6037A.13Security of metering installations, energy data and metering data6037A.13.1Confidentiality of data6037A.13.2Security of metering installations6037A.13.3Security controls for energy data6047A.13.4Additional security controls for type 4 metering installations6057A.13.5Access to data606Schedule 7A.1Metering register608S7A.1.1General608S7A.1.2Metering register information608S7A.1.3Communication guideline608Schedule 7A.2Metering provider608Schedule 7A.3Metering data provider609Schedule 7A.4Types and accuracy of metering installations609S7A.4.1General requirements609S7A.4.2Accuracy requirements for metering installations609S7A.4.3Check metering613S7A.4.4Resolution and accuracy of displayed or captured data614S7A.4.5General design standards614S7A.4.5.1Design requirements614S7A.4.5.2Design guidelines615Schedule 7A.5Metering functionality requirements for type 1, 2, 3 and 4 metering requirements616S7A.5.1Introduction616S7A.5.1.1Purpose616S7A.5.1.2Definitions616S7A.5.2Functionality Requirements for Meters in Type 1, 2, and 3 metering installations616S7A.5.2.1Application616S7A.5.2.2Applicable meter configurations616S7A.5.2.3Metrology617S7A.5.3Functionality Requirements for Meters in Type 4 metering installations .617 S7A.5.3.1Application617S7A.5.3.2Applicable meter configurations617S7A.5.3.3Metrology617S7A.5.3.4Remote and local reading of meters618S7A.5.3.5Supply disconnection and reconnection618S7A.5.3.5.1General requirements618S7A.5.3.5.2Disconnection619S7A.5.3.5.3Reconnection619S7A.5.3.6Time clock synchronisation620S7A.5.3.7Quality of Supply and other event recording620S7A.5.3.8Tamper detection621S7A.5.3.9Communications and data security621S7A.5.3.10Remote firmware upgrades621S7A.5.3.11Remote arming621Schedule 7A.6Inspection and testing requirements621S7A.6.1General621S7A.6.2Technical guidelines623Schedule 7A.7Metrology procedure624Part A624S7A.7.1Introduction624S7A.7.1.1General624S7A.7.1.2Definitions624S7A.7.1.3Relevant retailer625Part B625S7A.7.2Purpose and scope625S7A.7.2.1Purpose625S7A.7.2.2Scope625S7A.7.3Metering provision626S7A.7.3.1Responsibility for metering provision626S7A.7.3.2Metering installation components626S7A.7.3.3Use of optical ports and pulse outputs627S7A.7.3.4Load control equipment627S7A.7.3.5Data storage requirements for meters628S7A.7.3.6Metering installation clock628S7A.7.3.7Interval meters628S7A.7.3.8Alarm settings628S7A.7.3.9Summation metering629S7A.7.3.10629S7A.7.3.11Routine testing and inspection of metering installations629S7A.7.3.12Requests for testing type 1 – 6 metering installations630S7A.7.4Installation of meters and de-commissioning631S7A.7.4.1General installation requirements631S7A.7.4.2Type 4A, 5 and 6 metering installations631S7A.7.4.3Preliminary de-commissioning and removal of metering equipment requirements631S7A.7.4.4631S7A.7.5631S7A.7.6Responsibility for metering data services632S7A.7.6.1Metering data storage632S7A.7.6.2Verification of metering data for type 4, 4A, 5, 6 and 7 installations632S7A.7.6.3Metering installation type 7 – sample testing632S7A.7.6.4Request for text of calculated metering data634S7A.7.6.5NTESMO's metering data substitution obligations635Part C635S7A.7.7Purpose and scope635S7A.7.7.1Purpose635S7A.7.7.2Scope635S7A.7.8Principles for validation, substitution and estimation635S7A.7.8.1General validation, substitution and estimation requirements635S7A.7.8.2Substitution requirements635S7A.7.8.3Estimation requirement636S7A.7.8.4Metering data quality flags637S7A.7.8.5Final substitution637S7A.7.9Substitution for acquisition of metering data from remotely read metering installations638S7A.7.9.1Application of S7A.7.9638S7A.7.9.2Substitution rules638S7A.7.9.3Substitution types640S7A.7.10Substitution and estimation for manually read interval metering installations643S7A.7.10.1Application of S7A7.10643S7A.7.10.2Substitution and estimation rules643S7A.7.10.3Substitution and estimation types644S7A.7.11Substitution and estimation for metering installations with accumulated metering data646S7A.7.11.1Substitution and estimation rules646S7A.7.11.2Substitution and estimation types648S7A.7.12Substitution and estimation for calculated metering data649S7A.7.12.1Substitution rules649S7A.7.12.2Substitution and estimation types650S7A.7.13Data validation requirements650S7A.7.13.1Validation requirements for all metering installations650S7A.7.13.2Validation of interval metering data alarms651S7A.7.13.3Validation within the meter reading process for manually read metering installations651S7A.7.13.4Validation as part of the registration process652S7A.7.13.5Validation of metering data653S7A.7.14Determination of metering data for unmetered loads659S7A.7.14.1Load table659S7A.7.14.2Controlled unmetered devices660S7A.7.14.3Uncontrolled unmetered devices664Schedule 7A.8Service level procedures665Part AIntroduction665S7A.8.1Introduction665S7A.8.1.1Purpose and scope665S7A.8.1.2Definitions666Part BMetering provider services666S7A.8.2Introduction666S7A.8.2.1Purpose and exclusions666S7A.8.2.2Services666S7A.8.3General requirements667S7A.8.3.1Metering Provider capability and competency667S7A.8.3.2Use of contractors667S7A.8.3.3Insurance668S7A.8.4Device management and test equipment668S7A.8.4.1Procurement668S7A.8.4.2Storage, handling and transport668S7A.8.4.3Management of test equipment669S7A.8.4.4Management of meter programming and authorised software669S7A.8.5Installation and commissioning requirements669S7A.8.5.1General commissioning requirements669S7A.8.5.2Metering data validation requirements670S7A.8.6Metering installation maintenance671S7A.8.6.1Test plans671S7A.8.6.2Management of metering installation malfunctions671S7A.8.6.3Telecommunications672S7A.8.6.4Non-conforming test results or calibrations672S7A.8.7Systems and administration672S7A.8.7.1Register of metering installations672S7A.8.7.2Disaster recovery673S7A.8.7.3Audits undertaken by the Utilities Commission673Part CMetering Data Provider services674S7A.8.8Introduction674S7A.8.8.1Purpose674S7A.8.8.2Obligations674S7A.8.9Service requirements677S7A.8.9.1System requirements677S7A.8.9.2Metering data services database677S7A.8.9.3Exception reports678S7A.8.9.4Collection process requirements678S7A.8.9.5Specific collection process requirements for remotely read metering installations679S7A.8.9.6Specific collection process requirements for manually read metering installations679S7A.8.9.7Metering data processing requirements679S7A.8.9.8Specific metering data processing requirements for type 1, 2, 3 and 4metering installations680S7A.8.9.9Specific metering data processing requirements for type 7 metering installations681S7A.8.9.10Specific metering data estimation requirements for manually read and type 7 metering installations681S7A.8.9.11Delivery performance requirements for metering data682S7A.8.10Data management following the alteration of type of metering installation at a connection point683S7A.8.10.1Meter churn scenarios683S7A.8.10.2Scenario 1684S7A.8.10.3Scenario 2684S7A.8.10.4Scenario 3685S7A.8.10.5Scenario 4685S7A.8.11System architecture and administration686S7A.8.11.1Metering data archival and recovery686S7A.8.11.2Data backup686S7A.8.11.3Disaster recovery686S7A.8.11.4System administration and data management688S7A.8.12Quality control688S7A.8.12.1Audits688S7A.8.12.2Corrective action688S7A.8.13.1Administration689S7A.8.13.2Quality systems689Administrative Functions691Part AIntroductory693Administrative functions693[Deleted]693[Deleted]693Structure of this Chapter693Part BDisputes693Part CRegistered Participants' confidentiality obligations694Confidentiality694Confidentiality694AApplication695Exceptions695Conditions697[Deleted]697Indemnity to AER, AEMC and AEMO697AEMO information697Information on Rules Bodies697Part DMonitoring and reporting698Monitoring and Reporting698Monitoring698Reporting requirements and monitoring standards for Registered Participants698Consultation required for making general regulatory information order (Section 28H of the NEL)700Preparation of network service provider performance report (Section 28V of the NEL)701[Deleted]702Recovery of reporting costs702Part EReliability panel702Reliability Panel702Purpose of Reliability Panel702Constitution of the Reliability Panel704Reliability Panel review process706Determination of protected events708Part FRules consultation procedures710Rules Consultation Procedures710Part GConsumer advocacy funding712Consumer advocacy funding obligation712Part HAugmentations713Augmentations713Application713Object713Definitions713Planning criteria714Construction of augmentation that is not a contestable augmentation714Contestable augmentations715Construction and operation of contestable augmentation715Funded augmentations that are not subject to the tender process717Contractual requirements and principles718Annual planning review718Schedule 8.11Principles to be reflected in agreements relating to contestable augmentations719S8.11.1Risk allocation719S8.11.2Minimum requirements for agreements relating to contestable augmentation720S8.11.3Matters to be dealt with in relevant agreements720Part IValues of customer reliability721Development of methodology and publication of values of customer reliability7218A.Participant Derogations725Part 1Derogations Granted to TransGrid7278A.1[Deleted]727Part 2Derogations Granted to EnergyAustralia7278A.2[Deleted]7278A.2A[Deleted]727Part 3[Deleted]727Part 4[Deleted]727Part 5[Deleted]727Part 6Derogations Granted to Victorian Market Participants727Part 7[Deleted]728Part 8[Deleted]728Part 9[Deleted]728Part 10[Deleted]728Part 11[Deleted]728Part 12[Deleted]728Part 13Derogation granted to Aurora Energy (Tamar Valley) Pty Ltd7288A.13[Deleted]728Part 14Derogations granted to Ausgrid, Endeavour Energy and Essential Energy7288A.14Derogations from Chapter 6 for the current regulatory control period and subsequent regulatory control period7288A.14.1Definitions7288A.14.2Expiry date7328A.14.3Application of Rule 8A.147328A.14.4Recovery of revenue across the current regulatory control period and subsequent regulatory control period7338A.14.5Recovery of revenue in subsequent regulatory control period only and no reopening of subsequent distribution determination required7348A.14.6Recovery of revenue in subsequent regulatory control period only and reopening of distribution determination is required7358A.14.7Requirements for adjustment determination7378A.14.8Application of Chapter 6 under participant derogation737Part 15Derogations granted to ActewAGL7398A.15Derogations from Chapter 6 for the current regulatory control period and subsequent regulatory control period7398A.15.1Definitions7398A.15.2Expiry date7428A.15.3Application of Rule 8A.157428A.15.4Recovery of revenue across the current regulatory control period and subsequent regulatory control period7438A.15.5Recovery of revenue in subsequent regulatory control period only and no reopening of subsequent distribution determination required7458A.15.6Recovery of revenue in subsequent regulatory control period only and reopening of distribution determination is required7468A.15.7Requirements for adjustment determination7488A.15.8Application of Chapter 6 under participant derogation748Jurisdictional Derogations and TransitionalArrangements751Purpose and Application753Purpose753Jurisdictional Derogations753Part AJurisdictional Derogations for Victoria753[Deleted]753Definitions753General Definitions753[Deleted]755AFault levels755Transitional Arrangements for Chapter 2 - Registered Participants, Registration and Cross Border Networks755[Deleted]755Smelter Trader755Smelter Trader: compliance756Report from AER759Cross Border Networks759[Deleted]760Transitional Arrangements for Chapter 4 - System Security760Operating Procedures (clause 4.10.1)760Nomenclature Standards (clause 4.12)760Transitional Arrangements for Chapter 5 - Network Connection760[Deleted]760[Deleted]760[Deleted]760Regulation of Distribution Network Connection760[Deleted]761[Deleted]761[Deleted]761Transitional Arrangements for Chapter 6 - Network Pricing761[Deleted]761[Deleted]761[Deleted]761Transmission Network Pricing7619.8.4A[Deleted]7639.8.4B[Deleted]7639.8.4C[Deleted]7639.8.4D[Deleted]7639.8.4E[Deleted]7639.8.4F[Deleted]763G[Deleted]763[Deleted]763[Deleted]763Distribution network pricing – transitional application of former Chapter6 .................................................................................................................763Exclusion of AER's power to aggregate distribution systems and parts of distribution systems764Transitional Arrangements for Chapter 7 - Metering764Metering Installations To Which This Schedule Applies764[Deleted]765[Deleted]765[Deleted]765[Deleted]765[Deleted]765[Deleted]765[Deleted]765Periodic Energy Metering (clause 7.9.3)765Use of Alternate Technologies (clause 7.13)7659.9A[Deleted]7669.9B[Deleted]766C[Deleted]766Schedule 9A1.1 [Deleted]766Schedule 9A1.2 [Deleted]766Schedule 9A1.3 [Deleted]766Schedule 9A2[Deleted]766Schedule 9A3Jurisdictional Derogations Granted to Generators766Interpretation of tables766Continuing effect766Subsequent agreement767[Deleted]767Reactive Power Capability (clause S5.2.5.1 of schedule 5.2)767[Deleted]768[Deleted]768[Deleted]768[Deleted]768[Deleted]768[Deleted768[Deleted]768Governor Systems (load control) (clause S5.2.5.11 of schedule 5.2)768[Deleted]768[Deleted]768Excitation Control System (clause S5.2.5.13 of schedule 5.2)768Part BJurisdictional Derogations for New South Wales769[Deleted]769Definitions769Definitions used in this Part B769Transitional Arrangements for Chapter 2 - Generators, Registered Participants, Registration and Cross Border Networks770[Deleted]770Customers770Power Traders770Cross Border Networks773[Deleted]774Transitional Arrangements for Chapter 4 - System Security774Power System Operating Procedures774NSW contestable services for Chapter 5A774Definitions774Chapter 5A not to apply to certain contestable services774Transitional Arrangements for Chapter 6 - Network Pricing774NSW contestable services774[Deleted]774Jurisdictional Regulator774Deemed Regulated Interconnector775[Deleted]775Transitional Arrangements for Chapter 7 - Metering775Extent of Derogations775Initial Registration (clause 7.1.2)775Amendments to Schedule 9G1775Compliance with AS/NZ ISO 9002 (clause S7.4.3(f) of schedule 7.4)776A[Deleted]776[Deleted]776Part CJurisdictional Derogations for the Australian Capital Territory776[Deleted]776Definitions and Transitional Arrangements for Cross-BorderNetworks776Definitions776Cross Border Networks776[Deleted]777[Deleted]777Transitional Arrangements for Chapter 6 - Network Pricing777[Deleted]777[Deleted]777[Deleted777[Deleted]777Transitional Arrangements777Chapter 7 - Metering777[Deleted]777A[Deleted]777Part DJurisdictional Derogations for South Australia777Definitions777[Deleted]777Definitions777Transitional Arrangements for Chapter 2 - Registered Participants, Registration And Cross Border Networks780Registration as a Generator780Registration as a Customer781Cross Border Networks781[Deleted]781Registration as a Network Service Provider781[Deleted]782Transitional Arrangements for Chapter 5 - Network Connection782Application of clause 5.2782[Deleted]783Transitional Arrangements for Chapter 6 - Economic Regulation of Distribution Services783[Deleted]783[Deleted]783[Deleted]783[Deleted]783Distribution Network Pricing – South Australia783Capital contributions, prepayments and financial guarantees784Ring fencing784AMonitoring and reporting784Transitional Provisions785Chapter 7 - Metering785Part EJurisdictional Derogations for Queensland785[Deleted]785Definitions and Interpretation785Definitions785Interpretation787Transitional Arrangements for Chapter 1788[Deleted]788Transitional Arrangements for Chapter 2 - Registered Participants and Registration788Application of the Rules in Queensland (clauses 2.2 and 2.5)788Stanwell Cross Border Leases (clause 2.2)788[Deleted]788Registration as a Customer (clause 2.3.1)788There is no clause 9.34.5789Exempted generation agreements (clause 2.2)789[Deleted]793[Deleted]793Transitional Arrangements for Chapter 5 - Network Connection793[Deleted]793Existing connection and access agreements (clause 5.2)793[Deleted]794[Deleted]794Forecasts for connection points to transmission network (clause 5.11.1) .794 9.37.6There is no clause 9.37.6794Cross Border Networks794[Deleted]794Credible contingency events (clause S5.1.2.1 of schedule 5.1)794Reactive power capability (clause S5.2.5.1 of schedule 5.2)795[Deleted]795Voltage fluctuations (clause S5.1.5 of schedule 5.1)795[Deleted]797[Deleted]797[Deleted]797[Deleted]797[Deleted]797[Deleted]797Generating unit response to disturbances (clause S5.2.5.3 of schedule5.2) .............................................................................................................797[Deleted]798Excitation control system (clause S.5.2.5.13 of schedule 5.2)798[Deleted]798Annual forecast information for planning purposes (schedule 5.7)798Transitional Arrangements for Chapter 6 - Network Pricing799[Deleted]799[Deleted]799[Deleted]799Interconnectors between regions799Transmission pricing for exempted generation agreements799Transitional Arrangements for Chapter 7 - Metering800Metering installations to which this clause applies800[Deleted]800[Deleted]800[Deleted]800[Deleted]800Transitional Arrangements for Chapter 8 - AdministrationFunctions800[Deleted]800[Deleted]800[Deleted]800[Deleted]800Schedule 9E1Exempted Generation Agreements800Part FJurisdictional Derogations for Tasmania801Definitions and interpretation801Definitions801Interpretation802National grid, power system and related expressions802[Deleted]803Transitional arrangements for Chapter 2 – Registered Participants and Registration - Customers (clause 2.3.1(e))803Tasmanian Region (clause 3.5)803Transitional arrangements for Chapter 5- Network Connection803Existing Connection Agreements803Transitional arrangements - Transmission and Distribution Pricing.8039.48.4ARing fencing803BUniformity of tariffs for small customers804Transmission network804Deemed regulated interconnector804Part GSchedules to Chapter 9804Schedule 9G1Metering Transitional Arrangements804Introduction804[Deleted]804General Principle804[Deleted]805Accuracy Requirements805[Deleted]805[Deleted]805[Deleted]805[Deleted]805[Deleted]805Glossary807Savings and Transitional Rules941Part ZZJDemand management incentive scheme943Rules consequential on making of the National Electricity Amendment (Demand management incentive scheme) Rule 2015943Definitions943AER to develop and publish the demand management incentive scheme and demand management innovation allowance mechanism943Part ZZMCommon definitions of distribution reliability measures943Rules consequential on the making of the National Electricity Amendment (Common definitions of distribution reliability measures) Rule 2015943Definitions943Distribution reliability measures guidelines944Amended STPIS94411.86.8Distribution Ring Fencing Guidelines944Part ZZURate of Return Guidelines Review944Rules consequential on the making of the National Electricity Amendment (Rate of Return Guidelines Review) Rule 2016944Definitions944Application of current rate of return guidelines to making of a distribution determination for the subsequent regulatory control period945Part ZZVDemand Response Mechanism and Ancillary Services Unbundling ..946Rules consequential on the making of the National Electricity Amendment (Demand Response Management and Ancillary Services Unbundling) rule 2016946Definitions946Participant fees for Market Ancillary Service Providers946Part ZZWLocal Generation Network Credits946Rules consequential on the making of the National Electricity Amendment (Local Generation Network Credits) Rule 2016946Definitions946System limitation template946Part ZZYEmergency Frequency Control Schemes947Rules consequent on the making of the National Electricity Amendment (Emergency frequency control schemes) Rule 2017947Definitions947Interim frequency operating standards for protected events947First power system frequency risk review948AEMO must review existing load shedding procedures948Load shedding procedures948Part ZZZTransmission Connection and Planning Arrangements949Rules consequential on the making of the National Electricity Amendment (Transmission Connection and Planning Arrangements) Rule 2017949Definitions949Grandfathering of existing dedicated connection assets950Preparatory steps for registration changes under the Amending Rule951Participant fees for Dedicated Connection Asset Service Providers951Existing Connection Agreements951Connection process951Transmission Annual Planning Report952Preservation for adoptive jurisdictions952Part ZZZAReplacement expenditure planning arrangements952Rules consequential on the making of the National Electricity Amendment (Replacement expenditure planning arrangements) Rule 2017952Definitions952Interpretation954Transitional arrangements for affected DNSPs954Amendments to RIT documentation954Transitional arrangements relating to excluded projects954Transitional arrangements relating to Victorian bushfire mitigation projects955Transitional arrangements relating to review of costs thresholds955Part ZZZBManaging the rate of change of power system frequency955Rules consequential on the making of the National Electricity Amendment (Managing the rate of change of power system frequency) Rule 2017955Definitions955Inertia sub-networks956Inertia requirements methodology956Inertia requirements957NSCAS not to be used to meet an inertia shortfall after 1 July 2019957Inertia network services may be used to meet an NSCAS gap declared in the NSCAS transition period958Inertia network services made available before the commencement date.958Part ZZZCManaging power system fault levels959Rules consequential on the making of the National Electricity Amendment (Managing power system fault levels) Rule 2017959Definitions959System strength impact assessment guidelines960System strength requirements methodology960System strength requirements960NSCAS not to be used to meet a fault level shortfall after 1 July 2019961System strength services may be used to meet an NSCAS gap declared in the NSCAS transition period962Withdrawal of a system strength-related NSCAS gap already declared962System strength services made available before the commencement date963Part ZZZDGenerating System Model Guidelines963Making of Power System Model Guidelines963Part ZZZEFive Minute Settlement963Rules consequential on the making of the National Electricity Amendment (Five Minute Settlement) Rule 2017963Definitions963Amendments to procedures96411.103.3.Exemption for certain metering installations965New or replacement meters965Metering installations exempt from metering data provision requirements965Exemption from meter data storage requirements965Default offers and bids submitted prior to the commencement date965Part ZZZFContestability of energy services966Rules consequential on the making of the National Electricity Amendment (Contestability of energy services) Rule 2017966Definitions966New guidelines967Transitional arrangements for application of Distribution Service Classification Guidelines and service classification provisions968Transitional arrangements for application of Asset Exemption Guidelines, exemption applications and asset exemption decisions968Transitional arrangements for adjustment in value of regulatory assetbase969Part ZZZGDeclaration of lack of reserve conditions970Making of lack of reserve declaration guidelines970Definitions970Making of lack of reserve declaration guidelines970Part ZZZHImplementation of demand management incentive scheme970Implementation of demand management incentive scheme970Definitions970Purpose970Early application of revised demand management incentive scheme971Part ZZZIReinstatement of long notice Reliability and Emergency Reserve Trader972Rules consequential on the making of the National Electricity Amendment (Reinstatement of long notice Reliability and Emergency Reserve Trader) Rule 2018972Definitions972New RERT guidelines973Amendments to RERT procedures976Reserve contracts entered into before the commencement date976Part ZZZJRegister of distributed energy resources976Rules consequential on the making of the National Electricity Amendment (Register of distributed energy resources) Rule 2018976Definitions976AEMO to develop and publish DER register information guidelines977NSPs to provide AEMO with existing DER generation information977Part ZZZKGenerator technical performance standards977Rules consequential on the making of the National Electricity Amendment (Generator technical performance standards) Rule2018 ...........................................................................................................977Definitions977Application of the Amending Rule to existing connection enquiries978Application of the Amending Rule to existing applications to connect979Application of the Amending Rule to existing offers to connect981Application of the Amending Rule to Existing Connection Agreements981Part ZZZLGenerator three year notice of closure982Rules consequential on the making of the National Electricity Amendment (Generator three year notice of closure) Rule 2018982Definitions982AER to develop and publish notice of closure exemption guideline982Application of Amending Rule to AEMO982Application of Amending Rule to Generators982Part ZZZMParticipant compensation following market suspension983Rules consequential on the making of the National Electricity Amendment (Participant compensation following market suspension) Rule 2018983Definitions983Market suspension compensation methodology and schedule of benchmark values983Part ZZZNGlobal settlement and market reconciliation983Rules consequential on the making of the National Electricity Amendment (Global settlement and market reconciliation) Rule2018 ...........................................................................................................983Definitions983Amendments to AEMO procedures984AEMO to publish report on unaccounted for energy trends984Continuation of registration for non-market generators984Publication of UFE data by AEMO984Publication of UFE reporting guidelines985Part ZZZOMetering installation timeframes985Rules consequential on making of the National Electricity Amendment (Metering installation timeframes) Rule 2018985Definitions985Timeframes for meters to be installed985Part ZZZPEarly implementation of ISP priority projects986National Electricity Amendment (Early implementation of ISP priority projects) Rule 2019986Definitions986Modifications to clause 5.16.6 for ISP VNI and QNI projects987Modifications to clause 6A.8.2 for ISP projects988Part ZZZQEnhancement to the Reliability and Emergency Reserve Trader990Rules consequential on the making of the National Electricity Amendment (Enhancement to the reliability and emergency reserve trader) Rule 2019990Definitions990New RERT guidelines991Amendments to RERT procedures991Reserve contracts entered into before the commencement date991Clause 3.20.6 (Reporting on RERT by AEMO)991Part ZZZRRetailer Reliability Obligation991Rules consequential on the making of the National Electricity Amendment (Retailer Reliability Obligation) Rule 2019991Application991Reliability Instrument Guidelines992Forecasting Best Practice Guidelines992Reliability Forecast Guidelines992AER Opt-in Guidelines993Contracts and Firmness Guidelines993Qualifying contracts under interim Contracts and Firmness Guidelines993Grandfathering arrangements994Reliability Compliance Procedures and Guidelines995MLO Guidelines995Application of Part G, Divisions 2 – 6 (inclusive)995Interim deeming of MLO generators and MLO groups996MLO information template1002Initial MLO register1003Approved MLO products list1003Designated MLO exchange1003Five minute settlement intervals1003Review by AEMC1003Part ZZZSTransparency of new projects1004Rules consequential on the making of the National Electricity Amendment (Transparency of new projects) Rule 20191004Definitions1004Generation information page1004Generation information guidelines1004Provision and use of information100511A.NT Savings and Transitional Rules1007Part ASavings and transitional rules for Chapter 5100911A.1Chapter 5 provisions1009Part BSavings and transitional rules for Chapter 5A100911A.2Model standing offers100911A.2.1Definitions100911A.2.2Extended meaning of some terms101011A.2.3Transitional operation of relevant provisions101011A.2.4Exclusions, qualifications and modifications101011A.2.5References1011Part CSavings and transitional rules for Chapter 7A101211A.3Existing metering installations101211A.4Testing metering installations101311A.5Metering data services database and related requirements101311A.6Communication guideline101411A.7Timeframes for meters to be installed1014

(CHAPTER 1)

(NATIONAL ELECTRICITY RULES AS IN FORCE IN THE NORTHERN TERRITORY VERSION 38) (CHAPTER 1 INTRODUCTION)

(Page 10)

1. Introduction1.1 Preliminary1.1.1 References to the Rules

These Rules (the Rules) are called the National Electricity Rules.

1.1.2 Italicised expressions

Italicised expressions in the Rules are defined in the glossary in Chapter 10.

1.1.3 [Deleted]1.2 Background

These Rules are the National Electricity Rules made under the National Electricity Law and may be amended from time to time in accordance with the National Electricity Law.

1.3 Nomenclature of and references to provisions of a Chapter1.3.1 Introduction

(a) This rule applies to provisions inserted after 16 November 2006, and applies unless the context otherwise requires.

(b) In this rule, "numbered" means identified by one or more numbers or one or more letters, or by a combination of one or more numbers and one or more letters.

1.3.2 Parts, Divisions and Subdivisions

(a) Chapters may contain numbered Parts.

(b) Parts may contain numbered Divisions.

(c) Divisions may contain numbered Subdivisions.

(d) The following table indicates how Parts, Divisions and Subdivisions may be referred to in the Rules.

Level

Provision

Internal reference in same level

External reference in preceding level

1

Chapter 1

2

Part A

this Part

Part A

3

Division 1

this Division

Division 1

4

Subdivision 1

this Subdivision

Subdivision 1

Note:

The numbering of the provisions in the table is by way of example.

1.3.3 Rules, clauses, paragraphs, subparagraphs and other items

(a) Chapters, Parts, Divisions and Subdivisions of the Rules may contain numbered rules.

(b) Rules may contain numbered clauses.

(c) Rules and clauses may contain numbered paragraphs.

(d) Paragraphs may contain numbered subparagraphs.

(e) Subparagraphs may contain numbered items.

(f) The following table indicates how rules, clauses, paragraphs, subparagraphs and other numbered items may be referred to in the Rules.

Level

Provision

Internal reference in same level

External reference in preceding level

1

Chapter, Part or Subdivision

2

rule 1.2

this rule

rule 1.2

3

clause 1.2.3

this clause

clause 1.2.3

4

rule 1.2(a)

clause 1.2.3(a)

this paragraph

this paragraph

paragraph (a)

paragraph (a)

5

rule 1.2(a)(1)

clause 1.2.3(a)(1)

this subparagraph

this subparagraph

subparagraph (1)

subparagraph (1)

6

rule 1.2(a)(1)(i)

clause 1.2.3(a)(1)(i)

this rule 1.2(a)(1)(i)

this clause 1.2.3(a)(1)(i)

rule 1.2(a)(1)(i)

clause 1.2.3(a)(1)(i)

7

rule 1.2(a)(1)(i)(A)

clause 1.2.3(a)(1)(i)(A)

this rule 1.2(a)(1)(i)(A)

this clause 1.2.3(a)(1)(i)(A)

rule 1.2(a)(1)(i)(A)

clause 1.2.3(a)(1)(i)(A)

Note:

The numbering of the provisions in the table is by way of example.

1.4 Effect of renumbering of provisions of the Rules

(a) The renumbering of a provision of the Rules by an Amending Rule does not affect anything done or omitted under the provision before the Amending Rule comes into operation.

(b) A reference (however expressed) in the Rules or in any other document to that provision is taken to be a reference to the provision as renumbered.

(c) Paragraphs (a) and (b) have effect whether or not the renumbered provision is also relocated.

1.5 [Deleted]1.6 [Deleted]1.7 Interpretation1.7.1 General

In the Rules, unless the context otherwise requires:

(a) headings are for convenience only and do not affect the interpretation of the

Rules;

(b) words importing the singular include the plural and vice versa;

(c) words importing a gender include any gender;

(d) when italicised, other parts of speech and grammatical forms of a word or phrase defined in the Rules have a corresponding meaning;

(e) an expression importing a natural person includes any company, partnership, trust, joint venture, association, corporation or other body corporate and any government agency;

(f) a reference to any thing includes a part of that thing;

(g) a reference to a chapter, condition, clause, schedule or part is to a chapter, condition, clause, schedule or part of the Rules;

(h) a reference to any statute, regulation, proclamation, order in council, ordinances or by-laws includes all statutes, regulations, proclamations, orders in council, ordinances and by-laws varying, consolidating, re-enacting, extending or replacing them and a reference to a statute includes all regulations, proclamations, orders in council, ordinances, by-laws and determinations issued under that statute;

(i) a reference to a document or a provision of a document includes an amendment or supplement to, or replacement or novation of, that document or that provision of that document;

(j) a reference to a person includes that person's executors, administrators, successors, substitutes (including, without limitation, persons taking by novation) and permitted assigns;

(k) a period of time:

(1) which dates from a given day or the day of an act or event is to be calculated exclusive of that day; or

(2) which commences on a given day or the day of an act or event is to be calculated inclusive of that day;

(l) an event which is required under the Rules to occur on or by a stipulated day

which is not a business day may occur on or by the next business day; and

(m) the schedules to the Rules form part of the Rules.

It is not intended that any of the following provisions of Schedule 2 to the National Electricity Law should apply to the Rules:

Clauses 2, 4, 9, 10, 11, 21, 28, 29, 30, 31AH, 35, 36, 37 and 38.

This exclusion is in addition to an exclusion that arises from other provisions of the Rules in which an intention is expressed, or from which an intention may be inferred, that a provision of the relevant Schedule is not to apply to the Rules.

1.7.1AInconsistency with National Measurement Act

If there is an inconsistency between the Rules and the National Measurement Act, the National Measurement Act prevails to the extent of the inconsistency.

1.7.1 BInstruments

(a) In an instrument made under the Rules:

(1) a reference to the "National Electricity Law" or "Law" must be regarded as a reference to the National Electricity (NT) Law; and

(2) a reference to the "National Electricity Rules" or "Rules" must be regarded as a reference to the National Electricity Rules as defined in section 2(1) of the National Electricity (NT) Law.

(b) Paragraph (a) applies despite any provision to the contrary in an instrument.

(c) For the purposes of the application in this jurisdiction of an instrument made under the Rules:

(1) the reference to "the national electricity system" in the national electricity objective stated in section 7 of the Law must be regarded as a reference to one or more, or all, of the local electricity systems, as the case requires;

(2) if the context or subject matter indicates or requires, a reference in the instrument to:

(i) "regulatory control period" must be regarded as including a reference to the 2009-14 NT regulatory control period and the 2014-19 NT regulatory control period; and

(ii) "distribution determination" must be regarded as including a reference to the 2009 NT Network Price Determination and the 2014 NT Network Price Determination; and

(3) the AER must interpret the instrument consistently with the objects of the application Act of this jurisdiction and the modifications made to the National Electricity Law and the Rules by or under that Act.

(d) In this clause:

2009 NT Network Price Determination means the "Final Determination – Networks Pricing: 2009 Regulatory Reset" made by the Utilities Commission under the Utilities Commission Act (NT), Electricity Reform Act (NT) and Chapter 6 of the NT Network Access Code that applied from 1 July 2009 to 30 June 2014.

1.8 Notices1.8.1 Service of notices under the Rules

A notice is properly given under the Rules to a person if:

(a) it is personally served;

(b) a letter containing the notice is prepaid and posted to the person at an address (if any) supplied by the person to the sender for service of notices or, where the person is a Registered Participant, an address shown for that person in the register kept by the Utilities Commission under section 37 of the Electricity Reform Act (NT);

(c) it is sent to the person by facsimile or electronic mail to a number or reference which corresponds with the address referred to in clause 1.8.1(b); or

(d) the person receives the notice.

1.8.2 Time of service

A notice is treated as being given to a person by the sender:

(a) where sent by post in accordance with clause 1.8.1(b) to an address in the central business district of a capital city of Australia, on the second business day after the day on which it is posted;

(b) where sent by post in accordance with clause 1.8.1(b) to any other address, on the third business day after the day on which it is posted;

(c) where sent by facsimile in accordance with clause 1.8.1(c) and a complete and correct transmission report is received:

(1) where the notice is of the type in relation to which the addressee is obliged under the Rules to monitor the receipt by facsimile outside of, as well as during, business hours, on the day of transmission; and

(2) in all other cases, on the day of transmission if a business day or, if the transmission is on a day which is not a business day or is after 4.00 pm (addressee's time), at 9.00 am on the following business day;

(d) where sent by electronic mail in accordance with clause 1.8.1(c):

(1) where the notice is of a type in relation to which the addressee is obliged under the Rules to monitor receipt by electronic mail outside of, as well as during, business hours, on the day when the notice is recorded as having been first received at the electronic mail destination; and

(2) in all other cases, on the day when the notice is recorded as having been first received at the electronic mail destination if a business day or, if that time is after 4.00 pm (addressee's time) or the day is not a business day, at 9.00 am on the following business day; or

(e) in any other case, when the person actually receives the notice.

1.8.3 Counting of days

Where a specified period (including, without limitation, a particular number of days) must elapse or expire from or after the giving of a notice before an action may be taken neither the day on which the notice is given nor the day on which the action is to be taken may be counted in reckoning the period.

1.8.4 Reference to addressee

In this rule 1.8, a reference to an addressee includes a reference to an addressee's officers, agents, or employees or any person reasonably believed by the sender to be an officer, agent or employee of the addressee.

1.9 Retention of Records and Documents

Unless otherwise specified in the Rules, all records and documents prepared for or in connection with the Rules must be retained for a period of at least 7 years.

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.)

1.9 ANTESMO’s costs in connection with these Rules

Note

Costs for NTESMO are to be considered as part of the progressive application of the Rules in this jurisdiction.

Where, for any provision of these Rules, a corporate entity is both a Network Service Provider and NTESMO, any costs incurred by that corporate entity in complying with any requirements imposed on NTESMO under a provision where this clause applies are not to be recovered by that corporate entity as a Network Service Provider under Chapter 6.

1.10 [Deleted]1.11 AEMO Rule Funds

Note:

This rule has no effect in this jurisdiction (see regulation 5A of the National Electricity (Northern Territory) (National Uniform Legislation) (Modification) Regulations).

(a) AEMO must continue to maintain, in the books of the corporation:

(1) the registration and administration fund;

(2) the security deposit fund; and

(3) any other fund which the Rules provide will be maintained in AEMO's

books,

(each a "Rule fund" ).

(b) AEMO must ensure that there is paid into each Rule fund:

(1) in the case of the registration and administration fund, all amounts of

Participant fees and auction expense fees and any other amounts

payable under the auction rules or SRD agreements as AEMO considers necessary from time to time other than those which are to be paid into another Rule fund;

(2) in the case of the security deposit fund, amounts which are received by

AEMO under clauses 3.3.8A, 3.3.13(a)(2) and 3.3.13(a)(3);

(3) in the case of a fund referred to in paragraph (a)(3):

(i) all amounts which are received by AEMO in connection with carrying out its functions or powers in relation to that fund;

(ii) all amounts of Participant fees which are received or recovered by AEMO which relate to AEMO's actual or budgeted costs and expenses for carrying out its functions or powers in relation to that fund; and

(4) in the case of each Rule fund, income from investment of money in the

Rule fund.

(c) In respect of the security deposit fund, AEMO must keep records, in respect of each individual Market Participant, of:

(1) security deposits made by that Market Participant and actual interest or other income earned on that Market Participant's payments to that fund which will be recorded as credits for that Market Participant;

(2) any application, or return to that Market Participant, of monies in the security deposit fund in accordance with clause 3.3.13A;

(3) deductions for liabilities and expenses of the security deposit fund referable, or allocated, to that Market Participant which will be recorded as debits to that Market Participant; and

(4) the credit or debit balance for that Market Participant.

(d) AEMO must ensure that money from each Rule fund is only applied in payment of:

(1) in the case of the registration and administration fund, costs and expenses of AEMO carrying out its functions or powers:

(i) in relation to a fund referred to paragraph (a)(3) to the extent that such costs and expenses cannot be met from the money contained in that fund; or

(ii) other than those functions and powers referred to in subparagraph (i);

(2) in the case of the security deposit fund, monies owing to AEMO by a Market Participant or the return of monies to a Market Participant in accordance with clause 3.3.13A;

(3) in the case of a fund referred to in paragraph (a)(3), costs and expenses of AEMO carrying out its functions or powers in relation to that fund; and

(4) in the case of each Rule fund:

(i) other than the security deposit fund, reimbursement to a Registered Participant or another Rule fund to make any necessary adjustment for any excess amounts which are paid as Participant fees as a result of any of AEMO's actual costs and expenses being less than the budgeted costs and expenses or as a result of the payment of any interim Participant fees; and

(ii) liabilities or expenses of the Rule fund.

(CHAPTER 2)

(NATIONAL ELECTRICITY RULES AS IN FORCE IN THE NORTHERN TERRITORY) (CHAPTER 2) (VERSION 38) (REGISTERED PARTICIPANTS AND REGISTRATION)

(Page 12)

2. Registered Participants and Registration

Note:

This Chapter has no effect in this jurisdiction (see regulation 5A of the National Electricity (Northern Territory) (National Uniform Legislation) (Modification) Regulations). The application of this Chapter will be revisited as part of the phased implementation of the Rules in this jurisdiction.

(CHAPTER 2A)

(NATIONAL ELECTRICITY RULES AS IN FORCE IN THE NORTHERN TERRITORY VERSION 38) (CHAPTER 2A REGIONAL STRUCTURES)

(Page 15)

2A.Regional Structures

Note:

This Chapter has no effect in this jurisdiction (see regulation 5A of the National Electricity (Northern Territory) (National Uniform Legislation) (Modification) Regulations). The application of this Chapter will be revisited as part of the phased implementation of the Rules in this jurisdiction.

(CHAPTER 3)

(NATIONAL ELECTRICITY RULES AS IN FORCE IN THE NORTHERN TERRITORY VERSION 38) (CHAPTER 3 MARKET RULES)

(Page 19)

3. Market Rules

Note:

This Chapter has no effect in this jurisdiction (see regulation 5A of the National Electricity (Northern Territory) (National Uniform Legislation) (Modification) Regulations). The application of this Chapter will be revisited as part of the phased implementation of the Rules in this jurisdiction.

(CHAPTER 4)

(NATIONAL ELECTRICITY RULES AS IN FORCE IN THE NORTHERN TERRITORY VERSION 38) (CHAPTER 4) (POWER SYSTEM SECURITY)

(Page 23)

4. Power System Security

Note:

This Chapter has no effect in this jurisdiction (see regulation 5A of the National Electricity (Northern Territory) (National Uniform Legislation) (Modification) Regulations). The application of this Chapter will be revisited as part of the phased implementation of the Rules in this jurisdiction.

(CHAPTER 4A)

(NATIONAL ELECTRICITY RULES AS IN FORCE IN THE NORTHERN TERRITORY) (CHAPTER 4A) (VERSION 38) (RETAILER RELIABILITY OBLIGATION)

(Page 27)

4A.Retailer Reliability Obligation Part AIntroduction

4A.ADefinitions4A.A.1Definitions

In this Chapter:

actual demand means the demand determined in accordance with clause 4A.A.4(b).

adjustment day has the meaning given in clause 4A.E.7(f).

AEMO Opt-In Procedures means the procedures developed by AEMO under clause 4A.D.12.

AER Opt-In Guidelines means the guidelines made by the AER under clause 4A.D.13.

Auditors Panel means the panel of persons (who may be individuals or firms) from whom an Independent Auditor may be appointed in accordance with clause 4A.E.5.

bespoke firmness methodology means a firmness methodology which is not a default firmness methodology.

book build contract means a contract which satisfies the relevant criteria set out under the Book Build Procedures and which may be offered to other book build participants as part of a voluntary book build.

book build fees means fees imposed on book build participants to reimburse AEMO for its costs incurred in developing, establishing and conducting a voluntary book build.

book build participation agreement has the meaning given in clause 4A.H.4(b)(1).

Book Build Procedures means the procedures developed by AEMO under clause 4A.H.2.

compliance TIs has the meaning given in clause 4A.F.2.

contract position day has the meaning given in the National Electricity Law.

Contracts and Firmness Guidelines means the guidelines made by the AER in accordance with clause 4A.E.8.

controlling entity has the meaning given in clause 4A.G.6(a).

default firmness methodology has the meaning given in clause 4A.E.4. firmness methodology has the meaning given in clause 4A.E.3. firmness principles has the meaning given in clause 4A.E.3.

Forecasting Best Practice Guidelines means the guideline made by the AER under clause 4A.B.5.

forecast reliability gap period has the meaning given in the National Electricity Law.

gap trading intervals means the trading intervals stated in a T-1 reliability instrument.

generator capacity has the meaning given in clause 4A.G.3(b).

Independent Auditor means a member of the Auditors Panel.

large opt-in customer means a person registered as a large opt-in customer with the AER under clause 4A.D.4.

liable entity has the meaning given in the National Electricity Law and as determined in accordance with clause 4A.D.2.

liable load means the load determined under clause 4A.F.3(b).

liable share has the meaning given in clause 4A.F.3(a).

liquidity obligation means the obligation to be performed by a MLO generator in a region under rule 4A.G.17.

liquidity period means the period during which a liquidity obligation is in effect with respect to a forecast reliability gap, as determined under clause 4A.G.16.

matched book build participant means a book build participant:

(a) who offers to buy or sell a book build contract through the voluntary book build; and

(b) for which AEMO has identified another book build participant who has made an offer to buy or sell (as applicable) the book build contract referred to in paragraph (a),

in accordance with the Book Build Procedures.

minimum opt-in threshold has the meaning given in clause 4A.D.6(a)(2).

MLO exchange has the meaning given in clause 4A.G.23(a).

MLO generator has the meaning given in clause 4A.G.11.

MLO group has the meaning given in clause 4A.G.10.

MLO Guidelines means the guidelines made by the AER under clause 4A.G.25.

MLO nominee has the meaning given in clause 4A.G.20(a).

MLO products means any product which satisfies the criteria set out under clause 4A.G.22(a) or which the AER approves to be a MLO product under clause 4A.G.22(b).

MLO register means the register established, maintained and published by the AER

under clause 4A.G.12.

NCP report has the meaning given in clause 4A.E.6(a).

net contract position has the meaning given in the National Electricity Law and as determined in accordance with clause 4A.E.2.

new entrant has the meaning given in clause 4A.D.3.

new entrant contract position day means the first day of a reliability gap period, unless an alternative date is stated in a T-1 reliability instrument.

non-standard qualifying contract means a qualifying contract which is not a standard qualifying contract.

one-in-two year peak demand forecast has the meaning given in the National Electricity Law and as determined in accordance with clause 4A.A.3.

opt-in customer means a large opt-in customer or a prescribed opt-in customer.

opt-in customer threshold has the meaning given in clause 4A.D.6(a)(1).

opt-in cut-off day means the day determined in accordance with clause 4A.D.7.

opt-in register means a register established and maintained by the AER in accordance with clause 4A.D.9.

peak demand has the meaning given in the National Electricity Law and as determined in accordance with clause 4A.A.4.

position day means a contract position day or, for a new entrant, a new entrant contract position day.

prescribed opt-in customer means a person registered as a prescribed opt-in customer with the AER under clause 4A.D.5.

qualifying contract has the meaning given in the National Electricity Law and as determined in accordance with clause 4A.E.1.

registered capacity means in respect of a generating unit, the amount, in MW, shown as 'registered capacity' attributable to that generating unit in the 'NEM registration and exemption list' published by AEMO.

Reliability Compliance Procedures and Guidelines has the meaning given in the

National Electricity Law.

reliability instrument has the meaning given in the National Electricity Law.

Reliability Instrument Guidelines means the guidelines made by the AER under clause 4A.C.12.

reporting day

(a) has the meaning given in the National Electricity Law; and

(b) for a new entrant, means the day stated in the relevant T-1 reliability instrument.

standard qualifying contract means a qualifying contract which is specified to be a standard qualifying contract under the Contracts and Firmness Guidelines.

traced capacity has the meaning given in clause 4A.G.7(a).

trading group has the meaning given in clause 4A.G.5.

trading group capacity has the meaning given in clause 4A.G.9(a). trading period has the meaning given in clause 4A.G.18(a). trading right has the meaning given in clause 4A.G.4.

trading right holder has the meaning given in clause 4A.G.4(a).

T-1 cut-off day has the meaning given in the National Electricity Law.

T-1 reliability instrument has the meaning given in the National Electricity Law.

T-3 cut-off day has the meaning given in the National Electricity Law.

T-3 reliability instrument has the meaning given in the National Electricity Law.

ultimate controlling entity has the meaning given in clause 4A.G.6(b).

unscheduled generation has the meaning given in clause 3.7D(a).

4A.A.2Forecast reliability gap materiality

For the purposes of section 14G(1) of the National Electricity Law, a forecast reliability gap occurs in a region in a financial year if identified in a reliability forecast and is material if it exceeds the reliability standard.

Note

Section 14G(1) of the National Electricity Law states –

A forecast reliability gap occurs when the amount of electricity forecast for a region, in accordance with the Rules, does not meet the reliability standard to an extent that, in accordance with the Rules, is material.

4A.A.3One-in-two year peak demand forecast

For the purposes of section 14C of the National Electricity Law, the one-in-two year peak demand forecast for a region is:

(a) the forecast made in accordance with the Reliability Forecast Guidelines; and

(b) specified in a reliability forecast to be that forecast for that region for that

financial year.

Note

Section 14C of the National Electricity Law states the one-in-two year peak demand forecast, for a region during a specified period, means the peak demand forecast in accordance with the Rules –

(a) to occur for a region during the period; and

(b) where the likelihood is that the forecast amount will be exceeded once in any two-year period.

4A.A.4Peak demand

(a) For the purposes of section 14C of the National Electricity Law, the maximum electricity demanded is the highest actual demand in a trading interval in a region (in MW).

Note

Section 14C of the National Electricity Law states the peak demand, for a period in a region, means the maximum electricity demanded, in megawatts, in the region during the period, determined in accordance with the Rules.

(b) The actual demand for a region for a trading interval is:

(1) the demand for that region;

(2) adjusted, to reflect what would have been the demand but for the following adjustments in the market:

(i) directions by AEMO;

(ii) RERT activated or dispatched by AEMO;

(iii) load shedding by AEMO; and

(iv) any other adjustments as set out in the Reliability Forecast Guidelines,

in each case as determined in accordance with the Reliability Forecast Guidelines.

(c) AEMO must publish the actual demand for a trading interval for all regions

on its website as soon as practicable after the end of that trading interval.

Part BReliability Forecasts4A.B.1Reliability forecast

(a) The statement of opportunities must, for a reliability forecast, specify which parts of the statement of opportunities form part of that reliability forecast.

(b) A reliability forecast and indicative reliability forecast must include the matters set out in clause 4A.B.2.